The URL can be used to link to this page

Home My WebLink About215-024Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/21/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260121 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 16RD 50133205540100 207125 12/3/2025 AK E-LINE PPROF T41253 BRU 211-35 50283201890000 223050 11/7/2025 AK E-LINE Perf T41254 BRU 213-26 50283201920000 223069 11/23/2025 AK E-LINE Perf T41255 BRU 213-26T 50283202040000 225038 11/4/2025 AK E-LINE Perf T41256 BRU 241-34S 50283201980000 224077 11/9/2025 AK E-LINE Perf T41257 BRU 241-34T 50283201810000 220052 11/6/2025 AK E-LINE Perf T41258 BRU 244-27 50283201850000 222038 12/13/2025 AK E-LINE Perf T41259 BRU 244-27 50283201850000 222038 12/19/2025 AK E-LINE StripGun T41259 GP ST 17586 9 50733204480000 193062 11/13/2025 AK E-LINE Perf T41260 IRU 241-01 50283201840000 221076 12/21/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/30/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/16/2025 AK E-LINE Plug T41261 IRU 241-01 50283201840000 221076 11/26/2025 AK E-LINE Plug/Perf T41261 KALOTSA 01 50133206570000 216132 11/19/2025 AK E-LINE Perf T41262 KBU 31-18 50133206490000 215024 11/8/2025 AK E-LINE Drift/PPROF T41263 KU 12-17 50133205770000 208089 11/14/2025 AK E-LINE StimGun T41264 LRU C-01RD 50283200610100 201168 11/27/2025 AK E-LINE RCT/Perf T41265 MPI 2-32 50029220840000 190119 12/10/2025 AK E-LINE LDL T41266 MPI 2-38 50029220900000 190129 12/5/2025 AK E-LINE LDL T41267 MPU H-16 50029232270000 204190 12/3/2025 AK E-LINE CBL T41268 MPU H-16 50029232270000 204190 11/19/2025 AK E-LINE TubingCut T41268 MPU I-14 50029232140000 204119 11/13/2025 AK E-LINE CBL T41269 NCIU A-06A 50883200260100 225071 11/28/2025 AK E-LINE Perf/Plug T41270 NCIU A-08 50883200280000 169063 12/2/2025 AK E-LINE GPT T41271 NCIU A-19 50883201940000 224026 12/16/2025 AK E-LINE GPT T41272 NCIU A-19 50883201940000 224026 12/12/2025 AK E-LINE GPT/Perf/Plug T41272 NCIU A-19 50883201940000 224026 12/17/2025 AK E-LINE Perf T41272 NCIU A-21A 50883201990100 225075 12/30/2025 AK E-LINE PPROF T41273 OP19-T1N 50029234910000 213068 11/19/2025 AK E-LINE TubingPunch T41274 KBU 31-18 50133206490000 215024 11/8/2025 AK E-LINE Drift/PPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:35 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU D-10 50283202080000 225082 12/9/2025 AK E-LINE Perf T41275 SCU 322C-04 50133101040100 215217 12/4/2025 AK E-LINE TubingPunch T41276 SRU 222-33 50133207150000 223100 12/7/2025 AK E-LINE Plug T41277 SU 43-10 50133207390000 225107 11/26/2025 AK E-LINE CBL T41278 TBU A-12RD 50733200760100 171029 11/29/2025 AK E-LINE Perf T41279 TBU D-24A 50733202240100 174064 12/2/2025 AK E-LINE TubingPunch T41280 TBU D-24A 50733202240100 174064 11/21/2025 AK E-LINE TubingPunch T41280 TBU M-10 50733205880000 209154 11/15/2025 AK E-LINE Perf T41281 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:51 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Noel Nocas Cc:Stefan Reed; Juanita Lovett; Scott Warner Subject:RE: KBU 31-18 10-404 | PTD: 215-024 | Sundry: 325-624 Date:Wednesday, November 26, 2025 11:07:00 AM Noel, As discussed, it’s ok to keep the sundry open for this well while you are setting/pulling plugs to evaluate performance of the sundried perfs. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Noel Nocas <noel.nocas@hilcorp.com> Sent: Wednesday, November 26, 2025 11:03 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Stefan Reed <stefan.reed@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Scott Warner <scott.warner@hilcorp.com> Subject: KBU 31-18 10-404 | PTD: 215-024 | Sundry: 325-624 Bryan, I appreciated the phone call yesterday. Per our conversation, we are currently evaluating reservoir performance and are determining if a plug needs to be set. Therefore, the 404 will not be submitted within the typical 30 days as required. Once a decision has been made, we will move forward with work and/or closure. Happy Thanksgiving, Noel ---- Noel Nocas Hilcorp Alaska, LLC noel.nocas@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: CTCO, 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): 10,010' N/A Casing Collapse Structural Conductor Surface 2,470psi Intermediate 4,790psi Production 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 stefan.reed@hilcorp.com 206-518-0400 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: PRESENT WELL CONDITION SUMMARY Stefan Reed, 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 Fee-Private 215-024 50-133-20649-00-00 Hilcorp Alaska, LLC Proposed Pools: 18# / L-80 TVD Burst 9,990' 1,476' Size 130' 7-5/8"6,338' 1,476' MD See Schematic 6,890psi 5,210psi 130' 6,198' 130' 1,476' October 23, 2025 5" Perforation Depth MD (ft): 6,338' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Beluga Unit (KBU) 31-18CO 510C Same ~3239psi 9,301' Length Swell Packer; N/A 5,777' MD/5,657' TVD; N/A 9,703' 9,301' 9,024' Kenai Gas Field Beluga/Up Tyonek Gas 16" 10-3/4" See Schematic m n P s t N 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:18 am, Oct 13, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.10.10 16:19:27 - 08'00' Noel Nocas (4361) 325-624 10-404 BJM 10-13-25 DSR-10/15/25A.Dewhurst 13OCT25 10/16/2025 Well Prognosis Well: KBU 31-18 Date: October 2025 Well Name: KBU 31-18 API Number: 50-133-20649-00 Current Status: Producing Gas Well Permit to Drill Number: 215-024 Regulatory Contact: Donna Ambruz (907) 777-8305 (O) First Call Engineer: Stefan Reed (907) 777-8433 (O) (206) 518-0400 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: ~ 4,100 psi @ 8,611 TVD (Based on offset wells) Max. Predicted Surface Pressure: ~ 3,239 psi (0.10 psi/ft gas gradient) Applicable Frac Gradient: 0.62psi/ft using FIT from 3/27/2015 Shallowest Perf Depth: 3,239 psi/(0.62-0.1) = 6,229 TVD Top of Pools Per CO 510C: Top of Beluga/Upper Tyonek is 4,889 MD (4,798 TVD) Brief Well Summary KBU 31-18 was drilled as a Grass roots monobore completion in April 2015 to target gas sands in the Beluga and Tyonek formations. The initial perforations were made in the Tyonek D-3C Sand and found the zone to be tight gas. The Tyonek D-3 Sands were plugged back in September 2015, and the Tyonek Pool was plugged back in December of 2015. The Beluga/Upper Tyonek Pool was perforated in 2015 with additional sands added in 2024. KBU 31-18 currently produces ~500mscfd @ ~50psi FTP. The purpose of this work/sundry is to perform a fill cleanout down to cement at ~9,301 and add perforations in the TY 84-6 sand. All perforations will be in the existing Beluga/Upper Tyonek Pool, per CO 510C. Notes Regarding Wellbore Condition SL tagged fill @ 7,472 w/ 4 GR, 22-July-2025 3.80 restriction @ ~7,847 Monobore 5 completion Cement Bond Log indicates very good bond from TD to 6,340 Coil Tubing Procedure 1. MIRU Coil Tubing 2. Test BOPs to 250psi low / 3500psi high a. Provide 24-hour notice to AOGCC for witness 3. RIH w/ slim clean out BHA 4. Clean out well to top of cement (~9,301) using 6% KCL 5. Circulate out fluid with N2 and trap pressure on well. 6. RDMO coil. E-Line Procedure 1. MIRU E-line, PT lubricator to 250 psi low and 3,500 psi high 2. Drift well w/ Junk basket/Gauge Ring passed proposed perf interval 3. Perforate proposed interval per table below: Well Prognosis Well: KBU 31-18 Date: October 2025 Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT 84-6 ±8,865' ±8,887' ±8,611' ±8,632' ±22' 4. Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a. Record initial and 5/10/15 minute tubing pressures after firing, b. Pending well production, all of the proposed perf interval may not be perforated, or interval may be reperforated at RE/GEO discretion based on production results. c. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations or patch across perforations. d. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations e. Above perfs are in the Beluga/Upper Tyonek Gas Pool governed by CO 510C 5. RDMO e-line. 6. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Coil BOP Schematic 4. Standard Nitrogen Procedure Updated by DMA 04-10-24 Kenai Gas Field Well: KBU 31-18 PTD: 215-024 API: 50-133-20649-00-00SCHEMATIC PBTD = 9,903 MD / 9,600 TVD TD = 10,010 MD / 9,703 TVD RKB: 19CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16Conductor Driven 109 X-56 Weld 16Surf 130' 10-3/4"Surf. Csg 45.5 L-80 BTC 9.95Surf 1,476 7-5/8"Intermediate 29.7 L-80 BTC 6.875"Surf 2,805 7-5/8"Intermediate 29.7 L-80 Hydrill 511 6.875"2,8056,338 TUBING 5"Production 18 L-80 DWC/C HT 4.276Surf 9,990 116 10-3/4 5 JEWELRY DETAIL No. Depth ID OD Item 1 184.27611.00Tubing Hanger 2 5,7774.2766.87510 ft Swell Packer (Water Swell) 3 9,301-15 gal of cement on pebbles for plug 4 9,450-Posiset Plug w/ 10 cement (9/11/15) 7-5/8 Est TOC 3,354 2 OPEN HOLE / CEMENT DETAIL 10-3/4142 bbls of 12# lead cement 165BBLs of cement in 13.5 Hole. Returns to Surface 7-5/8" 132 BBL of 13.5# liteCRETE Lead w/ 1 ppb Cement 29.7 BBLS of 15.3# tail (No cement to surface, 111bbls losses) of cement in 9-7/8 Hole. TOC 3,354 Calculated 5128 BBLs of 15.3# EZ Block cement. 100% returns. CBL Top @ 6340. RA Tag depths: PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD Date Size Status LB 1B L 6,412 6,4196,270' 6,277' 3/28/2024 2-3/4Open LB-1C 6,452 6,466 6,309 6,32210/9/2015 3-3/8Open LB-1E 6,522 6,542 6,376 6,39610/9/2015 3-3/8Open LB-2C 6,736 6,746 6,582 6,59210/9/2015 3-3/8Open LB-2D 6,764 6,773 6,608 6,61810/9/2015 3-3/8Open LB 2E L 6,851 6,8576,693' 6,699' 3/27/2024 2-3/4Open LB 3 U 6,862 6,8676,704' 6,709' 2/22/2024 2-3/4Open LB 3 Mid 6,877 6,8826,718' 6,723' 3/27/2024 2-3/4Open LB 3 L 6,890 6,8946,731' 6,735' 3/22/2024 2-3/4Open LB 3A 6,921 6,9276,761' 6,766' 3/21/2024 2-3/4Open LB-3B 6,944 6,954 6,783 6,79310/9/2015 3-3/8Open LB 3B Mid 6,968 6,9766,806' 6,814' 3/21/2024 2-3/4Open LB 3B L 6,982 6,9906,820' 6,827' 3/21/2024 2-3/4Open LB 3C U 6,994 7,0016,831' 6,838' 2/21/2024 2-3/4Open LB-3C 7,003 7,028 6,840 6,86410/8/2015 3-3/8Open LB 4 7,067 7,0736,902' 6,907' 3/21/2024 2-3/4Open LB 4A 7,079 7,0926,913' 6,926' 3/20/2024 2-3/4Open LB-4B 7,115 7,124 6,948 6,95710/8/2015 3-3/8Open LB-4B 7,134 7,140 6,966 6,97210/8/2015 3-3/8Open LB 4B L 7,148 7,1536,980' 6,985' 3/20/2024 2-3/4Open LB 4C 7,155 7,1706,987' 7,001' 2/21/2024 2-3/4Open LB-4C 7,192 7,199 7,022 7,02910/8/2015 3-3/8Open LB-4D 7,206 7,216 7,036 7,0458/12/2015 3-3/8Open LB 5A U 7,259 7,2697,087' 7,069' 3/28/2024 2-3/4Open LB-5B 7,320 7,333 7,145 7,1588/12/2015 2-7/8Open LB-5B 7,347 7,3577,171 7,181 8/12/2015 2-7/8Open LB6 7,400 7,420 7,222 7,2417/9/2015 2-7/8Open LB6B 7,482 7,492 7,300 7,3107/9/2015 2-7/8Open PERFORATION DETAIL continued on following page CBL TOC 6,340 D-4B D-4A D-3B D-2 D-1 86-2 84-6 84-6 8,739 9,231 8,450 8,126 7,841 7,513 7,224 6,899 73-1 / 73-2 LB5AU- LB6B 3 TOC @ 9,301 Fill @ 8,325 on 11/18/23 4 LB1BL- LB3A LB3B- LB4D UT1B / 76-7 75-8 / 76-7 Updated by DMA 04-10-24 Kenai Gas Field Well: KBU 31-18 PTD: 215-024 API: 50-133-20649-00-00 SCHEMATIC PERFORATION DETAIL Continued from previous page Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Size Status 73-1 7,555 7,562 7,369 7,376 06/29/2015 2-7/8 Open 73-2 7,594 7,611 7,406 7,423 06/29/2015 2-7/8 Open UT1B 7,741 7,752 7,546 7,557 06/23/2015 3-3/8 Open 75-8 7,843 7,850 7,643 7,649 06/23/2015 3-3/8 Open 76-7 7,938 7,950 7,733 7,744 06/23/2015 3-3/8 Open 84-6 8,773 8,785 8,524 8,536 05/15/2015 2-7/8 Open 84-6 8,821 8,841 8,570 8,588 05/15/2015 2-7/8 Open 86-2 8,975 9,000 8,715 8,739 05/15/2015 2-7/8 Open D-1 9,124 9,144 8,856 8,875 05/14/2015 2-7/8 Open D-2 9,337 9,351 9,058 9,072 04/25/2015 2-7/8 Isolated (12/13/2015) D-3B 9,585 9,611 9,295 9,320 04/15/2015 3-1/2 Isolated (9/11/2015) D-4A 9,766 9,785 9,468 9,487 04/25/2015 2-7/8 D-4B 9,800 9,815 9,501 9,515 04/24/2015 2-7/8 tested tight Updated by SR 10-09-25 Kenai Gas Field Well: KBU 31-18 PTD: 215-024 API: 50-133-20649-00-00PROPOSED PBTD = 9,903 MD / 9,600 TVD TD = 10,010 MD / 9,703 TVD RKB: 19CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16Conductor Driven 109 X-56 Weld 16Surf 130' 10-3/4"Surf. Csg 45.5 L-80 BTC 9.95Surf 1,476 7-5/8"Intermediate 29.7 L-80 BTC 6.875"Surf 2,805 7-5/8"Intermediate 29.7 L-80 Hydrill 511 6.875"2,8056,338 TUBING 5"Production 18 L-80 DWC/C HT 4.276Surf 9,990 116 10-3/4 5 JEWELRY DETAIL No. Depth ID OD Item 1 184.27611.00Tubing Hanger 2 5,7774.2766.87510 ft Swell Packer (Water Swell) 3 9,301-15 gal of cement on pebbles for plug 4 9,450-Posiset Plug w/ 10 cement (9/11/15) 7-5/8 Est TOC 3,354 2 OPEN HOLE / CEMENT DETAIL 10-3/4142 bbls of 12# lead cement 165BBLs of cement in 13.5 Hole. Returns to Surface 7-5/8" 132 BBL of 13.5# liteCRETE Lead w/ 1 ppb Cement 29.7 BBLS of 15.3# tail (No cement to surface, 111bbls losses) of cement in 9-7/8 Hole. TOC 3,354 Calculated 5128 BBLs of 15.3# EZ Block cement. 100% returns. CBL Top @ 6340. RA Tag depths: PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD Date Size Status LB 1B L 6,412 6,4196,270' 6,277' 3/28/2024 2-3/4Open LB-1C 6,452 6,466 6,309 6,32210/9/2015 3-3/8Open LB-1E 6,522 6,542 6,376 6,39610/9/2015 3-3/8Open LB-2C 6,736 6,746 6,582 6,59210/9/2015 3-3/8Open LB-2D 6,764 6,773 6,608 6,61810/9/2015 3-3/8Open LB 2E L 6,851 6,8576,693' 6,699' 3/27/2024 2-3/4Open LB 3 U 6,862 6,8676,704' 6,709' 2/22/2024 2-3/4Open LB 3 Mid 6,877 6,8826,718' 6,723' 3/27/2024 2-3/4Open LB 3 L 6,890 6,8946,731' 6,735' 3/22/2024 2-3/4Open LB 3A 6,921 6,9276,761' 6,766' 3/21/2024 2-3/4Open LB-3B 6,944 6,954 6,783 6,79310/9/2015 3-3/8Open LB 3B Mid 6,968 6,9766,806' 6,814' 3/21/2024 2-3/4Open LB 3B L 6,982 6,9906,820' 6,827' 3/21/2024 2-3/4Open LB 3C U 6,994 7,0016,831' 6,838' 2/21/2024 2-3/4Open LB-3C 7,003 7,028 6,840 6,86410/8/2015 3-3/8Open LB 4 7,067 7,0736,902' 6,907' 3/21/2024 2-3/4Open LB 4A 7,079 7,0926,913' 6,926' 3/20/2024 2-3/4Open LB-4B 7,115 7,124 6,948 6,95710/8/2015 3-3/8Open LB-4B 7,134 7,140 6,966 6,97210/8/2015 3-3/8Open LB 4B L 7,148 7,1536,980' 6,985' 3/20/2024 2-3/4Open LB 4C 7,155 7,1706,987' 7,001' 2/21/2024 2-3/4Open LB-4C 7,192 7,199 7,022 7,02910/8/2015 3-3/8Open LB-4D 7,206 7,216 7,036 7,0458/12/2015 3-3/8Open LB 5A U 7,259 7,2697,087' 7,069' 3/28/2024 2-3/4Open LB-5B 7,320 7,333 7,145 7,1588/12/2015 2-7/8Open LB-5B 7,347 7,3577,171 7,181 8/12/2015 2-7/8Open LB6 7,400 7,420 7,222 7,2417/9/2015 2-7/8Open LB6B 7,482 7,492 7,300 7,3107/9/2015 2-7/8Open PERFORATION DETAIL continued on following page CBL TOC 6,340 D-4B D-4A D-3B D-2 D-1 86-2 84-6 84-6 8,739 9,231 8,450 8,126 7,841 7,513 7,224 6,899 73-1 / 73-2 LB5AU- LB6B 3 TOC @ 9,301 4 LB1BL- LB3A LB3B- LB4D UT1B / 76-7 75-8 / 76-7 Updated by SR 10-09-25 Kenai Gas Field Well: KBU 31-18 PTD: 215-024 API: 50-133-20649-00-00 PROPOSED PERFORATION DETAIL Continued from previous page Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Size Status 73-1 7,555 7,562 7,369 7,376 06/29/2015 2-7/8 Open 73-2 7,594 7,611 7,406 7,423 06/29/2015 2-7/8 Open UT1B 7,741 7,752 7,546 7,557 06/23/2015 3-3/8 Open 75-8 7,843 7,850 7,643 7,649 06/23/2015 3-3/8 Open 76-7 7,938 7,950 7,733 7,744 06/23/2015 3-3/8 Open 84-6 8,773 8,785 8,524 8,536 05/15/2015 2-7/8 Open 84-6 8,821 8,841 8,570 8,588 05/15/2015 2-7/8 Open 84-6 8,865 8,887 8,611 8,632 TBD TBD Proposed 86-2 8,975 9,000 8,715 8,739 05/15/2015 2-7/8 Open D-1 9,124 9,144 8,856 8,875 05/14/2015 2-7/8 Open D-2 9,337 9,351 9,058 9,072 04/25/2015 2-7/8 Isolated (12/13/2015) D-3B 9,585 9,611 9,295 9,320 04/15/2015 3-1/2 Isolated (9/11/2015) D-4A 9,766 9,785 9,468 9,487 04/25/2015 2-7/8 D-4B 9,800 9,815 9,501 9,515 04/24/2015 2-7/8 tested tight 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. 1. 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: 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 10,010 feet 9,301 feet true vertical 9,703 feet N/A feet Effective Depth measured 9,301 feet 5,777 feet true vertical 9,024 feet 5,657 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)5" 18# / L-80 9,990' MD 9,684' TVD Packers and SSSV (type, measured and true vertical depth)Swell Pkr; N/A 5,777' MD 5,657' TVD N/A, N/A 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: 4,790psi 5,210psi 6,890psi 1,476'1,476' Burst Collapse 2,470psi Production Liner 6,338' Casing Structural 6,198'6,338' 130'Conductor Surface Intermediate 16" 10-3/4" 130' 1,476' measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-024 50-133-20649-00-00 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: Fee-Private Kenai / Beluga-Up Tyonek Gas Kenai Beluga Unit (KBU) 31-18 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 50 Size 130' 14 40589 0 586 59 Chad Helgeson, Operations Engineer 324-059 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 chelgeson@hilcorp.com 907-777-8405 p k ft t Fra O 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 By Samantha Coldiron at 8:45 am, Apr 15, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.04.12 17:39:12 - 08'00' Noel Nocas (4361) DSR-4/23/24 RBDMS JSB 041824 Page 1/1 Well Name: KEU KBU 31-18 Report Printed: 4/10/2024www.peloton.com Alaska Weekly Report - Operations Jobs Actual Start Date:2/21/2024 End Date: Report Number 1 Report Start Date 2/21/2024 Report End Date 2/22/2024 Last 24hr Summary PJSM. Crew travel to location. MIRU Halliburton e-line unit. P-test lub to 250/3,500 psi - good. Run PT log survey. Perf LB 4C (7,155 - 7,170') and LB 3C Upper (6,994 - 7,001'). SDFN. Report Number 2 Report Start Date 2/22/2024 Report End Date 2/23/2024 Last 24hr Summary PJSM. Crew travel to location. RU WL lubricator and make up tools. Perf the LB 3 Upper Sand (6,862 - 6,867'). Run PT log survey. RDMO Halliburton e-line. Report Number 3 Report Start Date 3/20/2024 Report End Date 3/21/2024 Last 24hr Summary MIRU HES E-Line. PT 250/3500 PSI. Good. RIH w/ GPT. FL 4100’. RIH w/ Gun 1. Perf LB 4B Lower at 7148’ to 7153’. RIH w/ Gun 2. Perf LB 4A at 7079’ to 7092’. SDFN. Plan forward: Continue perforating LB zones. Report Number 4 Report Start Date 3/21/2024 Report End Date 3/22/2024 Last 24hr Summary MIRU HES E-Line. RIH w/ Gun 3. Perf LB 4 zone 7067’ to 7073’. RIH w/ Gun 4. Perf LB 3B Lower zone 6982’ to 6990’. RIH w/ Gun 5. Perf LB 3B Mid zone 6968’ to 6976’. RIH w/ Gun 6. Perf LB 3A zone 6921’ to 6927’. Secure well & SDFN. Report Number 5 Report Start Date 3/22/2024 Report End Date 3/23/2024 Last 24hr Summary PTW/PJSM. Halliburton e-line unit on location from yesterday. GIH with 2-7/8" guns and perforate the LB 3 Lower sand from 6,890 - 6,894' with well flowing. RDMO. Report Number 6 Report Start Date 3/27/2024 Report End Date 3/28/2024 Last 24hr Summary MIRU HES E-line. PT lubricator 300/3500 psi. RIH with GPT to 6950'. LOG ooh found fluid level 3490'. RIH gun 1 . Perforate LB 3 Mid with 5' gun from 6877'- 6882'. Perforate Gun 2 LB 2E Lower with 6' gun from 6851'-6857'. SDFN Report Number 7 Report Start Date 3/28/2024 Report End Date 3/29/2024 Last 24hr Summary Continue Perforating. Perforate LB 1B Lower 6412'-6419', LB 1B upper 6377'-6392' and the Tranche 4 LB 5A Upper 7259'-7269'. No change in pressure or rate during perforating. RDMO to next well. Field: Kenai Gas Field Sundry #: 324-059 State: Alaska Rig/Service:Permit to Drill (PTD) #:215-024Permit to Drill (PTD) #:215-024 Wellbore API/UWI:50-133-20649-00-00 Updated by DMA 04-10-24 Kenai Gas Field Well: KBU 31-18 PTD: 215-024 API: 50-133-20649-00-00 SCHEMATIC PBTD = 9,903’ MD / 9,600’ TVD TD = 10,010’ MD / 9,703’ TVD RKB: 19’CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven 109 X-56 Weld 16”Surf 130' 10-3/4"Surf. Csg 45.5 L-80 BTC 9.95”Surf 1,476’ 7-5/8"Intermediate 29.7 L-80 BTC 6.875"Surf 2,805’ 7-5/8"Intermediate 29.7 L-80 Hydrill 511 6.875"2,805’6,338’ TUBING 5"Production 18 L-80 DWC/C HT 4.276”Surf 9,990’ 116” 10-3/4” 5” JEWELRY DETAIL No.Depth ID OD Item 1 18’4.276”11.00”Tubing Hanger 2 5,777’4.276”6.875”10 ft Swell Packer (Water Swell) 3 9,301’-15 gal of cement on pebbles for plug 4 9,450’-Posiset Plug w/ 10’ cement (9/11/15) 7-5/8” Est TOC 3,354’ 2 OPEN HOLE / CEMENT DETAIL 10-3/4”142 bbls of 12# lead cement 165BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 132 BBL of 13.5# liteCRETE Lead w/ 1 ppb Cement 29.7 BBLS of 15.3# tail (No cement to surface, 111bbls losses) of cement in 9-7/8” Hole. TOC 3,354’ Calculated 5”128 BBL’s of 15.3# EZ Block cement. 100% returns. CBL Top @ 6340’. RA Tag depths: PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD Date Size Status LB 1B L 6,412’6,419’6,270'6,277'3/28/2024 2-3/4”Open LB-1C 6,452’6,466’6,309’6,322’10/9/2015 3-3/8”Open LB-1E 6,522’6,542’6,376’6,396’10/9/2015 3-3/8”Open LB-2C 6,736’6,746’6,582’6,592’10/9/2015 3-3/8”Open LB-2D 6,764’6,773’6,608’6,618’10/9/2015 3-3/8”Open LB 2E L 6,851’6,857’6,693'6,699'3/27/2024 2-3/4””Open LB 3 U 6,862’6,867’6,704'6,709'2/22/2024 2-3/4”Open LB 3 Mid 6,877’6,882’6,718'6,723'3/27/2024 2-3/4”Open LB 3 L 6,890’6,894’6,731'6,735'3/22/2024 2-3/4”Open LB 3A 6,921’6,927’6,761'6,766'3/21/2024 2-3/4”Open LB-3B 6,944’6,954’6,783’6,793’10/9/2015 3-3/8”Open LB 3B Mid 6,968’6,976’6,806'6,814'3/21/2024 2-3/4”Open LB 3B L 6,982’6,990’6,820'6,827'3/21/2024 2-3/4”Open LB 3C U 6,994’7,001’6,831'6,838'2/21/2024 2-3/4”Open LB-3C 7,003’7,028’6,840’6,864’10/8/2015 3-3/8”Open LB 4 7,067’7,073’6,902'6,907'3/21/2024 2-3/4”Open LB 4A 7,079’7,092’6,913'6,926'3/20/2024 2-3/4”Open LB-4B 7,115’7,124’6,948’6,957’10/8/2015 3-3/8”Open LB-4B 7,134’7,140’6,966’6,972’10/8/2015 3-3/8”Open LB 4B L 7,148’7,153’6,980'6,985'3/20/2024 2-3/4”Open LB 4C 7,155’7,170’6,987'7,001'2/21/2024 2-3/4”Open LB-4C 7,192’7,199’7,022’7,029’10/8/2015 3-3/8”Open LB-4D 7,206’7,216’7,036’7,045’8/12/2015 3-3/8”Open LB 5A U 7,259’7,269’7,087'7,069'3/28/2024 2-3/4”Open LB-5B 7,320’7,333’7,145’7,158’8/12/2015 2-7/8”Open LB-5B 7,347’7,357’7,171 7,181 8/12/2015 2-7/8”Open LB6 7,400’7,420’7,222’7,241’7/9/2015 2-7/8”Open LB6B 7,482’7,492’7,300’7,310’7/9/2015 2-7/8”Open PERFORATION DETAIL continued on following page CBL TOC 6,340’ D-4B D-4A D-3B D-2 D-1 86-2 84-6 84-6 8,739’ 9,231’ 8,450’ 8,126’ 7,841’ 7,513’ 7,224’ 6,899’ 73-1 / 73-2 LB5AU- LB6B 3 TOC @ 9,301’ Fill @ 8,325’ on 11/18/23 4 LB1BL- LB3A LB3B- LB4D UT1B / 76-7 75-8 / 76-7 Updated by DMA 04-10-24 Kenai Gas Field Well: KBU 31-18 PTD: 215-024 API: 50-133-20649-00-00 SCHEMATIC PERFORATION DETAIL – Continued from previous page Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Size Status 73-1 7,555’ 7,562’ 7,369’ 7,376’ 06/29/2015 2-7/8” Open 73-2 7,594’ 7,611’ 7,406’ 7,423’ 06/29/2015 2-7/8” Open UT1B 7,741’ 7,752’ 7,546’ 7,557’ 06/23/2015 3-3/8” Open 75-8 7,843’ 7,850’ 7,643’ 7,649’ 06/23/2015 3-3/8” Open 76-7 7,938’ 7,950’ 7,733’ 7,744’ 06/23/2015 3-3/8” Open 84-6 8,773’ 8,785’ 8,524’ 8,536’ 05/15/2015 2-7/8” Open 84-6 8,821’ 8,841’ 8,570’ 8,588’ 05/15/2015 2-7/8” Open 86-2 8,975’ 9,000’ 8,715’ 8,739’ 05/15/2015 2-7/8” Open D-1 9,124’ 9,144’ 8,856’ 8,875’ 05/14/2015 2-7/8” Open D-2 9,337’ 9,351’ 9,058’ 9,072’ 04/25/2015 2-7/8” Isolated (12/13/2015) D-3B 9,585’ 9,611’ 9,295’ 9,320’ 04/15/2015 3-1/2” Isolated (9/11/2015) D-4A 9,766’ 9,785’ 9,468’ 9,487’ 04/25/2015 2-7/8” D-4B 9,800’ 9,815’ 9,501’ 9,515’ 04/24/2015 2-7/8” tested tight Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/28/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240228 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# AN-37 50733203940000 187109 11/8/2023 HALLIBURTON RBT KBU 31-18 50133206490000 215024 2/22/2024 HALLIBURTON PressTemp KBU 42-6 50133205460000 204209 2/23/2024 HALLIBURTON PPROF KU 31-07X 50133204950000 200148 2/2/2024 HALLIBURTON PressTemp MPU C-13 50029213280000 185067 2/23/2024 READ CaliperSurvey MPU C-14 50029213440000 185088 2/23/2024 READ CaliperSurve MPU L-43 50029231900000 203224 2/14/2024 READ CaliperSurvey MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON COILFLAG TBU M-20 50733205870000 209093 1/1/2024 HALLIBURTON COILFLAG Please include current contact information if different from above. T38535 T38536 T38537 T38538 T38539 T38540 T38541 T38542 T38543 2/29/2024 KBU 31-18 50133206490000 215024 2/22/2024 HALLIBURTON PressTemp Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 09:17:32 -09'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 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): 10,010'N/A Casing Collapse Structural Conductor Surface 2,470psi Intermediate 4,790psi Production 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 chelgeson@hilcorp.com 907-777-8405 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: PRESENT WELL CONDITION SUMMARY Chad Helgeson, 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 Fee-Private 215-024 50-133-20649-00-00 Hilcorp Alaska, LLC Proposed Pools: 18# / L-80 TVD Burst 9,990' 1,476' Size 130' 7-5/8"6,338' 1,476' MD See Schematic 6,890psi 5,210psi 130' 6,198' 130' 1,476' February 14, 2024 5" Perforation Depth MD (ft): 6,338' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Beluga Unit (KBU) 31-18CO 510C Same 2,942psi 9,301' Length Swell Packer; N/A 5,777' MD/5,657' TVD; N/A 9,703'9,903'9,600' Kenai Gas Field Beluga/Up Tyonek Gas 16" 10-3/4" See Schematic m n P s t N 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Coldiron at 2:37 pm, Feb 07, 2024 324-059 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.02.06 19:04:05 - 09'00' Noel Nocas (4361) SFD 2/8/2024BJM 2/14/24 Perforate DSR-2/13/24 10-404 Beluga/Up Tyonek Gas *&:JLC 2/14/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.14 16:23:47 -06'00' RBDMS JSB 021524 Well Prognosis Well: KBU 31-18 Date: 1/30/24 Well Name: KBU 31-18 API Number: 50-133-20649-00 Current Status: Producing Gas Well Permit to Drill Number: 215-024 Regulatory Contact: Donna Ambruz 777-8305 First Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Maximum Expected BHP: ~ 3,678 psi @ 7,369’ TVD (Based on offset wells, EMW = 9.6ppg) Max. Predicted Surface Pressure: ~ 2,942 psi (0.10 psi/ft gas gradient) Brief Well Summary KBU 31-18 was drilled as a Grass roots monobore completion in April 2015 to target gas sands in the Beluga and Tyonek formations. The initial perforations were made in the Tyonek D-3C Sand and found the zone to be tight gas. The Tyonek D-3 Sands were plugged back in September 2015, and the Tyonek Pool was plugged back in December of 2015. The Beluga/Upper Tyonek Pool was perforated in 2015 and has flowed continuously since 2015, currently making ~600mcfd @ 70 psi. The purpose of this work/sundry is add perforations in the Upper Beluga sands. All perforations will be in the existing Beluga/Upper Tyonek Pool, per CO 510C. Notes Regarding Wellbore Condition x Monobore 5” completion x SL tagged fill @ 8,325’ & fluid level at 7,625’ x Cement Bond Log indicates very good bond from TD to 6,340’ E-Line Procedure 1. MIRU E-line, PT lubricator to 250 psi low and 3,500 psi high 2. PU GPT and RIH to confirm fluid depth 3. Perforate Lower Beluga sands with 2-3/4” 60 deg phased perf guns with the well flowing per the table below: 4. These zones will be shot and tested based on porosity, in 4 different tranche (listed in the table). Proposed Perforated Intervals Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Tranche LB1B Upper ±6,377' ±6,392' ±6,236' ±6,190' ±15' 3 LB 1B Lower ±6,412' ±6,419' ±6,270' ±6,277' ±7' 3 LB 2E Lower ±6,851' ±6,857' ±6,693' ±6,699' ±6' 3 LB 3 Upper ±6,862' ±6,867' ±6,704' ±6,709' ±5' 1 LB 3 Mid ±6,877' ±6,882' ±6,718' ±6,723' ±5' 3 LB 3 Lower ±6,890' ±6,894' ±6,731' ±6,735' ±4' 2 LB 3A ±6,921' ±6,927' ±6,761' ±6,766' ±6' 2 LB 3B Mid ±6,968' ±6,976' ±6,806' ±6,814' ±8' 2 LB 3B Lower ±6,982' ±6,990' ±6,820' ±6,827' ±8' 2 All perforations will be in the existing Beluga/Upper Tyonek Pool, per CO 510C. Well Prognosis Well: KBU 31-18 Date: 1/30/24 LB 3C Upper ±6,994' ±7,001' ±6,831' ±6,838' ±7' 1 LB 4 ±7,067' ±7,073' ±6,902' ±6,907' ±6' 2 LB 4A ±7,079' ±7,092' ±6,913' ±6,926' ±13' 2 LB 4B Lower ±7,148' ±7,153' ±6,980' ±6,985' ±5' 2 LB 4C ±7,155' ±7,170' ±6,987' ±7,001' ±15' 1 LB 5A Upper ±7,259' ±7,269' ±7,087' ±7,069' ±10' 4 Tyk 72-8 ±7,550' ±7,555' ±7,365' ±7,369' ±5' 2 a. Proposed perfs also shown on the proposed schematic in red font. b. Send the correlation pass to the Reservoir Engineer (Reid Edwards), and Geologist (Daniel Yancey) for confirmation. c. Verify PTs are open to SCADA before perforating. Record tubing pressures at 5, 10 and 15 minutes after each perforating run. d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot e. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations f. If necessary, nitrogen may be used to pressure up well during perforating or to depress water prior to setting a plug above perforations g. These sands are in the Beluga/Upper Tyonek Gas Pool per CO 510C. 5. RDMO e-line. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Standard Nitrogen Procedure Downhole Revised 7/9/15 Updated by DMA 01-12-16 Kenai Gas Field Well: KBU 31-18 PTD: 215-024 API: 50-133-20649-00 SCHEMATIC PBTD = 9,903’ MD / 9,600’ TVD TD = 10,010’ MD / 9,703’ TVD RKB: 19’CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven 109 X-56 Weld 16”Surf 130' 10-3/4"Surf. Csg 45.5 L-80 BTC 9.95”Surf 1,476’ 7-5/8"Intermediate 29.7 L-80 BTC 6.875"Surf 2,805’ 7-5/8"Intermediate 29.7 L-80 Hydrill 511 6.875"2,805’6,338’ TUBING 5"Production 18 L-80 DWC/C HT 4.276”Surf 9,990’ 116” 10-3/4” 5” JEWELRY DETAIL No.Depth ID OD Item 1 18’4.276”11.00”Tubing Hanger 2 5,777’4.276”6.875”10 ft Swell Packer (Water Swell) 3 9,301’15 gal of cement on pebbles for plug 4 9,450’Posiset Plug w/ 10’ cement7-5/8” Est TOC 3,354’ 2 OPEN HOLE / CEMENT DETAIL 10-3/4”142 bbls of 12# lead cement 165BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 132 BBL of 13.5# liteCRETE Lead w/ 1 ppb Cement 29.7 BBLS of 15.3# tail (No cement to surface, 111bbls losses) of cement in 9-7/8” Hole. TOC 3,354’ Calculated 5”128 BBL’s of 15.3# EZ Block cement. 100% returns. TOC 4,239’ Calculated RA Tag depths: PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Date Size Status LB-1C 6,452’6,466’6,309’6,322’10/09/2015 3-3/8”Open LB-1E 6,522’6,542’6,376’6,396’10/09/2015 3-3/8”Open LB-2C 6,736’6,746’6,582’6,592’10/09/2015 3-3/8”Open LB-2D 6,764’6,773’6,608’6,618’10/09/2015 3-3/8”Open LB-3B 6,944’6,954’6,783’6,793’10/09/2015 3-3/8”Open LB-3C 7,003’7,028’6,840’6,864’10/08/2015 3-3/8”Open LB-4B 7,115’7,124’6,948’6,957’10/08/2015 3-3/8”Open LB-4B 7,134’7,140’6,966’6,972’10/08/2015 3-3/8”Open LB-4C 7,192’7,199’7,022’7,029’10/08/2015 3-3/8”Open LB-4D 7,206’7,216’7,036’7,045’08/12/2015 3-3/8”Open LB-5B 7,320’7,333’7,145’7,158’08/12/2015 2-7/8”Open LB-5B 7,347’7,357’7,171 7,181 08/12/2015 2-7/8”Open LB6 7,400’7,420’7,222’7,241’07/09/2015 2-7/8”Open LB6B 7,482’7,492’7,300’7,310’07/09/2015 2-7/8”Open 73-1 7,555’7,562’7,369’7,376’06/29/2015 2-7/8”Open 73-2 7,594’7,611’7,406’7,423’06/29/2015 2-7/8”Open UT1B 7,741’7,752’7,546’7,557’06/23/2015 3-3/8”Open 75-8 7,843’7,850’7,643’7,649’06/23/2015 3-3/8”Open 76-7 7,938’7,950’7,733’7,744’06/23/2015 3-3/8”Open 84-6 8,773’8,785’8,524’8,536’05/15/2015 2-7/8”Open 84-6 8,821’8,841’8,570’8,588’05/15/2015 2-7/8”Open 86-2 8,975’9,000’8,715’8,739’05/15/2015 2-7/8”Open D-1 9,124’9,144’8,856’8,875’05/14/2015 2-7/8”Open D-2 9,337’ 9,351’ 9,058’ 9,072’ 04/25/2015 2-7/8”Isolated (12/13/2015) D-3B 9,585’9,611’9,295’9,320’04/15/2015 3-1/2”Isolated (9/11/2015)D-4A 9,766’9,785’9,468’9,487’04/25/2015 2-7/8” D-4B 9,800’9,815’9,501’9,515’04/24/2015 2-7/8”tested tight CBL TOC 6,340’ D-4B D-4A D-3B D-2 D-1 86-2 84-6 84-6 8,739’ 9,231’ 8,450’ 8,126’ 7,841’ 7,513’ 7,224’ 6,899’ 76-7 75-8 UT1B 73-2 LB6 LB6B 73-1 3 TOC @ 9,301’ Updated by DMA 01-31-24 Kenai Gas Field Well: KBU 31-18 PTD: 215-024 API: 50-133-20649-00-00 PROPOSED PBTD = 9,903’ MD / 9,600’ TVD TD = 10,010’ MD / 9,703’ TVD RKB: 19’CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven 109 X-56 Weld 16”Surf 130' 10-3/4"Surf. Csg 45.5 L-80 BTC 9.95”Surf 1,476’ 7-5/8"Intermediate 29.7 L-80 BTC 6.875"Surf 2,805’ 7-5/8"Intermediate 29.7 L-80 Hydrill 511 6.875"2,805’6,338’ TUBING 5"Production 18 L-80 DWC/C HT 4.276”Surf 9,990’ 116” 10-3/4” 5” JEWELRY DETAIL No.Depth ID OD Item 1 18’4.276”11.00”Tubing Hanger 2 5,777’4.276”6.875”10 ft Swell Packer (Water Swell) 3 9,301’-15 gal of cement on pebbles for plug 4 9,450’-Posiset Plug w/ 10’ cement (9/11/15) 7-5/8” Est TOC 3,354’ 2 OPEN HOLE / CEMENT DETAIL 10-3/4”142 bbls of 12# lead cement 165BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 132 BBL of 13.5# liteCRETE Lead w/ 1 ppb Cement 29.7 BBLS of 15.3# tail (No cement to surface, 111bbls losses) of cement in 9-7/8” Hole. TOC 3,354’ Calculated 5”128 BBL’s of 15.3# EZ Block cement. 100% returns. CBL Top @ 6340’. RA Tag depths: PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Date Size Status LB1B U ±6,377’±6,392’±6,236'±6,190'TBD 2-3/4”Proposed LB 1B L ±6,412’±6,419’±6,270'±6,277'TBD 2-3/4”Proposed LB-1C 6,452’6,466’6,309’6,322’10/09/2015 3-3/8”Open LB-1E 6,522’6,542’6,376’6,396’10/09/2015 3-3/8”Open LB-2C 6,736’6,746’6,582’6,592’10/09/2015 3-3/8”Open LB-2D 6,764’6,773’6,608’6,618’10/09/2015 3-3/8”Open LB 2E L ±6,851’±6,857’±6,693'±6,699'TBD 2-3/4””Proposed LB 3 U ±6,862’±6,867’±6,704'±6,709'TBD 2-3/4”Proposed LB 3 Mid ±6,877’±6,882’±6,718'±6,723'TBD 2-3/4”Proposed LB 3 L ±6,890’±6,894’±6,731'±6,735'TBD 2-3/4”Proposed LB 3A ±6,921’±6,927’±6,761'±6,766'TBD 2-3/4”Proposed LB-3B 6,944’6,954’6,783’6,793’10/09/2015 3-3/8”Open LB 3B Mid ±6,968’±6,976’±6,806'±6,814'TBD 2-3/4”Proposed LB 3B L ±6,982’±6,990’±6,820'±6,827'TBD 2-3/4”Proposed LB 3C U ±6,994’±7,001’±6,831'±6,838'TBD 2-3/4”Proposed LB-3C 7,003’7,028’6,840’6,864’10/08/2015 3-3/8”Open LB 4 ±7,067’±7,073’±6,902'±6,907'TBD 2-3/4”Proposed LB 4A ±7,079’±7,092’±6,913'±6,926'TBD 2-3/4”Proposed LB-4B 7,115’7,124’6,948’6,957’10/08/2015 3-3/8”Open LB-4B 7,134’7,140’6,966’6,972’10/08/2015 3-3/8”Open LB 4B L ±7,148’±7,153’±6,980'±6,985'TBD 2-3/4”Proposed LB 4C ±7,155’±7,170’±6,987'±7,001'TBD 2-3/4”Proposed LB-4C 7,192’7,199’7,022’7,029’10/08/2015 3-3/8”Open LB-4D 7,206’7,216’7,036’7,045’08/12/2015 3-3/8”Open LB 5A U ±7,259’±7,269’±7,087'±7,069'TBD 2-3/4”Proposed LB-5B 7,320’7,333’7,145’7,158’08/12/2015 2-7/8”Open LB-5B 7,347’7,357’7,171 7,181 08/12/2015 2-7/8”Open LB6 7,400’7,420’7,222’7,241’07/09/2015 2-7/8”Open LB6B 7,482’7,492’7,300’7,310’07/09/2015 2-7/8”Open Tyk 72-8 ±7,550’±7,555’±7,365'±7,369'TBD 2-3/4”Proposed PERFORATION DETAIL continued on following page CBL TOC 6,340’ D-4B D-4A D-3B D-2 D-1 86-2 84-6 84-6 8,739’ 9,231’ 8,450’ 8,126’ 7,841’ 7,513’ 7,224’ 6,899’ 76-7 75-8 UT1B 73-2 LB6 LB6B 73-1 3 TOC @ 9,301’ Fill @ 8,325’ on 11/18/23 4 Updated by DMA 01-31-24 Kenai Gas Field Well: KBU 31-18 PTD: 215-024 API: 50-133-20649-00-00 PROPOSED PERFORATION DETAIL – Continued from previous page Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Size Status 73-1 7,555’ 7,562’ 7,369’ 7,376’ 06/29/2015 2-7/8” Open 73-2 7,594’ 7,611’ 7,406’ 7,423’ 06/29/2015 2-7/8” Open UT1B 7,741’ 7,752’ 7,546’ 7,557’ 06/23/2015 3-3/8” Open 75-8 7,843’ 7,850’ 7,643’ 7,649’ 06/23/2015 3-3/8” Open 76-7 7,938’ 7,950’ 7,733’ 7,744’ 06/23/2015 3-3/8” Open 84-6 8,773’ 8,785’ 8,524’ 8,536’ 05/15/2015 2-7/8” Open 84-6 8,821’ 8,841’ 8,570’ 8,588’ 05/15/2015 2-7/8” Open 86-2 8,975’ 9,000’ 8,715’ 8,739’ 05/15/2015 2-7/8” Open D-1 9,124’ 9,144’ 8,856’ 8,875’ 05/14/2015 2-7/8” Open D-2 9,337’ 9,351’ 9,058’ 9,072’ 04/25/2015 2-7/8” Isolated (12/13/2015) D-3B 9,585’ 9,611’ 9,295’ 9,320’ 04/15/2015 3-1/2” Isolated (9/11/2015) D-4A 9,766’ 9,785’ 9,468’ 9,487’ 04/25/2015 2-7/8” D-4B 9,800’ 9,815’ 9,501’ 9,515’ 04/24/2015 2-7/8” tested tight 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. • S Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Monday,August 01,2016 1:14 PM To: 'Donna Ambruz' Cc: Chad Helgeson;Taylor Nasse;samantha.carlisle@alaska.gov Subject: RE: Sundry Cancellation - Sundry#315-493 KBU 31-18(PTD 215-024) Donna, The AOGCC will withdraw sundry#315-493 as requested. Scope of work was add perfs to well KBU 31-18. 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-U26) or(Guy.schwartz@alaska.gov). From: Donna Ambruz [mailto:dambruz@ hilcorp.com] Sent: Monday,August 01, 2016 1:06 PM To: Schwartz, Guy L(DOA) Cc: Chad Helgeson;Taylor Nasse Subject: Sundry Cancellation - Sundry # 315-493 KBU 31-18 (PTD 215-024) Guy, Please withdraw the above mentioned sundry. Thank you. Donna flncE�cvz SCANNED JAN 21117: Operations/Regulatory Tech Kenai Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 907.777.8305-Direct 907.777.8310-Fax dambruz@hilcorp.com 1 RBDMS `—AUG 2 5 2016 STATE OF ALASKA AIL OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LI Plug Perforations U Fracture Stimulate ❑ Pull Tubing H Operations shutdown ❑ Performed: Suspend ❑ Perforate El Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Orforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 215-024 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20649-00 7.Property Designation(Lease Number): 8.Well Name and Number: Unit Tract 14(Fee ADL-22330) Kenai Beluga Unit(KBU)31-18 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai Gas Field-Beluga/Upper Tyonek Gas Pool-Tyonek Gas Pool 1 11. Present Well Condition Summary: Total Depth measured 10,010 feet Plugs measured 9,450 feet,,E C E f V Ef''`, true vertical 9,703 feet Junk measured 9,301 (cement) feet �.J JAN 13 2016 Effective Depth measured 9,903 feet Packer measured 5,777 feet true vertical 9,600 feet true vertical 5,657 feet l�/�OGO^ Casing Length Size MD TVD Burst Collapse 4 Structural Conductor 130' 16" 130' 130' Surface 1,476' 10-3/4" 1,476' 1,476' 5,210 psi 2,470 psi Intermediate 6,338' 7-5/8" 6,338' 6,198' 6,890 psi 4,790 psi Production Liner SCANNED AUG 0 2 z016 Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 5" 18#/L-80 9,990'MD 9,684'TVD Packers and SSSV(type,measured and true vertical depth) Swell Pkr;N/A 5,777'MD 5,657'TVD N/A; N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 511 0 0 341 Subsequent to operation: 0 1277 2 0 165 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development M Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑i WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR H 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: 315-421 Contact Taylor Nasse-777-8354 Email tnasse@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature 01/nr:-. Phone 907-777-8405 Date j 1%3/I(p RBDMS LI. JAN 1 9 2016 f 2,-/(0 Form 10-404 Revised 5/2015 j� Submit Original Only • S Hilcorp Alaska, LLC , &„ Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 31-18 50-133-20649-00 215-024 7/15/15 12/17/15 Daily Operations: 07/15/2015-Wednesday Sign in at Office. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 3,500 psi high. RIH w/PLT with spinner and tie into Halliburton CBL log dated 4/8/15.Tools set down at 9,680'. Tried several times to go deeper but could not. Ran up and down logs at 40 fpm, 80 fpm and 120 fpm from 9,680' to 7,200'. Ran 5 min stages between each perf zone. Could not get to bottom on 2 zones which were the D4A and D4B. Ran log flowing with rate between 650k to 720K at 87 to 88 psi. Found Fluid Level at 7,945'. Rig down lubricator and turn well back over to field. Park equipment in field for perf job on KTU 32-07. 08/12/2015-Wednesday Meet at office. Mobe to location and spot equipment. Crane had a pin shear. Wait on crane. Rig up lubricator. Pressure test to 250 psi low and 3,500 psi high. Shut well in. RIH w/2-7/8" x 10' HC Connex, 6 spf, 60 deg phase and tied into Halliburton CBL log dated 4/8/15. Run correlation log and send to town. Got ok to perf. Spot shot from 7,347' to 7,357'. Fired gun with 1,406 psi on tubing. After 5 min pressure was 1,414 psi. POOH. All shots fired. RIH w/2-7/8" x 13' HC Connex, 6 spf, 60 deg phase and tied into Halliburton CBL log dated 4/8/15. Got ok to perf. Spot shot from 7,320' to 7,333'. Bled tubing to 1,331 psi and fired gun.After 5 min pressure was 1,352 psi. POOH. All shots fired. RIH w/2-7/8" x 10' HC Connex, 6 spf, 60 deg phase and tied into Halliburton CBL log dated 4/8/15. Got ok to perf. Spot shot from 7,206' to 7,216'. Bled tubing to 1,326 psi and fired gun. After 5 min pressure was 1,346 psi. POOH. All shots fired. Rig down lubricator and turn well over to field. 08/13/2015-Thursday Meet at office. Mobe to location. Spot equipment and rig up lubricator. PT to 250 low and 3,500 psi. Shut well in. RIH w/4" GR with junk basket and set down at 7,847'. Tools were stuck. Worked tools and pulled free at 2,500 lbs over tool weight. POOH. Will get slickline on it. Rig down lubricator and move over to KBU 11-08Y. 08/15/2015-Saturday Meet at office. Mobe to location. PTW and JSA. Rig up lubricator, PT to 250 psi low and 3,500 psi high. RIG w/3.85" GR and set down at 7,848'. Work thru tight spot a number of times. Went down and tagged fill at 9,638' KB. POOH. Had to spange thru tight spot to come out of hole. RIH w/3.80" swedge and didn't see tight spot at 7,848' KB (due to bevel on swedge. GR had flat shoulder on it). Coming out of hole tools hung up at 102'. Pumped 78 gals methanol down tubing but did not free tools. Closed BOPs and filled lubricator up with methanol and waited 30 min. Dropped methanol down hole and tools came free. Lay lubricator down and check packoff and wire. 08/16/2015 -Sunday Meet at office. Mobe to location. PTW and JSA. Rig up lubricator, PT to 250 psi low and 3,500 psi high.TP- 1,950 psi. RIH w/ 3.71" GR as a dummy and did not have any trouble going thru or coming back up at tight spot at 7,848'. Rig down and move to CLU 4. PTW and JSA. Rig up PESI lubricator, PT to 250 psi low and 3,500 psi high. RIH with 3.71" CIBP and set down at 7,848' KB.Tried different speeds and still could not go thru. Could not get more than 200 lb over pull. POOH. Plug showed a few metal marks on it. Replaced 3-1/8" CCL/GR with 1-11/16" and put centralizer above plug. Went in hole and still could not go thru perfs at 7,848' KB. POOH. Will discuss options on Monday. Rig down lubricator and turn well over to field. • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date • KBU 31-18 50-133-20649-00 215-024 7/15/15 12/17/15 Daily Operations: 09/11/2015- Friday Meet at office. Mobe to location. PTW and JSA. Rig up lubricator.Test tools out on line. Work on test pump.Attempted pressure test and had leak from 3" x 5" x 7" cross over. Changed 0-rings but still leaked. Wait on another cross over to come from SLB shop. Replace X0. Pressure test lubricator to 250 psi low and 3,500 psi high. RIH with posi-set plug and tie into Haliburton Press/Temp log. Had no trouble going thru tight spot at 7,860' tight spot. Run correlation log and send to town. Get ok to set plug at 9,450'. Spot plug and start setting plug. Plug took 20 min to set. TP was 2,070 psi. POOH and everything looked good. MU 2-1/8" x 40' bailer loaded with cement and run in hole. Dump bail cement on top of plug at 9,450'. POOH. Good dump. RIH w/2-1/8" x 40' bailer loaded with cement and dump bail cement on top of plug at 9,450'. POOH. Good dump. Est TOC at 9,440' (10' cement). Did not have any problem going thru tight spot at 7,860' with either run. Rig down lubricator and turn well over to field. Cement in place at 2130 hrs.TP- 2,069.1 psi. Cement samples left at office. 09/14/2015- Monday Meet at office and mobe to location. PTW and ISA. Spot equipment and rig up lubricator. PT lubricator to 250 psi low and 3,500 psi high. RIH with 2-1/4" x 12' DD bailer and set down at 9,438' KB.Spud twice on obstruction at 9,438' KB and didn't make any hole.Acted like hard cement at 9,438' KB and contaminated cement to 9,436' KB. Didn't want to spud very hard or long just in case it was Posiset plug. POOH. Had approx 2.5' of wet to soupy contaminated cement in bailer.There was no metal marks on bottom of bailer. Everything just added up to be top of cement which was estimated to be at 9,440'. Rig down lubricator and turn well over to field. 10/08/2015-Thursday Obtain PTW. Hold safety meeting and discuss job procedures. Lay out containment, spot equipment. Make up 7'gun with 3- 3/8", 6 SPF, 60 degree phasing, 3-1/8" razor charge. Pressure test 250/3,500 psi. RIH with gun#1. Log from 7,500'-6,850'. Send log to town. 1,150 psi SITP. 7.8'from CLL to top shot. Park at 7,184.2' puts shots at 7,192'-7,199'. Shot fired 1,150 psi SITP. No increase from shots. POOH. SITP 1,250 psi. Close swab. Bleed down. Pop off well. Confirm all shots fired. Make up gun#2: 6' 3-3/8", 6 SPF, 60 degree phasing, HC, 3-1/8" razor charge. Open well. RIH. Log correlation pass from 7,370' to 6,855'. CCL to TS 7.8'. PU to 7,126.2' shooting(7,134'-7,140'). Shoot. Pressure increase from 1,350-1,375 psi. POOH. At surface SITP 1,375 psi. All shots confirmed fired. MU gun run#3. 7,115'-7,124'. 9 ft gun. Loaded with 3-3/8", 6 SPF, 60 degree, HC, 3-1/8" razor charge. RIH. Log correlation pass. Send Log to town. CCL to top shot 8.8'. Pulled to 7,106.2' puts guns at 7115'-74124' . Parked. Town approves. Shoot. WHP from 1,400-1,475 psi. POOH. At surface. Confirmed all shots fired. Making up gun run #4. 25' 3-3/8", 6 SPF, 60 degree, HC, 3-1/8" razor charge. RIH. Log correlation pass. Send log to town. CCL to top shot 7.8'. Pick up to 6,995.2' top shot 7,003'-7,028'. Shoot. Shots fired. No increase in pressure. 1,575 psi. POOH. At surface. SITP 1,575 psi. Production prep to flow well. Pop off lubricator. All shots confirmed fired. Rig back for the night. Will flow well and continue perfs tomorrow. • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 31-18 50-133-20649-00 215-024 7/15/15 12/17/15 Daily Operations: 10/09/2015 - Friday Obtain PTW. Hold safety meeting and discuss job procedures. Previous night well flowed at 685K @ 85 psi. Shut in well. Check for fire on tools. Tools check out. Make up 10' 3-3/8", 6 SPF, 60 degree, HC, 3-1/8" razor charge. 950 psi SITP. RIH. Log correlation pass 7,050'-6,300'. Send Log to town. 2 ft off depth. CCL to TS 7.8'. PU to 6,936.2' puts shot at 6,944' - 6,954'. In position. shoot LB-3B. 1,000 psi no change in SITP. POOH. At surface. All shots fired. making up 10' 3-3/8", 6 SPF, 60 degree, HC, 3-1/8" razor charge. RIH. Log correlation pass. Send log to town. Log into position. Log off two feet. Change perf depths. 6,763'-6,773'. CCL to TS 7.8'. PU to 6,755.2 ft. 1,460 psi SITP. Shoot LB-2D SITP from 1,460psi to 1,470 psi. . POOH. At surface. All shots fired. Install 2 ft gun for LB-2C. 6,739'-6,741' 8.5" CCL to TS. RIH. RIH, log correlation pass. Send log to town. Wrong Gun. Called Pollard to make up 10'gun. POOH, break down gun. Rig up 20' gun. 3-3/8" SPF, 60 degree, HC, 3-1/8" razor charge. RIH, log correlation pass. Send log to town. Log on depth . PU to 6,514.2' CCL to top shot 7.8". Puts shots at 6,522'-6,542'. Shot LB-1E. SITP 1,650psi no pressure increase. POOH. All shots confirmed fired. Make up 10' 3-3/8", 6 SPF, 60 degree, HC, 3-1/8" razor charge. RIH. Log correlation pass. Send log into town. 3 ft off. Change perf depth. CCL to top shot 7.8'. PU to 6,728.2' puts shots at 6,736'-6,746'. Shoot LB-2C. 1,700 psi SITP no change. At suface. All shots fired. Making up 14' 3-3/8", 6 SPF, 60 degree, HC, 3-1/8" razor charge. RIH, log correlation pass. Send log to town. Log is on depth. CCL to TS is 7.8'. pick up to 6,444.2 puts shots at 6,452'-6,466'. SITP 1,740 psi. POOH to surface. 1,750 psi SITP. Close well. Rig down Pollard. 12/13/2015-Sunday Rig up slickline. P/T lubricator to 3,500 psi. RIH w/ 10' 2.50" drive down bailer. Tag TD @ 9,349' WLM (9,367' MD). POOH. Bailer full of mud. RIH w/28' 2.5" dump bailer. Tag @ 9,356' WLM. Dump pebbles. Very sticky. POOH. RIH w/28' 2.5" dump bailer.Tag @ 9,350' WLM. POOH. Glass has small plunger hole in it. Did not dump. RIH w/28' 2.5" dump bailer. Tag @ 9,350' WLM. POOH. Same result. C/O bottom shear sub. RIH w/28' 2.5" dump bailer. Tag @ 9,350' WLM. POOH. 5 gallons of pebbles dumped. 12/14/2015 - Monday Rig up slickline. P/T lubricator to 3,500 psi. RIH w/28' 2.5" dump bailer.Tag @ 9,319' WLM. POOH. 5 gallons of pebbles dumped. RIH w/2.70 fluted cent. 1.75" sample bailer. Tag fill @ 9,307' SLM ( 9,325' KB). Mix ten gallons of cement Neo Slurry 17ppg. RIH w/28' 2.5" dump bailer with cement. Tag @ 9,309' WLM (9,327' KB). Dump 5 gallons of cement. POOH. RIH w/28' 2.5" dump bailer with cement. Tag cement @ 9,309'WLM (9,327' KB). Dump 5 gallons of cement. POOH. Rig down. 12/16/2015 -Wednesday Rig up slickline. P/T lubricator to 3,500 psi. RIH w/2.25" Cent, 1.75" Bailer. Tag T/D 9,303' KB (9,285' WLM). Drive bailer 2 feet. Sample of almost set cement. RIH @ 80'/minute. Tag cement @ 9,301' KB. POOH @ 80' minute. Good data. Rig down. 0 • Kenai Gas Field .- n Well: KBU 31-18 SCHEMATIC PTD: 215-024 API: 50-133-20649-00 Hilcorp Alaska,LLC RKB:85' CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" Conductor-Driven 109 X-56 Weld 16" Surf 130' 16" 10 3/4" Surf.Csg 45.5 L-80 BTC 9.95" Surf 1,476' 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 2,805' 7-5/8" Intermediate 29.7 L-80 Hydrill 511 6.875" 2,805' 6,338' TUBING I 5" Production 18 L-80 DWC/C HT 4.276" Surf 9,990' 10-3/4" I JJJGGG OPEN HOLE/CEMENT DETAIL Est TOC-j 142 bbls of 12#lead cement 10-3/4" 3,354' 165BBL's of cement in 13.5"Hole.Returns to Surface 132 BBL of 13.5#IiteCRETE Lead w/1 ppb Cement 7-5/8" 29.7 BBLS of 15.3#tail(No cement to surface,111bbIs losses)of cement in 9-7/8" Hole.TOC 3,354'Calculated 5" 128 BBL's of 15.3#EZ Block cement. 100%returns. TOC 4,239'Calculated .r JEWELRY DETAIL RA TagNo. Depth ID OD Item depths: i ` 7-5/8" 1 18' 4.276" 11.00" Tubing Hanger 6,899' 2 5,777' 4.276" 6.875" 10 ft Swell Packer(Water Swell) / ,+ CBL TOC 3 9,450' Posiset Plug w/10'cement 4,, koi 6,340' 7,224' PERFORATION DETAIL 7,513' LB6 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date Size Status LB6B LB-1C 6,452' 6,466' 6,309' 6,322' 10/09/2015 3-3/8" Open 73-1 LB-1E _ 6,522' 6,542' 6,376' 6,396' 10/09/2015 3-3/8" Open 73-2 LB-2C 6,736' 6,746' 6,582' 6,592' 10/09/2015 3-3/8" Open ISM UT1B LB-2D 6,764' 6,773' 6,608' 6,618' 10/09/2015 3-3/8" Open 7,841' 1 LB-3B 6,944' 6,954' 6,783' 6,793' 10/09/2015 3-3/8" Open 75-8 LB-3C 7,003' 7,028' 6,840' 6,864' 10/08/2015 3-3/8" Open Nry 76-7 LB-4B 7,115' 7,124' 6,948' 6,957' 10/08/2015 f 3-3/8" Open 8,126' LB-4B 7,134' 7,140' 6,966' 6,972' 10/08/2015;/ 3-3/8" Open M fr. LB-4C 7,192' 7,199' 7,022' 7,029' 10/08/20157 3-3/8" Open 8,450' LB-4D 7,206' 7,216' 7,036' 7,045' 08/12/2015 3-3/8" Open LB-58 7,320' 7,333' 7,145' 7,158' 08/12/2015 2-7/8" Open LB-58 7,347' 7,357' 7,171 7,181 08/12/2015 2-7/8" Open 8,739' LB6 7,400' 7,420' 7,222' 7,241' 07/09/2015 2-7/8" Open `" 84-6 LB6B 7,482' 7,492' 7,300 7,310 07/09/2015 2-7/8" Open 73-1 7,555' 7,562' 7,369' 7,376' 06/29/2015 2-7/8" Open 84-6 73-2 7,594' 7,611' 7,406' 7,423' 06/29/2015 2-7/8" Open UT1B 7,741' 7,752' 7,546' 7,557' 06/23/2015 3-3/8" Open TOC @ 86-2 75 8 7,843' 7,850' 7,643' 7,649 06/23/2015 3-3/8" Open 9,301' II 76-7 7,938' 7,950' 7,733' 7,744' 06/23/2015 3-3/8" Open l a D-1 84 6 8,773' 8,785' 8,524' 8,536' 05/15/2015 2-7/8" Open /9,231' Jam'"i 84-6 8,821' 8,841' 8,570' 8,588' 05/15/2015 2-7/8" Open // ~�'� 86-2 8,975' 9,000' 8,715' 8,739' 05/15/2015 2-7/8" Open tirtirtirtiftif�� -2 ' yasslw D-1 9,124' 9,144' 8,856' 8,875' 05/14/2015 2-7/8" Open ' '- 3 / D-2 9,337' 9,351' 9,058' 9,072' 04/25/2015 2-7/8" Isolated ""' D-3B / D-3B 9,585' 9,611' 9,295' 9,320' 04/15/2015 3-1/2" Isolated i D-4A 9,766' 9,785' 9,468' 9,487' 04/25/2015 2-7/8" Isolated "1'" D-4A D-4B 9,800' 9,815' 9,501' 9,515' 04/24/2015 2-7/8" Isolated e,r. sI w D-4B 5" p.- :1 PBTD=9,903' MD/9,600'TVD TD=10,010' MD/9,703'ND Downhole Revised 7/9/15 Updated by DMA 01-12-16 • STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT_ _ la.Test: U Initial Li Annual U St Special lb.Type Test: abilized U Non Stabilized ❑Multipoint Q Constant Time ❑Isochronal D Other: Nodal 2.Operator Name: 5.Date Completed: 11.Permit to Drill Number: Hilcorp Alaska,LLC 5/15/2015 215-024 3.Address: 6.Date TD Reached: 12.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 3/31/2015 50-133-20649-00 4a.Location of Well(Governmental Section): 7.KB Elevation above MSL(feet): 13.Well Name and Number: Surface: 413'FEL,707'FNL,Sec 18,T4N,R11W,SM,AK 85' Kenai Beluga Unit(KBU)31-18 Top of Productive Horizon: 8.Plug Back Depth(MD+TVD): 14.Field/Pool(s): 593'FNL,2166'FEL.Sec 18,T4N,R11W,SM,AK 9,903'MD/9,600'TVD Kenai Gas Field Total Depth: 9.Total Depth(MD+ND): Beluga/Upper Tyonek Gas Pool 387'FNL,2466'FEL,Sec 18,T4N,R11W,SM,AK 10,010'MD/9,703'ND Tyonek Gas Pool 1 4b.Location of Well(State Base Plane Coordinates NAD 27): 10.Land Use Permit: 15.Property Designation: Surface: x- 275392 y- 2356026 Zone- 4 N/A Unit Tract 14(Fee Lease ADL-22330) TPI: x- 273688.4 y- 2356050 Zone- 4 16.Type of Completion(Describe): Total Depth: x- 273391.68 y- 2356261.87 Zone- 4 7-5/8"Production String,Perforated 17.Casing Size Weight per foot,lb. I.D.in inches Set at ft. 19.Perforations: From To 10-3/4" 45.5// 1,476' 8,773'-8,785' 18.Tubing Size Weight per foot,lb. I.D.in inches Set at ft. 8,821'-8,841' 5" 18N 4.276" 9,990' 8,975'-9,000' 9,124'-9,144' h� 9,337'-9,351' scow JAN 2 Q '�U' 9,585'-9,611' 9,766'-9,785' 9,800'-9,815' 20.Packer set at ft: 21.GOR cflbbl: 22.API Liquid Hydrocardbons: 23.Specific Gravity Flowing Fluid(G): 5,777' N/A N/A N/A 24a.Producing through: 24b.Reservoir Temp: 24c.Reservoir Pressure: 24d.Barometric Pressure(Pa): Q Tubing ❑ Casing 125 F° 3192 psia @ Datum 7093 TVDSS 14.7 psia 25.Length of Flow Channel(L): Vertical Depth(H): Gg: %CO2: %N2: %H2S: Prover: Meter Run: Taps: N/A N/A 0.56 0.26 0.37 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice psig Hw F° psig F° psig F° Hr. Size(in.) Size(in.) 1. X 24 2. X 3. X 4, X 5. X Basic Coefficient Flow Temp. Super Comp. Pressure Gravity Factor Rate of Flow No. (24-Hour) hwPm Pm Factor F Factor Q,Mcfd Fb or Fp Ft g Fpv 1. 1281 860 2. 986 926 3. 687 976 4. 292 1010 5. Temperature for Separator for Flowing No. PrT Tr z Gas Fluid Gg G 1. 0.892 . 2. 0.912 3. 0.936 Critical Pressure 673 4. 0.971 Critical Temperature 345 5. Form 10-421 Rev. 7/2009 CONTINUED ON REVERSE SIDE Submit In Duplicate Pc 2 • Pc S f 3192 pe 10188864 No. Pt Pt2 Pc2-Pt2 Pw Pw2 Pc2-Pw2 Ps Ps2 Pf-Ps2 1. 1281 1640961 8547903 2, 986 972196 9216668 3. 687 471969 9716895 4. 292 85264 10103600 5. 25. AOF(Mcfd) 1,028 n 1 Remarks: I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed . Title Reservoir Engineer Date /.2/41// DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producin face were reduced to zero psia Fb Basic orifice factor Mcfd/ Pm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= 1WZ dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas (air=1.00), dimensionless GOR Gas-oil ratio, cu, ft. of gas(14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet(TVD) L Length of flow channel, feet(MD) n Exponent(slope)of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back-Pressure Testing of Gas Welts, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10.421 Revised 7/2009 Side 2 • i • YUYYani;;>>Ya»rV4nnn»»n» TET TY»»YY>Y»)Y>»»> >YYYYY»»»> »»}> vn Jj4 -' a., m nonan r.YnnrvNma 'J omanDHm ✓u vm^nra'a Hnwa9 e`T'u �n.N.,�n'n.Ho o3"'ti:rnorvavvvo � -e$rrrw.nr$."orvono3.rYuw `y` $Ax HelNrvrvmm�mm •�x� .... ,�abY; .Y,Ya.Yaa -%>�+ rvan :. «rmaraaraase..i:i rio if' a r.=�:�iO-�:a,=�,=nnIn HHHHHHHHH 1,4, €2;22;212;12222€g228 04, ggg2g221:8$2222gg0gg £� WALL LL y w VV ♦ m HHH+N�Nn nwiH a.HV O+Owaw�H Y c� $$$NTmn10Nmorai��Nn.abMN.Oio 1.M"Y 000wa�+`o.vgmrvaD'H..mr..itU .cN»Y Do9ndnn.+a�:a:� '" m.i.-aM I 4d r"'$$'m' iTo9 ooeood� 5 Ooc 400eO p .O.o $0$$$ .O Vyg 898$$$$O$Sdd pm $90 •000000000 O Z by •O 000000000000 non SSSS 2=Ig..n rHrmnm•�narA nN �n Ynihn3 on e o nvncvvni��n$��(:g�n�oa$rana« iui SOOOO.iArN3 .',m$$ "'.:.na nn'no Twp 000u.3.nimi.f4o,:m.SAA ay.r D m$m4m sl.ts+ BEU.4o'an$n E.in,R Nn -'-'4.— rn.:iwavmaroNramc�n.,'vRNea'wna Tcu�'� no'R$.:r:»:330'"'"0�°o8or.:e:r:i. » . Sen p°^"e^me^�^aYn°�pS�ANw:e 2or,C SDD 9e...ao3SSS gw e e a .Y.Yre e�� i "17 MillUnii&ingniTa —.4s 'liniltai7IFia-E5F1Fa I: n, ..;:wwun.;.: .oa,4ag °2 000O.i.+.i.ir,;rir;..m..;,4avvr.•; Ng>:Y .1'' >v O 4'^ .neowoamr:OnOmmm.i.an ^ •a 'o oo n°ava vrmNva 48urit .H0 d3'- nn ,�o: vn nn nau =.4a .= sr A PNndnEi °Y yveMN —d `4. �GgaOn:':,:d64 yr "rgna,' mrndm -" ' dddo0o00 AA9 nnmrHnMar w orr.ia3mm niN:unTbNvrnmo i ma3roa.aHaemanernioo qc4 •µtat 9m7; Eili r:::::::::::::::::::: N:.. .. Y ::::::::::::::::::::ao $."0 $$$$$$$uueeuueuuu$dm 14' $$$$$$$.HY."Yueee.Na.NYu.== A. pa d$$$$$$$$$$$$$$$$$$$ 1E—a $$$$$$$$$$ $$$$$$ $$ 74.WA OOOOOaaRUM, = a oaoO000Osss$ U s$$ 3u▪ .iHHH:i.0a�.1Di:i D1.01.0i.0-1.O-IN.Oi.0i.0i.0i nnnnnMn n NV"' Ni0000000000000000000 00000000000000000000 FN h 90000000000000000000 00080000000900094000 *FC oc Gi▪t Ga u b0D00004000000o OTTT O ,...=5.8'n»» 3 bbDee �qqq =Mall 66 DD999dd9d9d999999Ded Gr nn nw.,.N;aaaa rr U�� rU? F,MtVV0 , rEG aEti o Odd HOanrnh 00TYanNnn 0 �r s H N 0000909949000000000 t qb 0009000000040000000 �OH N " iDO♦z0 na�M�oV mem. H V O EV .,°-, a4"OO b O .� O po =1 t11 C 00409090499900000000 t1�- Cv 00900044040000066000 ni o, I;! 8 7gµaµcOµ OPOI "tti O!"1" �Mµ�4 „.r 40499490000080004990 ✓ ° tea Twu ae'»»»uLGun'unu,- i O +Gi V.�. OOgcngcc CtlOq»YY Ur-.-4 VYtYYGUrr-LL ctic M4 /H.9i Vin m 3�M�:.0 VAaO O«Ox»n>]NI-d tlOOnn>Y YNiba p�T Yah M� 11Cp1 ting OO sO. 03,bbppV IYO-W7 ti5 gv1Dgnri=i q.. al-Nv4 ni ��r-. vP.ain YO.a OnnrvrvOpn Mane e"Y9ry v in 0-.WIL.Mr:3 pn Vr V r 3r v .. .... ,0 3uLY 38; n » Sa��.XX$n�.�edM:,6ma" yrC}r' gn Q�J$� •e�N9mgg v "8 er Mr-g-1gE malty$ 'I gnu :4j$:I aregaNumn V F i U N 4 nmM rvnHNNNNNeine v`.°aO N ro,J yj rcr,YEJ2Cj Z O ,...,m,,,,,,..-,,,......-." °M°NawaHomnwvN M �v HHHHHH F wry tr�U"3 i3rOMY2 q,�L ccc �� On v4 V Hwo Si^UL " g!e-suzi».. r -g Y_ nwaeNaivamrva:,AAA:nooarvr 7i p °bOv inMq��neorvn < g rog'ti M-'tn g u g_ .1D n ,:' " e""ir::t,taa /61 h Minanaarwrvcannnrinn 1 $ W LLLLVY e" �6v nM,rnYnm..aCC mm3a"�nnnnmon ��a Ov Nwa a O aY yp N LL mM Hra ra yid" -if n qo aYmrvnwnNH�ma Yg ♦1♦ c m n Hvbm b e�*1H HnN�ra Nam nMN�i� yr n aNO�HMri.min n.inTnnnn�Y� LI. dr99"g9O�Dooa"��Dinao" � Y aa�� d�� ?b°�" o�" 09440 ur 32r $O,;000oadaoa99990dO T wroorN.Yi a+arvnnrninnnanmvn u n mnn ne•He N q v Oordaai n orN$oni.H* q o H rwi�VartNnein.r.mi.`O�go 35v90000000 00000000 0 aft 00000000ddd0000000 D" • • jj� E�d\ N,;,;,;.4.44, 4.4 ,-; .+-.f1Ya""r"w"i.Wi. NN"�VVbV bIgiiE �.r-al.i,irvielr-�IA.1.r..r..rvl rrvl„Nr,.ri4 r.;r ::222242241221€4224$ e� ug i▪n% '$� 000000000 0000 0000 Lb. ebb. $ii$o5emN r.��a • 0.,;,ic ”"«,;4 , ...;i ' MY .eigrvn.'.inonemnILIE 2rej ••Y{Y`gl 1.im d.Nirvi t'�NN:nmg.n.4.444NM' 4141 nnnnmmm�mmm mn=== yjvj "M b n"M"n M O.0 M"m m M"c.n 'P,RY� A :eb.4KMo�Aag P o? 8.,0ooaoti .i.i""ririr.rvrvrvm 1-• 8 u` n:a g„... rni.°-immmarvor'a Y00oo0ooaoo a.1.a r.;,1 v�nco 8 hk, 8888888aadjajun a2 LL04,4 & N F nn 0.lnmbnm.nlH g8s1V.n.+h Wo RN4 VbbbbObi.ibb.i bihbbVrybVbd1 .8 b ip RE- 8888888888888888888S ."� 88888888888888888888 "ate ryc 00000000000000000000 FN Fc 0000av v0000000000000 v4 VV tN „ »» »» '`'`'`il?iii_ ^^88 u 8 =4st= P. g 00ooe000000000000000 "'n '�^88�u € ..^^88 v zP MM ate€ eaeo8NA" €.-a�00000ea sl<3"sc. p? 9��.0r88a o Mr.239�eeeeee�mYR"Mb 00 w gg 8 eeeeeeeeeoeeeeooaaea moeeeee N rom$ S "PM a" 0o e n .-A.ioo.0.:0 8e.ingo",..0,'.0 P "" "�p"".„;a "u .iwo ,,X, bo 08 o e8 o ee 18 o S o } 0 0 0 t4+ c 00000000000000000000 0 24 uuuuuc>ccueeeii4PlAb4ri . S SSeSA�`eooe��ALD�ApvyYZLLrr«oo .y yy N° °HN � VV e n ei°i" Sir.. fi M- NNNN• F! W y �ef�a� ri G ioYinny .'in.'.''jj��77��Vr.4✓ O _ YN'>NVi'MNliEgV VVVN -� V _LL tss Ez-gE S n OOo00oo0000000000000 _ G.. 6b _OOnC FSV.O1.O- E 8S t0 O�cO�mc�M��acgrtCCVV '0e�p �•oeooNNu r-suSBNN>>-_..0 8. -,7Aa Y'•u` ` 1 .a - $ �ov�au $ � >�'ry >u>r+ 0 8 �'ovo,ao Nw°.a �aN 3' ., 9�-0.Y VV,......ss.. a OM1"V%l yNow (tJ Sitt Vtev „ q „p0b,1Z "� .� a § beFFB Y�3�..� R^ r'3oy9M fa. 3a�a 'a 'a Go r 'a• pp p �3'Q8$e$4 OA p n aea♦:�«amnion HMH."..ir;.'..po�.WoW.mnnitne��ao°. � 8 o' vv�v.L`yuf,cpSu$ a�iYYn N s rob R..1.,.—,—. 2nOa4PLV2 E IL4¢ nnr(e0.Ntry H«Hrvry Orlrlriai.r04, H e S v � 7ViM3.�V s7VM • " g s ' e-"ova s " 5.1 s�i$B�T,4doirvp4a�ni � 3 g su - w �s y .MM:,9aWiNa�s�rvs- ” P r 4:0 " .«' ab na"Y Yrve a- r4 A u� a b:ar Y;»��R� b t. �, a. rc 3 � $$"a�oaooe eeeeeoea e ; " rvabmr.n"nw"vbmv.rn LL u" 'C 80000000eo'000aoeeeo" ms s • g >»»»»»»»»>;; 7 n0 �t«tl POONNf NNfnninnlil MMM 1140x NOHrOiNMMMNNrOioioi.Oio-IN a.Ot.01.1 ~�. 2222222222221221;111 1ry h0� gr HHocO`.nMNHNq'"m"HVNN� 1. 1 aaHEFARNREE t f 000§§§§ss$sss8800000 "iiBMt` :te'rron�0 � e�m��m ss e�.ie,H��Npp ■VO NriM Nnmo== taus:m iNObgOHm $ 80do0o4r4r,Nr;.;M m000mmmM 5o� £as'.82v1�.8'0^+.^•�"..o'n.oPB.iN.. 74. 41k mHtleHHror.novNeO2 2S?vONmnm8 N38M1113N b r I2.4 8000 0000 Sa .aH HHHHHHrrry N.-. g&Ingg=2R.rnihri'.pnroi.M1i.n 3=81a,mmnnn m m 'm$cninanoe+�:na yyC pmpgµqN O �obb eiH riH.i LVa ry.iNOOo00 00 00 HhN!,1 7-1 g1=gmgi eem>ee bepe pNp HNVmnmoNa.n b0 rib P ton+tiffi�a1°�e�o^$� ^dao s0000 ori.ir:.ari.ir;.vrirur.r.�i 0b mmmm�mmmmmmmmmmmmmm r$� 088888888888888888 XP.« eoeee88Nt%N '8888888 �n9 nnnnnnnnnnnnnnnnnnn 00000000000000000000 4 Fc g n..00000000008000.04 000000.0000000000000 22—. Mggtl` 5 ..""8888 S ` d eo P....-...,-. CY3CCw s" o ?? r�8 3 .i0.i.-rm ri000000�� i eeo0000000000000000 0 2NN2•nr4g.$`rt4 oN'. $� 0 00H m 0o8H0 g !dri3 .o H0 R 09 00 }it) 8 00000000000000000000 0000000000eoee000000 diHf«` VV aoo o4 a"ncc000acai « O VAN "�6��TOW�O rOrOOxM�� F-p 80.+"a« Fa OOY6 a l]O«a0.Y « - »N : »N x. -Yna g" c 2� of v 'g7=�q1 U 9> r 8 x�r Om tlVmYrtHNO.rrro nH meo o �0 2 7VV"r 2FQ� F c. r:''IOhmNNoom.�m 1T1 v i3 0 r Ab TIB .•nem mm..�NmNb�N�Ne� � � � �� q3�f�� i'8l„R�' 8 Y: SrH4rti «�Ntlm.��HH.tliNi.O•f` ossa Yu Y+: yX "w $lawwF4 o Sn 333====22155,13 • 0 � f8 y 1"rX L 7,1♦ q«onNnHIlmW l41 $1 0O000 vIO tl.0"p. a,.1+mpiap NNyn .M�t{npii Mw�l HOHNN rN+TVtlNNV��OHV PH OaV 80000000000000000 0 i 2 0 12/17/2015 KBU 31-18 AOGCC 10-421 Submitted 12-17-15[015-024] KBU 31-18 AOGCC 10-421 Submitted 12-17-15 [PTD 215-024] Donna Ambruz [dambruz@hilcorp.com] Sent: Thursday, December 17, 2015 10:33 AM To: AOGCC Reporting (DOA sponsored) Cc: Jeremy Mardambek [jmardambek@hilcorp.com]; Chad Helgeson [chelgeson@hilcorp.com]; Larry Greenstein [I greenstei n@hi lcorp.com] Attachments:KBU 31-18 AOGCC 10-421 Sub—l.pdf (971 KB) FYI — Per AOGCC Industry Guidance Bulletin 15-001 dated October 2, 2015: ...Effective immediately all forms listed above [10-421 (Gas Well Open Flow Potential Test Report)] and any correspondence related to these forms should be submitted to the following email: aogcc.reporting(Walaska.gov... Please see the attached 10-421 (Gas Well Open Flow Potential Test Report) for KBU 31-18 [PTD 215-024]. Thank you. Donna Ambruz Operations/Regulatory Tech Kenai Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 907.777.8305- Direct 907.777.8310- Fax dambruz@hilcorp.com https://webm ai la.alaska.gov/owa/?ae=Item&t=IPM.Note&id=RgAAAABKLne2zgP4SoM kepOhCxbSBwBUvQ964rjQTgYgn3632GdIAAAAhhLyAABUvQ964rj QT... 1/1 • Seth Nolan Hilcorp Alaska, LLC II GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 DATA LOGGED t2ig/201 Itukrurit %Li&i.1,11, Fax: 907 777-8510 M.K.BENDER E-mail: snolan@hilcorp.com DATE 12/04/2015 )- 15 0 d� . To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL RECEIVED -'DEC 0 4 20,IS KDU 10 and KBU 31-18 rO GCC PLT data and print Prints: i Production Profile (KDU 10) Production Log (KBU 31-18) SCANNED MAY 0 2 2096 CD1: PLT data 2 1 4 0 6 2 2 6 5 1 4 . DLIS DATA 12/4/2015 2:42 PM File folder . LAS DATA 12/4/2015 2:42 PM File folder ► , Log DATA 12/4/2015 2:42 PM File folder CD2: PLT data 2 1 5 0 2 4 2 6 5 1 5 . 11102015 1740360 PM File folder i corp_KBU31-18 151UL2015 PPROF Fie... 7/17/2015 11:34 AM Adobe Acrobat D.., 6,373 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Receive c,/, 6 Date: .._ ................... 0 ........,.... ---• .,... 3 i-/ 0 .....-- . -... K61 ....„ 8 ... -7 %,._,'' - 0 •• fiD1• ----....--6 C,,_ k • 6 _______waim,,.....4,,_ ,>-1 fiiiiiiiiirliniorr,a,. . ..111v44 • '000°I.I•I 1111 ; , : i ., .108'4- 9 il.k cr- JA.--- . .,..,,,..„---, ,•••• _.4.---4------- r , -.... ,..... ,.....x.„..... • . . „ ,,,),.. /S7 /.2)6--.1/./577-.. .,;=-;r>/:V-,,,,,,----' . ----,-___ -; : ; — ,7-----/-, . -- -., -'.. :•,. .,., . " 7 -„-,\--, - -, .,-------.:-.r. ..00 -. , _1,-----1 ,• • -.72 ---- ---------- . C 5 A- i.....----i-____4---, , i "',.'"•••:•‘:. .s.....;,,>, ''s. ' -.......::,,,(:•., •,....N., -,.,•, i/7..",,'/ .,'/.•••'A. „,'r.'''....`.. ...''',..:„.,..,...-.\ .,..----- ------- __,..___. i_____ . .- ,z1"--7----._ ...,*„...4•,,,',.:•.Nz2-,,'"o\ .,...'s,\`• /.' ' ,'..'.A., .• ,,,/ // ,- •7',:r'.. - . .,- -----r. : : t------7---,--7----f-•'T LZI-l---......, - ''b' •'/i ''/..\." ,/X, -/ '';;,-:,--. ' • -N '.: / ..!.-/X":3 i i i • .' r.//..,:'.,-'/ .'V.:: •,...- Ca":"25":11_-1.__,. 48•-i-414'1' f. .• -•-•,,Z,C• '. "*;-:••`,.`,. ' \\,...x.,,, *----...<,.:',,,,76-„,-..:.'•<' ' sx-s. \\'''.:' : , Z----7L---.4..___ .',,..•-:.4..,'"•,.WO•-.*...` sx- `•s• '•): . , /,-...,'..:',,,/ii/')s,/40 • i .*':.'./:••• .' 7 ..7„:".--. :„...- o'')...---r---; " 41 ----1------: . f ! ,g„,„ . , ---....., ..., ,..;•.,,.•.,•.,,,4; /:.::.• • ' 7.,, • . •/„ // A., i,\••,'..,'. ...,,,,,,,,,,,... ,a , cc„....-7--',,,- , : 36 i •----/---..-4 -3,4.........--‹7 ••;-- -, \. A2 ,/,..,./.,/,• ,,•:. ,: ,. ", • / :•-•,, , . ., •-•,.. - ,..••,. ...-c 0....--f ! . -•-7-.4— ; • .---. Cio‘ '..3.:,e.',\„‘>.:\•,\ \ 1:/,.:',. .X„,..'..././. ,/,.,.,, ,(9,"; •// '.)4•4'/,/c../:,rx;' ,./..,- • ...---,•,_,...k .._-i--!---777 ,4-- ..._. ..T.:•>•Z:,.,„• c,..@,•'•,,•'- ' X•;‘,\ \ \\/7 \'‘,./•/,4'!../.."/ ''','/".. .. - vi • / A.',/,' V.::•\:---,":-.N.Y.- 2----- • . -4-------' - •"94.....". .4(/\N••:"..\\..". ' \\,:\ .•\. I/I.%•'./,'"/:?•-•• '•/)(,••.1.' \4\„//"A',..'),V.,•/:,,-•7\-,01P"' , ; -•"' ; 24- . .. ; . . . ,„... ,.. • , .. \ •. ••• ' • , ‘, -...•<-• ••-\ • - •••,,,...> f:... :'•••,,,/..., :./..,•...//,.//,,,.:,./,.,;51.,,,/,:(,,,cc? .,' •••\.,,,•xic),,,T,../...„.,,,,,.;-;...).F)"., .--7.,..c t....- , .1:2_ P-7----i. ---,,,,,„. „,..',"-._x•-•:„\z/,`.,-,; :,.' \ ,,'•<\- \ \ / : : • • , /-f„.•; .:i.,. .. , ;,••,....,,:,..":,."\::.//i.., „ (xi., , .'(x• ,-„,-:--- '. .--. ' % ', ! - -f-- --;'---•' ' .:4,•,` „•::, ••\\•Kiliw ,\\..\",<\\L.,,,..\-s-s l:,..",\.::./.'i i'il-,*:,:...,;/ "./:' ,/-"/"//:.';'''veP''' s>•(,/,,./,'<.<:.>". -,1,- -';,,,..ii.. d;iti&ii ' ! ' 1.-- ' ' r ''. ° ''''''.•''',?C‘';,' .s'. '\:,-- \...p,- \\\-- /„.:,:,,.,,st..// ./.'S.:!!1';`•-i;.; ,!,..iYc'/./..,'/•,,c0'..., . "...7'Ci:; : f'''": i i ': • I'ic;`,'••//N.1.-:`•/ • . ''''c/\;> '- •.'..<"-.),.<-'-1 -...„N„-, -x,',‘„ -‹ ,,,,..‘„c,0,-. , • , ip j ,-•••••„:..' . ,.‘„.• ,,i-,/,,,J,..,; . ••.• ,r ...,„.•...- •-,c;.1;•-..it„ 7 /-;,•x', ..v-- 1 • ,i I:-I:': •-,-„,:. , : . !i••:',f '.'i/ c''';'<./.'. f.:.•''•/././. / : .. .i. ••• • .,./>.- ' : . . . • . .--..: . c 1 i •.:'-',c r • ; 1,-;.; . . •dit ,r'''', I.,./i,"!if i'`.,-*.._,:,i ri s 7'hci,,Li/7--?.,&,(../1 ' ' 'I °" : '''' .),r,y`." ** } "tu- '' -1* :4 .r., ••..›: 1.--,, . ..., ,.A.\ ,..•2v_ .,\\\.,\ :1:••• -f i i./:';'-'. ..1_1//i t•if,U I/1`,:•-;...4/; :'.'//77'.--.1.„(>,,';‘,... ,' 1 It 4....4..3i,\O 1,,t. • ., s Nr. i\------r ....1,4\-,--,.•*-Tiri ! : :.8,' : !I i i i>;.-Ii....J i i 1.7--,'--Li i i-/--;‹,'c •'i l;1,17.5,/,,.c'':' 1 licsZ 1 '4$ liec % 0 ,),--Itrk:Ac.\.,',\ I. \ %', ', \\i't,t • ...,„,%., , ic. i ' , , , - . ' ! i,, i , ,' i,. i , --•'--4.4." i • •--",.!:i i : ,.'7.--.<7 ,.s I 7, c,4 ,, .:,,r--, ,, , ••+.,„_;,,_,...1 . 1111 if if'f,:i...1 :•••,.x.....; i.,Si 1 : ;;. : i f..,*)(0.s,s," ' '1/-..--,<I",-,‘--,•f-•!...;i :' '71g \ li •,: * ,...`1,<4 :•‘,4.107,--r-t-r".\y\‘ „.t,.:•,,‘\,;1,\___,_1,';'it.. I 7.-.....,,;,• i • ; : ! ; ; :-.7---;,..! ; c., ; i , , ' ' , • . .....,e I cf ! !i i I:-"- -..:',i ,...7"1,...LI qt. : i-i-f-2.-4.._L; : '''N! !"-..--..S.L.',.! :e 1 : ' : 1 • • ; : ; i : '! '77-!--t- Agei og I \ • , --..gc' 1 , '3, .H.--H-t ,--• ••..... : : ! , ..!•H .-7-, !..._:,:c4: : : ; i • ! , : ! : : : ,7--,--..-4..: .,- ;A4 i -f---L,.._. .1 !,61: .-t-,--r+-L-1_, , , vi c9, rt : : ; : : . ;7-1--:-.4-.L..0 ,-,-! u ,o) i no . h;<-5-rt-H, t..: ti i .e- LJ.4i " • to ! j lor-rm 1 1, vi• c., ,,,t.,--hp-i,-i-- i.j i;;.4.. f3.1eit, i 1 • ! ! I 1,--1--,---14-w . i ! i i i . . :Th--.--,-v+ 1),+--- d- 412 '....____J VI\ "' .2 1-5-f: ilMil ! 1 ! ' • i , t '. ! !--;-t-H--:,--;-__ _Ciii , I i , t ,,±,r2.7Jr3:.(,)i,..,• a i')'t 4 ,., . . .. . .. , , , , „; . . , , , i . . . . . 0 1, .:'7.;::.1. ,:,,.,t,!,.,:k,.1:,..LLI.,;k i!:1,jr ,li.•,:•,r,,'.:,.\:,i !',;•1 'k fk 1k''‘, :\ l:..'•.:11'' '''•'‘90s \ k ! H ' • , :7-1•",•'',-,-•r-L.-k.2,..,..• , I , . k ' ! . t 1\! ! ! ! 1.„i.....*•-et-, I 1_,...3.3-.:r•-',""r‘Sill‘ ',=-4.--.2,2 i k ; •; .', k k '; \ k k\1', k \ „k, k k '. 1 : k k•, ! k k ! t t ..\ k '. ‘ \ \\ '• '.\1\'_,------",\' \.',',.\,---'7,-r.\.__-.,\'. \',.....--\C,.:,:k\;), ick , 1 1 • et ', Ili Qi jit 1 ‘-iL,_Lli.i '' \_12Li•4•. '4.4-: #-:777-\:.\\\"\-17,-\:\: -\‘-c-c..4,-\-\(''''')<-\ Pk ' 1 ' ..1.1141 2 \ k ,...,\',,,1\ \, ,,,\\\ \\\\\\\.,.\',.1 ' ,,m3.1.-v.',,..:--c•\dl.,•<\,,. .`,:c's. \••••,.._ ,.,... ., 7,..c. i . •i/ P-1--,"/ ; 1.•••'-`' .P.,:t i/, •i i i•s-1.,1 1 ; i;-' 1 1 % /,/// •A7,,,', ''';‘1,1•?'sf:.,.4.f i„" '••2` A/N.:AK• •X I A Ni i 7,1 1 I i 1 i, Ir. -.-4 os S ,,,,x, / / , i-v •• 04 1 ., ' ' ,..' .• ' , V• '.4.'`xi./,:'7•: i, i• //I. \ \-,. \\ , ,,.,%, ., \ , ', .,,, ',,%,',..::.,_;__\-",-',--'-.;•6'3436,,..,„<r^. •::.‘„1,..,...,,..c‘i\\.s.r:\‘.,... ', ,.,,....„ 0: '‘.. • ' ' P. ril ' ' ' , , " " ', ' '.. ...L. -4-•, ---.-'-', • ' rIl. - \' \-9, ,.\ , • A:•' \,' ,•• I \-13 ,'' „,/25 crk i7'' ''''''`.-t . • %•. ' ' '.',\ ',..\\ .3,,j,l,,..1/4.-c-reg\...,›\co\\:. sec,,, • --- ,-, .-ez,--- .. . 6 ,-\ ,..,c\\ • •• •:- • \ ),‘4),. >&. i --, ' -7--------, i 4.pi. ' ' - - :s /,,/ /Au,' . . (c,,,,c„\\ \\_, •\\\.‘. •,..-.,:,,,?(.. 0, ‹.• / i ; -,:,,,•),),,., ,-,/-,,.-›-&<\4—,,...,,,,/,-/xi,,,,;(,,,,,/, ..\-c\ .\>(.,. ,e,•'s),--)--ee ' -----./---4...--..- -7---i- CI, \\:\\'‘::' ,V1,.. --c-':, ‘..'\\\\Vac\,7 \\.>>': V sy>\: Z,<:\x" ' '-'-.::4-'.---/ ii...__•wiwaisi z I-; 00.0207,.1 ." '' // /.'''' /,'co/i. . ,;\:\\ .9>',. \\.\\\\\''..V. -,;--\\,,,,\:`,.\\,-'• \\0, ',.,\\„•.. ., ,z , asitlft, f • iiroomiiiiiiiIIIII.S.1011 ..A!:' ...•,,,,/2\ /X?) \ \ \‘••\, c.-'c.•,,•:\'..\ \ \ \\' N.'.. .'•• IF ..... .....7."'"--,_,/ 1 'IYZ /11101011. *..)••'' , '/A/ NO. '.0•• i•/,, / i /jiNff /• •.,,:,..cic-•:;\\\ \\ .,\ •\ \\ \\;\ \ \ \,.. ..6.<\• e.,,,,: ..z„------,-___ , _,./3 :,,,. ,,,,, ,,,,, ",, / \\\\\ \ •. ...\\,. --\\, -,,,,,,`),,--',?) ••••!,-,,,. 4.„., — - . --/ • \\,;\ ',..• \s\, \• ,\ \\ •'•• . -\••••••- •o-,-,---:;:s.---..., .' --7----17711111111111a1011. ..---1) °°(.'. 400 ,.•';', /' ',".., -,' // ,,././''•-''/ \ , -''\ \\ \\. . \•...?" .• 7."---,4-___, . Dia 111.1111111111111111111•01114 ',13 OC:02" V.)\,%'' / .\ .. ,„\\ ,..... ..„ ..,,,,,,,. .,-...- . , -; '-'• \'''\1\ \\\\. \\\\,k's'. \\• Cti.A .`,'''Ne... ......,.. .4-•-•...../.... ...4 ( „........ ......111IiialMIN I \\\s's \,X:\‘: -',N.•••,...Oe):-.:,.. ...)-:, •-• --. 0r7lia.. -1 09' ,' sr,,Filo" -.6•60 • 7- .4r>/' ; ';\\\ " ' s',‘4. ' •••'N,`-le•-:',e',;-/- ' 01011.11 .10101° _di .---7Z .;--• • ''‘,:>•:>'•:••\- s'•''' • -C.I7A<'...."•:'''':"'. 411111411111111.1111111111.— . - 111011111.1.010 ...saf0011111,"? .11.- %.,,,"-.• Z.-/ ,.. -„,x--.....„ ..,.:::,..,,,xe*•...'"•,•(•..:\, '-'0411aftirif aisiosillillw"-, cp.,..„.....,..k.-‹*--;--., ..." .,KA., \ -, .;,,06i-. •;.,..,.'•N.:, '''',..,`-..".,-..."---,. . ••.2.,..--,,N..4'..,.... .../., ',...Z••• . , „. , • . ...1- ., ,-- A • • - :>•. ,.s'y N.. ' ' ------ ' '--.....?.\.:---.. -..c:-.--, 4%, , • : ,......00, . ... • , OO :;,,...---,..„----,,,• . ----.'._ --->--...7*,....,...-• • \ •••••--.. ••••••:-...., ----2:•------- '`.. ---..„--,..,:••„....,. -,...,. .._,___ •-•-••-____'-.L..____....... -------1----_---,'---------_____.--;-----__:____.' -t_Z-----',.---', „.• SCANNED -,--:„.- AUG 10 ME 6. i'---z.f.t. • , , . ,• - -_.:..---- L------...._. .....--- ..A.A(.....v.:.sry/E-, : ,-------7--___.- ...---. __..- . • _ • •••4! ,...,.. , :41-.VIVNATNimkti7a 'L.4Ml----'4'4' '',.... .... • • K31.4_ pTh Zi 5-D 2A-C) HILCORP CALIBRATION CERTIFICATE Test Equipment Traceable to NIST Gauge type: t.N l. et Pressure range: (0 I.D. number: o clk Date: TEST PRESSURE INDICATION CAA ScJQ 0 (10 0 7& -- So rtS dip vicA .q te 106 ("ie Calibrated by: Test equipment S/N: AsVv_v-t \\V9 This certificate expires in 90 days on Li — I k . For recertification, contact Gina Bogart or Cathy Marshall at KGF 776-6825. • • 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. _1. - O al.l_Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: Cojp r Items: ❑ M//aps: Grayscale Items: ,Logs: ❑ Poor Quality Originals: V❑ Other: ❑ Other: BY: Date: )1 I 49/15— /s/ vnP Project Proofing BY: Date: /5 /s/ alp Scanning Preparation 7 x 30 = aJ O + a J =TOTAL PAGES ./.3.5"..- (Count does not include cover sheet) BY: i /..5—Date: S Production Scanning Stage 1 Page Count from Scanned File: .43 Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: a, Date: 'I ca. 1 i is /s/ 04 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO r BY: Maria Date: /s/ Stage 2 Additional Well Reports 0 NO TOTAL PAGES 9 2-- Digital version appended by: Meredith dr' Michal Date: ,°V3 a 1 /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: J.,7 a Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc • al o "' 1 1 oo I NO • 9 O_ .(1) a • t CO a) 7 > • az oo 00 t w ooc c • . � O5N '@ M E ' J J M 0 n W W • W co CT; M PI _ m N ° d IP 7 6 @ m ❑ > '.>—.� C C ❑ > 0 > 0 > M M m m T N ❑ j Y g F c ii i.i 2 F— 2 F— 2 F- F- F- Y Y m z Z E 00 o II FI F- F- F- I- I- I- > z E E 7 C co co co co co W co ao co co co co < < C C F Q �_ ° a) a) @c 03 W LL CO CO CO CO CO CO CO CO CO CO CO CO J J it LL g o 2 2 2 2 2 2 2 2 2 2 2 2 W W Cn .0 a) @ m m m m m m m m m m m m m m a) (NO a) Q 2 ° w U r Y Y Y Y Y Y Y Y Y Y Y Y co U p o c', (0 a ai ai CO ui ai ai ai ai ai ai ai ai Z Z m m CO d',.❑ x LL it LL it: LL it it: it: LL it LL it W W ❑ ❑ u) ° E' o W o 0 0 0 0 0 0 0 0 0 0 o Yo Yo ° o o m co w O o c o o o o o o o o o o o o V W V W c0 @ 0 coQ) m m N❑ N❑ E c U to J U m V a) a) a) a) a) a) a) a) a) a) a) a) �_W 2 W a).c a) -5- Ce LL J p W F- W W W W W W W W W W W W N 2 N 2 W U W U OmN ',,, O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 JY@ N NNNNNNNNNNNN N N W a @ a) (NI CN (N (N (N CN N N N N N CN N N N IX @73 Q' () (n 0 0 (n 0 (n Lf) U) LO Lf) L() Ln (n (n LU V Q = _ CI'• � V = U' 0 U Z c caQ o_ Ql6 N O O O 04O d w @ y 0 O a) J Q 0 d CL In co c c r O ,a- -a- O C r O asco . O O LP 1 � co ON E a) i E oa U U Eca co COco = o Q co Z co an ca o o, 7CD 13 co 1''" Z Lc) I2 o a) 0 ° J r2 c CO o p' Z o ra J (° U J N Cl) Z D Q ct Q Yg W C n ii Z a �l Q E U o a m fpm 0 Z in inn a) y @ @ @ @ CO CO CO CO @ @ @ @ @ a -° Co i • IN 0 9 o L \:2 cl 9 r at J 0 �j CooZ co co LL •' •w . . 0 J C .0 En E N Q E E -o v v .� '"' •� O w C o 2 a) 0 a� a) o- a 4 a a •— '_ — p eM- W W J J J J J D1 J J J J r co Ol .@ .� V] W W W W W O W w LL' w e N Y Y J 03 m 0 LL Q LL 0 LL 0 LL --I 0 LL 0 LL M co= E E < 0 0 0 0 0 0 0 0 N 0 0 0 0 — COC o O ci ai ai Z 2 2 2 2 2 2 2E 2 2 2 2 Z 0 0 LL LL o E E LL N N N U) N N Nu) H N N N U) 0 0 0 0 0 Z co co ao ao ao ao 0o OD CO CO OD OD CO CO ao 0o a N N 2 2 2 2 H Q a) i i 1 0 N U1 1 LL LL M M CO CO CO CO CO CO CO CO CO CO CO CO CO J 0)0) 0) 0) D-o D D D D D D D > > D D D 7 D w c — c - U) I a) a) m 0_ m m CO m CO m m m m m m CO CO CO m 0 0) 0) ) a Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y -c 0 0 0 0) . COa)Ce a) a) N as a) as a) a) a) a) a) a) a) a) Z 0 J J J co co co O 0 co O D D N it d I1 I1 it it it it it I1 11 it it it I1 it Y d' N C6 CO C OD c E m c • c cC E E E E c c E E E E 0 E E 0 E 0 E 00 >a)0 0 0 0 0 0 f0 O- O O J 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N W > U 0 U a) U a) ` CO CO CO M CO M (n U n 0-0 22 0 J 0 0 0 0 0 0 0 0 0 0 0 0 0 0 °W C 7 t 0)t > 7 > V _0 a? 0 O 0 W a) a) a) a) 0 N a) a) a) a) a) a) a) a) � ce J N W e w 2 W W W W W W W W W W W W W W W N 2 LL co co J U)W U)W 03 U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) a N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N W 0 1 N N N N N N N N N N N N N N N N N N (X 0. .,U) U) U) U) It) l0 U) U) It) IC) U) U) to In to It) U) to LU 0 V J a L, , Z s co 0 0 to 0 0 Q m o 0 J 0 co CL S � r S r 0 N O CO O 5 O N a E M V0 w '‘Z, � I 0 cv ) co cc Q ro a In' to • N ' CO J N CD a, li CO a 0 Q w c • 46 Q c E 0 Z E w U d E co a) 0 Z (0 (0 6) CO CO CO CO CO CO CO (0 CO CO CO CO CO CO CO N a) co co co CO CO CO CO CO CO CO CO CO CO CO CO CO CO -0 Mo 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 COi 0 r To To to co CO co co co co co co co co co co CO CO 2 J o 0 D O D 0 0 0 0 0 0 0 0 0 0 O D 0 0 J 2 Tr > CO U) co co co co CO c0 CO CO CO CO CO CO CO CO (D CO CO N ~ a00 OOo COCCOCCO OOD CO W CO W W W CO • (0 CO CO CO OD 0 IL) U) U) U) U) U) U) u) U) u) c0 U) U) m U) U) U) U) LI) U) ✓ N N N N N N N N N N N N N N N N N N N 1 N •: 0 in ZS O 0 U �, o o o 0 0 0 0 0 0 0 0 00 0 0 0 00 U U. 0 d• 0 '0 0 D0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 p 0. M w w w w w w w w w w w w w w w w w J J • 0 O ,, v- o 0 0 � ® Z� I9O 1 b NZ a I 5 a) t. cl co co a , ^ c m c In m in c v' (7) Q b o n o Z 5 Z :c r O , IT. U a % H Q m m a U U Q C7 III H fn 0 Z Z '.. 7 rts VN co 0 ceJ m ` CO CD jL o 3 Ci. en a ��' 10 o LU a u) z u; m - co LU o N m N Q j I� as O co Z u v ( a? co co ICC to .. 0 0 cs o m Co J C. C w3+ -0 E -- a o Lo in c 2 0 ci 0 N • O 11 1 (.!) . • N n ^ V r U ..... ,..,,... M ICC co ct P. M o o m V $ o E I— Z N o cC • N > °' a) - Z' II' 1i /cam J 0 `- a N E W C 0 1- E '�... - - W .O c +_ 0 111 N a Z W o r Y _m _ n a O o 0 a7o 0 ' O Z o - m T £ 0 a 2 a coZ d 10 I0 10. 3 C7 C Z N N IN-O O 1 N E, a ._ �C)e 1j1 H F C 1 .4. > .2 1 LLI 0 1 I.:r1 N I I a in w v E o 1 I O I [ 3 N d 0) 1 W c C U) d O. 0 C d' 0 e, 1 = > Q I d E E 3 z 0 N i W c0I I� "- N a3 U F (0 V O C 1 0 a Z F- Z as 0 .y+ v p O d ,, Q O < O a '++ C C U g � '_' _1 -� a) — a) — U •� 0 �,1 0 a -o 0 L d ai o E O. 0 0 - Li- S 2 o E d E d a 2 3 _J 3 0 a 0 1 0 0 a 0 0 • tiOF 7.4 w\ yy � THE STATE Alaska Oil and Gas ofALAS KA. Conservation Commission .;Ez ,_ 333 West Seventh Avenue F GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALAS Fax: 907.276.7542 www.aogcc.alaska.gov Taylor Nasse r , Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Beluga/Upper Tyonek Gas Pool, Tyonek Gas Pool 1, KBU 31-18 Sundry Number: 315-493 Dear Mr. Nasse: 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, a141 p_7Cathy P. oerster , ,,, Chair DATED this /4 aay of August, 2015 Encl. • • • 1 STATE OF ALASKA AUG 1 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION DTS g` 'SII S APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown❑ Suspend❑ Perforate 2 • Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Weil ❑ Re-enter Susp Well ❑ Other. ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development 2• 215-024 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20649-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.510A Kenai Beluga Unit(KBU)31-18 - Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): Unit Tract 14(Fee ADL-22330) • Kenai Gas Field/Beluga/Upper Tyonek Gas Pool-Tyonek Gas Pool 1 • 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): 10,010 9,703 9,903 9,600 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 130' 16" 130' 130' Surface 1,476' 10-3/4" 1,476' 1,476' 5,210psi 2,470psi Intermediate 6,338' 7-5/8" 6,338' 6,198' 6,890psi 4,790psi Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 5" 18#/L-80 9,990' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Swell Packer;N/A 5,777'MD-5,657'ND;N/A 12.Attachments: Description Summary of Proposal ❑✓ • 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 10 Exploratory ❑ Stratigraphi0❑ Development Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 08/24/15 Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 10 • WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Nasse Email tnasseehiicorD.com Printed Name Taylor Nasse Title Operations Engineer -Z771 Signature Phone 907-777-8354Date K/ /)J / S COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 316- 4493 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No 4 Subsequent Form Required: /O Yo APPROVED BY Approved by: 4.2 7-.) COMMISSIONER THE COMMISSION Date: g/)1..tSS OkRoi NAv Submit Form and Form 10-403 Revised 5/2015 i lid for 12 months from the date of approval. qtt ments in Duplicate , RBDMS Y'� 1 4 2015 y(c S�°l s•`' .�• r.-�� r3 rt • • Well Prognosis Well: KBU 31-18 • Date: 8/10/2015 Hilcorp Alaska,LL' Well Name: KBU 31-18 API Number: 50-133-20649-00 Current Status: Flowing Gas Well Leg: N/A Estimated Start Date: 8/24/15 Rig: N/A Reg.Approval Req'd: 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-024 First Call Engineer: Taylor Nasse (907) 777-8354(0) (907) 227-5293 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (C) Current Bottom Hole Pressure: — 1,568 psi @ 9,589' TVD (Measured with eline on 7/9/15) Maximum Expected BHP: — 3,922 psi @ 9,589' TVD (Based on offset wells, EMW= 9.6ppg) Max. Allowable Surface Pressure: —2,990 psi a (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Kenai Gas Field well KBU 31-18 was drilled as a Grass roots monobore completion in April 2015 to target gas sands in the Beluga and Tyonek formations.The initial perforations were made in the Tyonek D-3C Sand and - found the zone to be tight gas. Additional perfs were added in the Tyonek Gas Pool and the Beluga/Upper Tyonek in April, May and June 2015. The well is currently flowing at 545 MCFD @ 208 psi tubing pressure. The purpose of this work/sundry is to perforate additional zones in the Beluga/Upper Tyonek Pool. Top of cement is 6,356'. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. a. Tree connection is 6.5" OTIS. 2. RU 2-7/8" 6 spf Connex HC wireline guns. 3. RIH and perforate the following intervals (work will be split in different days to get analysis of zones between perfs) Zone Sands Top (MD) Btm (MD) FT SPF Beluga LB-4A ±7,088 ±7,095 7' 6 Beluga LB-5A ±7,260 ±7,269 9' 6 a. Bleed tubing pressure to 1,000 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Correlate using CBL Log dated 4/08/15 (CBL Tie-in log). d. Use Gamma/CCL/to correlate. e. Record tubing pressures before and after each perforating run. Run P/T tool with guns if agreed by reservoir engineer. f. Proposed intervals are in the Beluga/Upper Tyonek Gas Pool. g. Spacing allowance is based CO 510a; no wells within 1,500'of property border. - 4. RD E-line. 5. Turn well over to production. E-line Procedure (Contingency): • • Well Prognosis Well: KBU 31-18 Date:8/10/2015 Ililcora Alaska,LL 6. If zone produces sand and/or water. 7. MIRU E-line, PT lubricator to 3,500 psi Hi, 250 Low. a. Tree connection is 9.5" OTIS. 8. RIH and set 5" CIBP at depth above zone. Or 9. RIH and set 5" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Schematic •S . Kenai Gas Field 11 Well: KBU 31-18 ACTUAL SCHEMATIC PTD: 215-024 API: 50-133-20649-00 Hilcorp Alaska,LLC CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16"4. 1 Conductor- 16" Driven 109 X-56 Weld 16" Surf 130' 10-3/4" Surf.Csg 45.5 L-80 BTC 9.95" Surf 1,476' 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 2,805' 10-3/4" 44 7-5/8" Intermediate 29.7 L-80 Hydrill 511 6.875" 2,805' 6,338' Est TOC TUBING 3,354' ` 5" Production 18 L-80 DWC/C HT 4.276" Surf 9,990' lig '. OPEN HOLE/CEMENT DETAIL 2 ' 10-3/4" 142 bbls of 124 lead cement 165BBL's of cement in 13.5"Hole.Returns to Surface 132 BBL of 13.54 IiteCRETE Lead w/1 ppb Cemnet RA Tag7-5/g„ 7-5/8" 29.7 BBLS of 15.34 tail(No cement to surface,111bbIs losses)of cement in 9-7/8" depths: Hole.TOC 3,354'Calculated 6,899' i CBL TOC 5" 128 BBL's of 15.34 EZ Block cement. 100%returns. TOC 4,239'Calculated 6,340' 7,224' JEWELRY DETAIL ;147,513' ' LB6B No. Depth ID OD Item 73-1 1 18' 4.276" 11.00" Tubing Hanger 73-2 2 5,777' 4.276" 6.875" 10 ft Swell Packer(Water Swell) UT1B 7,841' 75-8 76-7 8,126' 4 PERFORATION DETAIL 8,450' kif I Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date Size Status LB6 7,400' 7,420' 7,222' 7,241' 7/9/15 2-7/8" Open 8,739' '' r LB6B 7,482' 7,492' 7,300' 7,310' 7/9/15 2-7/8" Open 84-6 73-1 7,555' 7,562' 7,369' 7,376' 6/29/15 2-7/8" Open It 73-2 7,594' 7,611' 7,406' 7,423' 6/29/15 2-7/8" Open 84-6 UT1B 7,741' 7,752' 7,546' 7,557' 6/23/15 3-3/8" Open '; 86-2 75-8 7,843' 7,850' 7,643' 7,649' 6/23/15 3-3/8" Open 1 :a D-1 76-7 7,938' 7,950' 7,733' 7,744' 6/23/15 3-3/8" Open 9 231' 84-6 8,773' 8,785' 8,524' 8,536' 5/15/15 2-7/8" Open je„ 84-6 8,821' 8,841' 8,570' 8,588' 5/15/15 2-7/8" Open D-2 86-2 8,975' 9,000' 8,715' 8,739' 5/15/15 2-7/8" Open ;ra 11 "' D-3B D-1 9,124' 9,144' 8,856' 8,875' 5/14/15 2-7/8" Open D-2 9,337' 9,351' 9,058' 9,072' 4/25/15 2-7/8" Open D-3B 9,585' 9,611' 9,295' 9,320' 4/15/15 3-1 2 Open D-4B D-4A 9,766' 9,785' 9,468' 9,487' 4/25/15 2-7/8" Open 5„ f41-,,‘ D-48 9,800' 9,815' 9,501' 9,515' 4/24/15 2-7/8" Open PBTD=9,903' MD/9,600'TVD TD=10,010' MD/9,703'TVD Downhole Revised: 7/9/15 Updated by CAH 7/09/15 0 0 Kenai Gas Field Well: KBU 31-18 PROPOSED SCHEMATIC PTD: 215-024 API: 50-133-20649-00 Hilcorp Alaska,LLC CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" Conductor-Driven 109 X-56 Weld 16" Surf 130' ;4 *,*2.1 16" 1 10-3/4" Surf.Csg 45.5 L-80 BTC 9.95" Surf 1,476' 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 2,805' .k L 7-5/8" Intermediate 29.7 L-80 Hydrill 511 6.875" 2,805' 6,338' + TUBING t''' 5" Production 18 L-80 DWC/C HT 4.276" Surf 9,990' 10-3/4" ,' OPEN HOLE/CEMENT DETAIL Est TOC142 bbls of 12#lead cement 3,354' • 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface 14, ; 132 BBL of 13.5#IiteCRETE Lead w/1 ppb Cemnet 7-5/8" 29.7 BBLS of 15.3#tail(No cement to surface,111bbls losses)of cement in 9-7/8" ,r . .I, Hole.TOC 3,354'Calculated 5" 128 BBL's of 15.3#EZ Block cement. 100%returns. TOC 4,239'Calculated IS 2 f " t JEWELRY DETAIL RA Tag +, )4; No. Depth ID OD _ Item depths: 7-5/8" 1 18' 4.276" . 11.00" Tubing Hanger 6,899' CBL TOC 2 5,777' 4.276" 6.875" 10 ft Swell Packer(Water Swell) 4:4 t 6,340' 7,224' k A ` fs ea PERFORATION DETAIL 7,513' 4 LB6 Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) Date Size Status • LB6B LB-1C ±6,430 ±6,445 ±6,288 ±6,302 TBD 2-7/8" Proposed ` 73-1 LB-1C ±6,452 ±6,466 ±6,309 ±6,322 TBD 2-7/8" Proposed ?' 73-2 LB-1E ±6,522 ±6,542 ±6,376 ±6,396 TBD 2-7/8" Proposed UT1B LB-2C ±6,739 ±6,741 ±6,585 ±6,587 TBD 2-7/8" Proposed 7,841' il t P LB-2D ±6,765 ±6,775 ±6,610 ±6,620 TBD 2-7/8" Proposed ® 75-8 LB-3B ±6,946 ±6,956 ±6,785 ±6,794 TBD 2-7/8" Proposed 44 w 76-7 LB-3C ±7,005 ±7,032 ±6,842 ±6,868 TBD 2-7/8" Proposed 8,126' /- LB-4A ±7,088 ±7,095 ±6,922 ±6,929 TBD 2-7/8" Proposed 0. r LB-4B ±7,111 ±7,120 ±6,944 ±6,953 TBD 2-7/8" Proposed 8,450' LB-4B ±7,134 ±7,140 ±6,966 ±6,972 TBD 2-7/8" Proposed LB-4C ±7,192 ±7,199 ±7,022 ±7,029 TBD 2-7/8" Proposed tiro LB-4D ±7,208 ±7,218 ±7,038 ±7,047 TBD 2-7/8" Proposed 8,739' '4100 k LB-5A ±7,260 ±7,269 ±7,088 ±7,096 TBD 2-7/8" Proposed kit LB-5B ±7,320 ±7,333 ±7,145 ±7,158 TBD 2-7/8" Proposed Re 1111 84-6 LB-5B ±7,347 ±7,357 ±7,171 ±7,181 TBD 2-7/8" Proposed 84-6 LB6 7,400' 7,420' 7,222' 7,241' 7/9/2015 2-7/8" Open F y: LB6B 7,482' 7,492' 7,300 7,310 7/9/2015 2-7/8" Open 86-2 73-1 7,555' 7,562' 7,369 7,376' 6/29/2015 2-7/8" Open �r,XI 73-2 7,594' 7,611' 7,406' 7,423' 6/29/2015 2-7/8" Open D-1 9,231' UT1B 7,741' 7,752' 7,546' 7,557' 6/23/2015 3-3/8" Open i 75-8 7,843' 7,850' 7,643' 7,649' 6/23/2015 3-3/8" Open • 76-7 7,938' 7,950' 7,733' 7,744' 6/23/2015 3-3/8" Open OT D-2 84-6 8,773' 8,785' 8,524' 8,536' 5/15/2015 2-7/8" Open 84-6 8,821' 8,841' 8,570' 8,588' 5/15/2015 2-7/8" Open D-3B 86-2 8,975' 9,000' 8,715' 8,739' 5/15/2015 2-7/8" Open D-1 9,124' 9,144' 8,856' 8,875' 5/14/2015 2-7/8" Open .x, D-4A D-2 9,337' 9,351' 9,058' 9,072' 4/25/2015 2-7/8" Open ra D-3B 9,585' 9,611' 9,295' 9,320' 4/15/2015 3-1/2" Open D-4B D-4A 9,766' 9,785' 9,468' 9,487' 4/25/2015 2-7/8" Open ,4. D-4B 9,800' 9,815' 9,501' 9,515' 4/24/2015 2-7/8" Open PBTD=9,903' MD/9,600'TVD TD=10,010' MD/9,703'ND Downhole Revised:7/9/15 Updated by TWN 08-10-15 PTDi4 z16 - 021-1 4111 1111 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday,August 13, 2015 10:10 AM To: 'Taylor Nasse' Cc: Chad Helgeson Subject: RE: KBU 31-18 plugback lower zones (Sundry# 315-421) Taylor, You have approval to plug perfs (set CIBP @ 9450 ft) under the sundry 315-421 as proposed based on the production log results. 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: Taylor Nasse [mailto:tnasse@hilcorp.com] Sent: Thursday, August 13, 2015 9:30 AM To: Schwartz, Guy L(DOA) Cc: Chad Helgeson Subject: KBU 31-18 plugback lower zones (Sundry # 315-421) Hi Guy- We ran a flowing survey on the KBU 31-18 well last month and it indicated that the lower D sands in this well were making water. We currently have an open sundry(see attached for reference)to add perforations in this well and plug back any zones which make water or sand (steps#6-9 in the e-line procedure).Would it be acceptable to set a CIBP at ±9,450' under this sundry to isolate these lower zones? If you have any questions, please feel free to contact me. Thanks, Taylor W. Nasse, PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907)777-8354 office (907)903-0341 cell 1 STATE OF ALASKA • RECEIVED A•KA OIL AND GAS CONSERVATION COMMISSION IUL 2 2 2015 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon Li Plug Perforations U Fracture Stimulate Li Pull Tubing U Operations shutdown Li Performed: Suspend ❑ Perforate CI Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑., Exploratory ❑ 215-024 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20649-00 7.Property Designation(Lease Number): 8.Well Name and Number: Unit Tract 14(Fee ADL-22330) Kenai Beluga Unit(KBU)31-18 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai Gas Field-Beluga/Upper Tyonek Gas Pool-Tyonek Gas Pool 1 11.Present Well Condition Summary: Total Depth measured 10,010 feet Plugs measured N/A feet true vertical 9,703 feet Junk measured N/A feet Effective Depth measured 9,903 feet Packer measured 5,777 feet true vertical 9,600 feet true vertical 5,657 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 130' 16" 130' 130' Surface 1,476' 10-3/4" 1,476' 1,476' 5,210 psi 2,470 psi Intermediate 6,338' 7-5/8" 6,338' 6,198' 6,890 psi 4,790 psi Production Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 5" 18#/L-80 9,990'MD 9,684'TVD Packers and SSSV(type,measured and true vertical depth) Swell Pkr;N/A 5,777'MD 5,657'TVD N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 25 0 45 120 Subsequent to operation: 0 741 0 65 237 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 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 0 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: 315-353 Contact Chad Helgeson Email chelaeson a( hilcorD.com Printed Name Chad Helgeson Title Operations Manager Signature �� Phone 907-777-8405 Date 7l21//5-- 7 —�s RBDMS JUL 2 4 2015 Form 10-404 Revised 5/2015 7/ Submit Original Only Z � • • r. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 31-18 50-133-20649-00 215-024 6/23/15 7/9/15 Daily Operations: 06/23/2015 -Tuesday PTW and JSA. Mobe to location and spot equipment. Pressure test lubricator to 250 psi low and 3,500 psi high. Arm gun. RIH w/3-3/8" x 12' HC, 6 spf, 60 degree phase and tie into Halliburton CBL log. Run correlation log#1 and send to town. Get ok to perf from 7,938'to 7,950' (76-7 SAND).TP 1,350 psi. Fired guns and saw no pressure increase. POOH. All shots fired and gun was wet. RIH w/3-3/8" x 7' HC, 6 spf, 60 degree phase and tie into Halliburton CBL log. Run correlation log and send to town. Get ok to perf from 7,843'to 7,850' (75-8 SAND). Bled tubing pressure down to 919 psi. Fired guns and and after 5 min pressure was 930 psi. POOH. All shots fired and gun was wet. RIH w/3-3/8" x 11' HC, 6 spf, 60 degree phase and tie into Halliburton CBL log. Run correlation log and send to town. Get ok to perf from 7,741'to 7,752' (UT1B SAND). Bled tubing pressure down to 750.5 psi. Fired guns and and after 5 min pressure was 772 psi. POOH. All shots fired gun and was wet. Rig down lubricator and turn well over to field. 06/29/2015- Monday PTW and JSA. Mobe to location and spot equipment. Rig up lubricator and pressure test to 250 psi low and 3,500 psi high. RIH w/press/temp tool and tied into Halliburton CBL log down to 9,815'. Log up to 7,700' stopping 2 min between each perf zone. Well flowing 450 mcf at 90 psi. RIH w/2-7/8" x 17' HC, 6 spf, 60 degree phase and tie into Halliburton P/T log. Run correlation log and send to town. Spot shot from 7,594' to 7,611' (73-2 zone).,Bleed well down to 800 psi. Fired gun. Could not tell any significant difference in the well build up time. POOH. All shots fired. Gun was wet. RIH w/2-7/8" x 7' HC, 6 spf, 60 degree phase and tie into Halliburton P/T log. Run correlation log and send to town. Spot shot from 7,555' to 7,562' (73-1 zone). Bleed well down to 800 psi. Fired gun. Could not tell any significant difference in the well build up time. POOH.All shots fired. Gun was wet. Rig down lubricator and turn well over to field.TP- 1,160 psi. 07/09/2015-Thursday PTW and JSA. Mobe to location and spot equipment. Rig up lubricator and pressure test to 250 psi low and 3,500 psi high. Well flowing 450K at 207 psi. RIH with GPT/2-7/8" x 10' Connex, 6 spf, 60 deg phase down to 9,800'.Tie into Halliburton CBL log and run PT and correlation log. Send to town. Shut well in. Get ok to perf from 7,482' to 7,492'. Halliburton Engr said FL look like is was at 2,700'. Spotted shot and shot zone with 600 psi surface pressure on well. Could not tell how much psi gain due to well still building. POOH. All shots fired. Gun was wet. RIH with GPT/2-7/8" x 20' Connex, 6 spf, 60 deg phase and tie into Halliburton CBL log. Run correlation log and send to town. Get ok to perf from 7,400' to 7,420'. Spot gun and fire gun with 1,261 psi on tubing. POOH, all sots fired and gun was wet. Town was not satisfied with GPT tool so Halliburton is going to run GPT tool again followed by PLT tool to see if they can figure out the problem. Production operations brought well back on so. RIH with GPT tool to 9,800' and tie into Halliburton CBL log . Log at 30' per min up to 7,400' and continued out of hole at normal speed. RIH with PLT tool down to 9,800' and tie into Halliburton CBL log. Log up to 7,400' and continue pulling out of hole. Tools in lubricator. Well flow rate was 557 mcf at 765 psi. Rig down lubricator and turn well over to field. Halliburton will get with town and discuss logs. • • Kenai Gas Field 11 Well: KBU 31-18 ACTUAL SCHEMATIC PTD: 215-024 API: 50-133-20649-00 Hilcorp Alaska,LLC CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 10-3/4" " ` 1 Conductor- Driven 41 16 16" 109 X 56 Weld 16" Surf 130' 10-3/4" Surf.Csg 45.5 L-80 BTC 9.95" Surf 1,476' r. vo ' 7 5/8" Intermediate 29.7 1-80 BTC 6.875" Surf 2,805' `' 7-5/8" Intermediate 29.7 L-80 Hydrill 511 6.875" 2,805' 6,338' Est TOC � TUBING 3,354' p, , '+ Vis. . 5" Production 18 L-80 DWC/C HT 4.276" Surf 9,990' r,N OM1' ill# . 0)1 VP. Fit OPEN HOLE/CEMENT DETAIL '" 142 bbls of 12#lead cement 2 �'� 103/4" •s4 r:t 165BBL's of cement in 13.5"Hole.Returns to Surface RA Ta isu 132 BBL of 13.5#IiteCRETE Lead w/1 ppb Cemnet g .,,+ 7-g/g„ 7-5/8" 29.7 BBLS of 15.3#tail(No cement to surface,111bbls losses)of cement in 9-7/8" depths: Hole.TOC 3,354'Calculated 6,899' % CBL TOC 5" 128 BBL's of 15.3#EZ Block cement. 100%returns. TOC 4,239'Calculated 6,340' 7,224' 31 i JEWELRY DETAIL it 7,513' LB6 No. Depth ID OD Item LB6B 73-1 1 18' 4.276" 11.00" Tubing Hanger �, 73-2 UT1B 2 5,777' 4.276" 6.875" 10 ft Swell Packer(Water Swell) 7,841' ,. 75-8 76-7 8,126' "' L# # PERFORATION DETAIL id 8,450' 4 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date Size Status 2:24LB6 7,400' 7,420' 7,222' 7,241' 7/9/15 2-7/8" Open 8,739' LB6B 7,482' 7,492' 7,300' 7,310' 7/9/15 2-7/8" Open v 84-6 73-1 7,555' 7,562' 7,369' 7,376' 6/29/15 2-7/8" Open 73-2 7,594' 7,611' 7,406' 7,423' 6/29/15 2-7/8" Open 84-6/ UT1B 7,741' 7,752' 7,546' 7,557' 6/23/15 3-3/8" Open 86-2 75-8 7,843' 7,850' 7,643' 7,649' 6/23/15 3-3/8" Open gy,.i.,$ m`' D-1\, 76-7 7,938' 7,950' 7,733' 7,744' 6/23/15 3-3/8" Open 9,231' 84-6 8,773' 8,785' 8,524' 8,536' 5/15/15 2-7/8" Open 84-6 8,821' 8,841' 8,570' 8,588' 5/15/15 2-7/8" Open D-2 86-2 8,975' 9,000' 8,715' 8,739' 5/15/15 2-7/8" Open te D-3B D-1 9,124' 9,144' 8,856' 8,875' 5/14/15 2-7/8" Open •' D-2 9,337' 9,351' 9,058' 9,072' 4/25/15 2-7/8" Open D-4A D-3B 9,585' 9,611' 9,295' 9,320' 4/15/15 3-1/2" Open •_., D4B D-4A 9,766' 9,785' 9,468' 9,487' 4/25/15 2-7/8" Open •,, , " «` D-4B 9,800' 9,815' 9,501' 9,515' 4/24/15 2-7/8" Open PBTD=9,903' MD/9,600'ND TD=10,010' MD/9,703'ND Downhole Revised: 7/9/15 Updated by CAH 7/09/15 OF Tipp • • �� 1%%y4, THE STATE Alaska Oil and Gas hrr, 7-- OfALA KA Conservation Commission y 333 West Seventh Avenue 2 - kv GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®F ALAS�� Fax: 907.276.7542 www.aogcc.alaska,gov Chad Helgeson Operations Manager �^ Hilcorp Alaska, LLC Q I �7 c)4,14` 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Beluga/Upper Tyonek Gas Pool and Tyonek Gas Pool 1, KBU 31-18 Sundry Number: 315-421 Dear Mr. Helgeson: 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,day of July, 2015 Encl. • • RECEIVED STATE OF ALASKA U 0 9 2 015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 7' ... AOGC ` s 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend❑ Plug Perforations p Perforate Q • Pull Tubing ❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing ❑ Other. ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number. Exploratory ❑ Development ❑✓ 215-024 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20649-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.510A • Kenai Beluga Unit(KBU)31-18 • Will planned perforations require a spacing exception? Yes ❑ No Q 9.Property Designation(Lease Number): 10.Field/Pool(s): Unit Tract 14(Fee ADL-22330) • Kenai Gas Field/Beluga/Upper Tyonek Gas Pool Tyonek Gas Pool 1 . 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): 10,010 9,703 9,903 9,600 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 130' 16" 130' 130' Surface 1,476' 10-3/4" 1,476' 1,476' 5,210psi 2,470psi Intermediate 6,338' 7-5/8" 6,338' 6,198' 6,890psi 4,790psi Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 5" 18#/L-80 9,990' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Swell Packer;N/A 5,777'MD-5,657'TVD;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing07/28/15 Operations: Oil ❑ Gas Q • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ El WAG ❑ Abandoned ❑ Commission Representative: GSTOR El SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson Email chelgeson anhilcorp.com Printed NameChad Helgeson Title Operations Manager Signature �.,/-' L —. Phone 907-777-8405 Date 7/ /J5- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315-y2.1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: r Spacing Exception Required? Yes ❑ No g Subsequent Form Required: /0-YO 1 APPROVED BY Approved by: P n COMMISSIONER THE COMMISSION Date: 7—/ .....4.5-- dg4. YXt 7 � �1 Submit Form and Form 10-403 Revised 10/2012) I OrRdiaCcitNsAito..r 12 gopl{;ag ir9m tb ate of ULapproval. 2015 �� Duplicate r i • • Well Prognosis Well: KBU 31-18 Date: 7/09/2015 Hilcarp Alaska,LL Well Name: KBU 31-18 API Number: 50-133-20649-00 Current Status: Flowing Gas Well Leg: N/A Estimated Start Date: 7/28/15 Rig: N/A Reg.Approval Req'd: 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-024 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 227-5293 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(C) Current Bottom Hole Pressure: — 1,568 psi @ 9,589' ND (Measured with eline on 7/9/15) Maximum Expected BHP: — 3,922 psi @ 9,589' ND (Based on offset wells, EMW= 9.6ppg) Max. Allowable Surface Pressure: —2,990 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Kenai Gas Field well KBU 31-18 was drilled as a Grass roots monobore completion in April 2015 to target gas sands in the Beluga and Tyonek formations.The initial perforations were made in the Tyonek D-3C Sand and found the zone to be tight gas. Additional perfs were added in the Tyonek Gas Pool and the Beluga/Upper Tyonek in April, May and June 2015.The well is currently flowing at 545 MCFD @ 208 psi tubing pressure. The purpose of this work/sundry is to perforate additional zones in the Beluga/Upper Tyonek Pool. Top of , cement is 6,356'. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. a. Tree connection is 6.5" OTIS. 2. RU 2-7/8" 6 spf Connex HC wireline guns. 3. RIH and perforate the following intervals(work will be split in different days to get analysis of zones between perfs) Zone Sands Top(MD) Btm (MD) FT SPF Beluga LB-1C ±6,430 ±6,445 15' 6 Beluga LB-1C ±6,452 ±6,466 14' 6 Beluga LB-1E ±6,522 ±6,542 20' 6 Beluga LB-2C ±6,739 ±6,741 2' 6 Beluga LB-2D ±6,765 ±6,775 10' 6 Beluga LB-3B ±6,946 ±6,956 10' 6 Beluga LB-3C ±7,005 ±7,032 27' 6 Beluga LB-4B ±7,111 ±7,120 9' 6 Beluga LB-4B ±7,134 ±7,140 6' 6 Beluga LB-4C ±7,192 ±7,199 7' 6 Beluga LB-4D ±7,208 ±7,218 10' 6 Beluga LB-5B ±7,320 ±7,333 13' 6 Beluga LB-5B ±7,347 ±7,357 10' 6 • • Well Prognosis Well: KBU 31-18 Date: 7/09/2015 Hite m p_tlaska.Ll.' a. Bleed tubing pressure to 1,000 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Correlate using CBL Log dated 4/08/15 (CBL Tie-in log). d. Use Gamma/CCL/to correlate. e. Record tubing pressures before and after each perforating run. Run P/T tool with guns if agreed by reservoir engineer. f. Proposed intervals are in the Beluga/Upper Tyonek Gas Pool. g. Spacing allowance is based CO 510a; no wells within 1,500'of property border. 4. RD E-line. 5. Turn well over to production. E-line Procedure (Contingency): 6. If zone produces sand and/or water. 7. MIRU E-line, PT lubricator to 3,500 psi Hi, 250 Low. a. Tree connection is 9.5" OTIS. 8. RIH and set 5" CIBP at depth above zone. Or 9. RIH and set 5" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Schematic • 0 Kenai Gas Field II Well: KBU 31-18 • ACTUAL SCHEMATIC PTD: 215-024 API: 50-133-20649-00 Ililcorp Alaska,LLC CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 4*16" ;1 1 Conductor- 16" Driven 109 X-56 Weld 16" Surf 130' w 10-3/4" Surf.Csg 45.5 L-80 BTC 9.95" Surf 1,476' 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 2,805' 10-3/4" ' iG 1_01, 7-5/8" Intermediate 29.7 L-80 Hydrill 511 6.875" 2,805' 6,338' Est TOC r TUBING 3,354' `At. ‘, 5" Production 18 L-80 DWC/C HT 4.276" Surf 9,990' kI;,' ' , '' 1 OPEN HOLE/CEMENT DETAIL F' 142 bbls of 12#lead cement 2 '.4.-' 10 3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface t 71 v 132 BBL of 13.5#IiteCRETE Lead w/1 ppb Cemnet BA Tag ',,,, 111 *-4 7-5/8" 7-5/8" 29.7 BBLS of 15.3#tail(No cement to surface,111bbls losses)of cement in 9-7/8" depths: Hole.TOC 3,354'Calculated 6,899' KCBL TOC 5" 128 BBL's of 15.3#EZ Block cement. 100%returns. TOC 4,239'Calculated : 6,340' oti7,224' 31 JEWELRY DETAIL 7,513' ' LB6B B No. Depth ID OD Item : 73-1 1 18' 4.276" 11.00" Tubing Hanger 73-2 2 5,777' 4.276" 6.875" 10 ft Swell Packer(Water Swell) UT1B 7,841' g 12 75-8 76-7 8,126' .p„ PERFORATION DETAIL 8,450' Sands Top(MD) Btm(MD) Top(ND) Btm(ND) Date Size Status dc LB6 7,400' 7,420' 7,222' 7,241' 7/9/15 2-7/8" Open 8,739' LB6B 7,482' 7,492' 7,300' 7,310' 7/9/15 2-7/8" Open 84-6 73-1 7,555' 7,562' 7,369' 7,376' 6/29/15 2-7/8" Open 73-2 7,594' 7,611' 7,406' 7,423' 6/29/15 2-7/8" Open 84-6 iiiill ii. UT1B 7,741' 7,752' 7,546' 7,557' 6/23/15 3-3/8" Open 86-2 75-8 7,843' 7,850' 7,643' 7,649' 6/23/15 3-3/8" Open XII D-1 76-7 7,938' 7,950' 7,733' 7,744' 6/23/15 3-3/8" Open 9,231' ii 84-6 8,773' 8,785' 8,524' 8,536' 5/15/15 2-7/8" Open 84-6 8,821' 8,841' 8,570' 8,588' 5/15/15 2-7/8" Open ::'; D-2 86-2 8,975' 9,000' 8,715' 8,739' 5/15/15 2-7/8" Open 'tD-3B D-1 9,124' 9,144' 8,856' 8,875' 5/14/15 2-7/8" Open 1 AS D-2 9,337' 9,351' 9,058' 9,072' 4/25/15 2-7/8" Open d :71D-4A D-3B 9,585' 9,611' 9,295' 9,320' 4/15/15 3-1/2" Open D-4B D-4A 9,766' 9,785' 9,468' 9,487' 4/25/15 2-7/8" Open , 5•• '."' k d D-4B 9,800' 9,815' 9,501' 9,515' 4/24/15 2-7/8" Open PBTD=9,903' MD/9,600'TVD TD=10,010' MD/9,703'ND Downhole Revised: 7/9/15 Updated by CAH 7/09/15 MMEMMEMMIL • S S Kenai Gas Field • 14Well: KBU 31-18 PROPOSED SCHEMATIC PTD: 21 API: 50-133-5-02420649-00 Ililcorp Alaska,LLC CASING DETAIL Size Type Wt Grade Conn. ID Top Btm ,�; 16" Conductor-Driven 109 X-56 Weld 16" Surf 130' 16" `r e 1 10-3/4" Surf.Csg 45.5 L-80 BTC 9.95" Surf 1,476' v f",. 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 2,805' <;.i+ x 7-5/8" Intermediate 29.7 L-80 Hydrill 511 6.875" 2,805' 6,338' 14. TUBING 5" Production 18 L-80 DWC/C HT 4.276" Surf 9,990' 10-3/4" .11 `" �`,, OPEN HOLE/CEMENT DETAIL Est TOC . . 142 bbls of 12#lead cement 3,354' y 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface ,1 ' tea 132 BBL of 13.5#IiteCRETE Lead w/1 ppb Cemnet 7-5/8" 29.7 BBLS of 15.3#tail(No cement to surface,111bbIs losses)of cement in 9-7/8" lio 0 ,, Hole.TOC 3,354'Calculated 5" 128 BBL's of 15.3#EZ Block cement. 100%returns. TOC 4,239'Calculated s " 2 JEWELRY DETAIL RA Tag ..,,,,, No. Depth ID OD Item depths: 7-5/8�� 1 18' 4.276" 11.00" Tubing Hanger 2 5,777' 4.276" 6.875" 10 ft Swell Packer(Water Swell) 6,899' c CBL T C P. 6,340' 7,224' fi"" gPERFORATION DETAIL 7,513' LB6 Sands Top(MD) Btm(MD) Top(ND) Btm(ND) Date Size Status LB6B LB-1C ±6,430 ±6,445 ±6,288 ±6,302 TBD 2-7/8" Proposed 73-1 LB-1C ±6,452 ±6,466 ±6,309 ±6,322 TBD 2-7/8" Proposed ,, 73-2 LB-1E ±6,522 ±6,542 ±6,376 ±6,396 TBD 2-7/8" Proposed UT1B LB-2C ±6,739 ±6,741 ±6,585 ±6,587 TBD 2-7/8" Proposed , 7,841' LB-2D ±6,765 ±6,775 ±6,610 ±6,620 TBD 2-7/8" Proposed : 75-8 LB-38 ±6,946 ±6,956 ±6,785 ±6,794 TBD 2-7/8" Proposed ■ 76-7 LB-3C ±7,005 ±7,032 ±6,842 ±6,868 TBD 2-7/8" Proposed 8,126' LB-4B ±7,111 ±7,120 ±6,944 ±6,953 TBD 2-7/8" Proposed la Al LB-4B ±7,134 ±7,140 ±6,966 ±6,972 TBD 2-7/8" Proposed 8,450' LB-4C ±7,192 ±7,199 ±7,022 ±7,029 TBD 2-7/8" Proposed LB-4D ±7,208 ±7,218 ±7,038 ±7,047 TBD 2-7/8" Proposed LB-5B ±7,320 ±7,333 ±7,145 ±7,158 TBD 2-7/8" Proposed 8,739' LB-5B ±7,347 ±7,357 ±7,171 ±7,181 TBD 2-7/8" Proposed LB6 7,400' 7,420' 7,222' 7,241' 7/9/2015 2-7/8" Open 84-6 LB6B 7,482' 7,492' 7,300' 7,310' 7/9/2015 2-7/8" Open 84-6 73-1 7,555' 7,562' 7,369' 7,376' 6/29/2015 2-7/8" Open 73-2 7,594' 7,611' 7,406' 7,423' 6/29/2015 2-7/8" Open 86-2 UT1B 7,741' 7,752' 7,546' 7,557' 6/23/2015 3-3/8" Open 75-8 7,843' 7,850' 7,643' 7,649' 6/23/2015 3-3/8" Open ` 76 7 7,938' 7,950 7,733' 7,744' 6/23/2015 3-3/8" Open 9,231' „,, i �'l°' D-1 84-6 8,773' 8,785' 8,524' 8,536' 5/15/2015 2-7/8" Open lit ' 84-6 8,821' 8,841' 8,570' 8,588' 5/15/2015 2-7/8" Open D-2 86-2 8,975' 9,000' 8,715' 8,739' 5/15/2015 2-7/8" Open D-1 9,124' 9,144' 8,856' 8,875' 5/14/2015 2-7/8" Open D-3B D-2 9,337' 9,351' 9,058' 9,072' 4/25/2015 2-7/8" Open + D-3B 9,585' 9,611' 9,295' 9,320' 4/15/2015 3-1/2" Open D-4A D-4A 9,766' 9,785' 9,468' 9,487' 4/25/2015 2-7/8" Open a a D-4B 9,800' 9,815' 9,501' 9,515' 4/24/2015 2-7/8" Open '" D-4B PBTD=9,903' MD/9,600'TVD TD=10,010' MD/9,703'ND Downhole Revised:7/9/15 Updated by DMA 07-09-15 • OF T� I%% ks‘ THE STATE Alaska Oil and Gas ofAT 4AsKA Conservation Commission . _== 333 West Seventh Avenue F GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS4P' Fax: 907.276.7542 www.aogcc.alaska.gov Stan Porhola Operations Engineer Li -0t s j— Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Beluga/Upper Tyonek Gas Pool—Tyonek Gas Pool 1, KBU 31-18 Sundry Number: 315-353 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this/z day of June, 2015 Encl. • • , ,.., „_ ,.,,A,„„..,„ 1.1 L.„,,,,...ar STATE OF ALASKA % 0 S 26;j ALASKA OIL AND GAS CONSERVATION COMMISSION LLAk(AV') APPLICATION FOR SUNDRY APPROVALS Aooicr 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill 0 Perforate New Pod 0 Repair Well 0 Change Approved Program ❑ Suspend 0 Plug Perforations❑ Perforate❑✓ • Pull Tubing 0 Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing ❑ Other. ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development 0 • 215-024 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20649-09 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? C.O.510A Kenai Beluga Unit(KBU)31-18 ' Will planned perforations require a spacing exception? Yes ❑ No 0 - 9.Property Designation(Lease Number): 10.Field/Pool(s): Unit Tract 14(Fee ADL-22330) Kenai Gas Field/Beluga/Upper Tyonek Gas Pool-Tyonek Gas Pool 1 ' 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): 10,010 9,703 9,903 9,600 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 130' 16" 130' 130' Surface 1,476' 10-3/4" 1,476' 1,476' 5,210psi 2,470psi Intermediate 6,338' 7-5/8" 6,338' 6,198' 6,890psi 4,790psi Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 5" 18#/L-80 9,990' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Swell Packer;N/A 5,777'MD-5,657'ND;N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: • Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 06/18/15 Commencing Operations: Oil ❑ Gas Q• WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email sporholae.hilcorp.com Printed Name Stan Porhola�/ Title Operations Engineer / Signature Phone 907-777-8412 Date (0/0,0 S COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: IG-35' Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No 4 Subsequent Form Required: /10 — VD il Approved by: e),-. APPROVED BY ��COMMISSIONER THE COMMISSION Date: /45 4. y f 9rR+G4tNsAii2mOçOm JUN 2 4 201W PI Form 10-403(Re0/2012) the date of approval. i Attachments in Duplicate • • Well Prognosis Well: KBU 31-18 Date: 6/08/2015 llilcorp Alaska,Lb Well Name: KBU 31-18 API Number: 50-133-20649-00 Current Status: New Gas Well Leg: N/A Estimated Start Date: 6/18/15 Rig: N/A Reg.Approval Req'd: 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-024 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (C) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824 (C) Current Bottom Hole Pressure: — 1,250 psi @ 9,589' TVD (Calculated based on surface pressure) Maximum Expected BHP: — 3,922 psi @ 3,922' TVD (Based on offset wells, EMW= 9.6ppg) Max. Allowable Surface Pressure: —2,990 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Kenai Gas Field well KBU 31-18 was drilled as a Grass roots monobore completion in April 2015 to target gas sands in the Beluga and Tyonek formations.The initial perforations were made in the Tyonek D-3C Sand and found the zone to be tight gas. Additional perfs were added in the Tyonek Gas Pool and the Beluga/Upper Tyonek in April and May 2015.The well is currently flowing at 100 MCFD @ 70 psi tubing pressure. The purpose of this work/sundry is to perforate additional zones in the Beluga/Upper Tyonek. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. a. Tree connection is 6.5" OTIS. b. SITP will be 1,500 psi (Gas Pressure). 2. RU 2-7/8" 6 spf Connex HC wireline guns. 3. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Beluga LB6 7,400' 7,420' 20' 6 Beluga LB6B 7,482' 7,492' 10' 6 Upper Tyonek 73-1 7,555' 7,562' 7' 6 Upper Tyonek 73-2 7,594' 7,611' 17' 6 Upper Tyonek UT1B 7,741' 7,752' 11' 6 Upper Tyonek 75-8 7,843' 7,850' 7' 6 Upper Tyonek 76-7 7,938' 7,950' 12' 6 a. Bleed tubing pressure to 1,500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Correlate using CBL Log dated 4/08/15 (CBL Tie-in log). d. Use Gamma/CCL/to correlate. e. Record tubing pressures before and after each perforating run. f. Proposed intervals are in the Beluga/Upper Tyonek Gas Pool. g. Spacing allowance is based CO 510a; no wells within 1,500'of property border. 4. RD E-line. • • Well Prognosis Well: KBU 31-18 Date: 6/08/2015 Ili'carp Alaska,LL 5. Turn well over to production. E-line Procedure(Contingency): 6. If zone produces sand and/or water. 7. MIRU E-line, PT lubricator to 3,500 psi Hi, 250 Low. a. Tree connection is 9.5" OTIS. 8. RIH and set 5" CIBP at depth above zone. Or 9. RIH and set 5" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Schematic • • Kenai Gas Field II Well: KBU 31-18 ACTUAL SCHEMATIC PTD: 215-024 API: 50-133-20649-00 Hilcorp Alaska,LLC CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" 4 14:8Conductor- , 16" Driven 109 X-56 Weld 16 Surf 130 10-3/4" Surf.Csg 45.5 L-80 BTC 9.95" Surf 1,476' 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 2,805' t0-3/4" . 1 7-5/8" Intermediate 29.7 L-80 Hydrill 511 6.875" 2,805' 6,338' TUBING Est TOC 3,354' , , 5" Production 18 L-80 DWC/C HT 4.276" Surf 9,990' k ' } OPEN HOLE/CEMENT DETAIL 142 bbls of 124 lead cement ;;r 2 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface e 4 T w, >, 132 BBL of 13.54 IiteCRETE Lead w/1 ppb Cemnet RA Tag x,,, �,. d7-5/8" 7-5/8" 29.7 BBLS of 15.34 tail(No cement to surface,111bbIs losses)of cement in 9-7/8" depths: Hole.TOC 3,354'Calculated 6,899' CBL TOC 5" 128 BBL's of 15.34 EZ Block cement. 100%returns. TOC 4,239'Calculated 6,340' 7,224' g i 7,513' 7 JEWELRY DETAIL No. Depth ID OD Item 7,841' 1 18' 4.276" 11.00" Tubing Hanger 2 5,777' 4.276" 6.875" 10 ft Swell Packer(Water Swell) 8,126' 8,450' `' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) Date Size Status 8,739' 84-6 8,773' 8,785' 8,524' 8,536' 5/15/15 2-7/8" Open 84-6 84-6 8,821' 8,841' 8,570' 8,588' 5/15/15 2-7/8" Open 1111 86-2 8,975' 9,000' 8,715' 8,739' 5/15/15 2-7/8" Open ti 84-6 D-1 9,124' 9,144' 8,856' 8,875' 5/14/15 2-7/8" Open 86-2 D 2 9,337' 9,351' 9,058' 9,072' 4/25/15 2-7/8" Open NI D-3B 9,585' 9,611' 9,295' 9,320' 4/15/15 3-1/2" Open D-1 D-4A 9,766' 9,785' 9,468' 9,487' 4/25/15 2-7/8" Open 9,231 ii ki D-4B 9,800' 9,815' 9,501' 9,515' 4/24/15 2-7/8" Open "" D-2 £LLi gIn 3 ., D-3B or, D-4A d P*44 "" D-4B " r % PBTD=9,903' MD/9,600'TVD TD=10,010' MD/9,703'ND Downhole Revised: 5/15/15 Updated by STP 5/20/15 II • nai Field Well: KBUGas5 31- PROPOSED SCHEMATIC PKeTD: 21 -024 API: 50-133-2018649-00 Ililcorp Alaska,LLC CASING DETAIL _ Size Type Wt Grade Conn. ID Top Btm 16" ' 116" Driven Conductor- 109 X-56 Weld 16" Surf 130' 10-3/4" Surf.Csg 45.5 L-80 BTC 9.95" Surf 1,476' "1.4 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 2,805' 10-3/4" 110 it 7-5/8" Intermediate 29.7 L-80 Hydrill 511 6.875" 2,805' 6,338' TUBING Est TOC , 3,354' �d ,.' ,. + 5" Production 18 L-80 DWC/C HT 4.276" Surf 9,990' 4 c' x'.44 I s OPEN HOLE/CEMENT DETAIL 142 bbls of 12#lead cement £ , 2 * ' 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface A` F� 132 BBL of 13.58 IiteCRETE Lead w/1 ppb Cemnet RA Tag ' , t' 7-5/8" 7-5/8" 29.7 BBLS of 15.38 tail(No cement to surface,111bbIs losses)of cement in 9-7/8" depths: Hole.TOC 3,354'Calculated 6,899' CBL TOC 5" 128 BBL's of 15.38 EZ Block cement. 100%returns. TOC 4,239'Calculated 7,224' L"' 6,340' LB6 JEWELRY DETAIL AL 7,513' LB6B No. Depth ID OD Item :.: 73-1 1 18' 4.276" 11.00" Tubing Hanger w 73-2 2 5,777' 4.276" 6.875" 10 ft Swell Packer(Water Swell) 14, V UT1B 7,841' kli :A.' 75-8 76-7 8,126' ,..t. PERFORATION DETAIL tii 8,450' All Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date Size Status LB6 7,400' 7,420' 7,222' 7,241' 2-7/8" Proposed 8,739' LB6B 7,482' 7,492' 7,300' 7,310' 2-7/8" Proposed „ 84-6 73-1 7,555' 7,562' 7,369' 7,376' 2-7/8" Proposed it 73-2 7,594' 7,611' 7,406' 7,423' 2-7/8" Proposed 184-6 iUT1B 7,741' 7,752' 7,546' 7,557' 2-7/8" Proposed 86-2 75-8 7,843' 7,850' 7,643' 7,649' 2-7/8" Proposed $2 X1 76-7 7,938' 7,950' 7,733' 7,744' 2-7/8" Proposed 9,231' "� D 1 84-6 8,773' 8,785' 8,524' 8,536' 5/15/15 2-7/8" Open IN 84-6 8,821' 8,841' 8,570' 8,588' 5/15/15 2-7/8" Open ero 0-2 86-2 8,975' 9,000' 8,715' 8,739' 5/15/15 2-7/8" Open '010 D-3B D-1 9,124' 9,144' 8,856' 8,875' 5/14/15 2-7/8" Open ?. 7,% D-2 9,337' 9,351' 9,058' 9,072' 4/25/15 2-7/8" Open D-4A D-3B 9,585' 9,611' 9,295' 9,320' 4/15/15 3-1/2" Open )41 D-4B D-4A 9,766' 9,785' 9,468' 9,487' 4/25/15 2-7/8" Open �`` D-4B 9,800' 9,815' 9,501' 9,515' 4/24/15 2-7/8" Open 5„ '_` s _ i PBTD=9,903' MD/9,600'TVD TD= 10,010' MD/9,703'TVD Downhole Proposed Updated by STP 6/08/15 Hilcorp Alaska, LLC RECEIVED Post Office Box 244027 Anchorage,AK 99524-4027 JUN 0 9 2015 3800 Centerpoint Drive Suite 1400 AOGAOGCCAnchorage,AK 99503 CC Phone: 907/777.8389 June 8, 2015 Fax: 907/777.8301 Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: KBU 31-18 Form 10-407 PTD: 215-024 API: 50-133-20649-00-00 Dear Commissioner: Please find the enclosed Well Completion Form 10-407 for KBU 31-18. Please do not hesitate to contact me should you have any questions or need additional information. Sincerely, HIL ORP ALASKA, LLC Cody Dinger Drilling Technician (907)777-8389 cdinger@hilcorp.com 1 of 1 JUN 0 9 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ' � WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: oil ❑ Gas E - SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAc 25105 20AAc 25.110 Development E " Exploratory ❑ GINJ❑ WINJ ❑ WAGE WDSPL P No.of Completions: _1 " Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Dat(Comp. Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: 5/15/2015 ` • 215-024/315-208/j; -2L ei 3.Address: 7. Date Spud d: ! 15.API Number: 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 3/2015 ' 50-133-20649-00-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 413'FEL, 707'FNL, Sec 18,T4N, R11 W, SM,AK - •3/31/2015 Kenai Beluga Unit(KBU)31-18 Top of Productive Interval: 9. KB(ft above MSL): 85' • 17. Field/Pool(s): Kenai Gas Field Beluga/ 593'FNL, 2166'FEL, Sec 18,T4N, R11 W, SM,AK GL(ft above MSL): 67' • Upper Tyonek GP/Tyonek GP 1 - Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: _ 387'FNL,2466'FEL, Sec 18,T4N, R11 W, SM,AK 9,903'MD/9,600'TVD • Unit Tract 14(Fee Lease ADL-22330) 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 275392 . y- 2356026 • Zone- 4 .10,010'MD/9,703'TVD. N/A TPI: x- 273688.4 y- 2356050 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 273391.68 y- 2356261.87 • Zone- 4 N/A N/A 5. Directional or Inclination Survey: Yes ❑ttalched) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) °N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation, casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary 5"Formation Log MD,2"Formation Log MD, 2"Gas Ratio Log MD,2"Drilling Engineering Log MD,2"/5"ROP-DGR-EWR-ALD-CTN MD,2"/5"DGR-EWR-ALD- CTN TVD 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING" FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 10-3/4" 45.5 L-80 0 1,476' 0 1,476' 13-1/2" 142 bbls 12#/77 bbls 15.4# 7-5/8" 29.7 L-80 0 6,338' 0 6,198' 9-7/8" 132 bbls 13.5#/29.7 bbls 15.3# 5" 18 L-80 0 9,990' 0 9,683' 6-3/4" 128.1 bbls/15.3# 24.Open to production or injection? Yes ❑ , No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and t3ottom;"l-e'rforation Size SIZE DEPTH SET(MD) PACKER SET(MD/TVD) and Number): r 5" 9,990' 5,777'MD/5,657'TVD 1. 8,773'-8,785'MD/8,524'-8,536'TVD 2-7/8"6 SPF ' 2.8,821'-8,841'MD/8,570'-8,588'TVD 2-7/8"6 SPF 5. ,15 15-26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. 3.8,975'-9,000'MD/8,715'-8,739'TVD 2-7/8"6 SPF Was hydraulic fracturing used during completion? Yes ❑ No ❑ 4.9,124'-9,144'MD/8,856'-8,875'TVD 2-7/8"6 SPF 5.9,337'-9,351'MD/9,058'-9,072'TVD 2-7/8"6 SPF Per 20 AAC 25.283(i)(2)attach electronic and printed information 6.9,585'-9,611'MD/9,295'-9,320'TVD 3-1/2"6 SPF DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 7.9,766'-9,785'MD/9,468'-9,487'TVD 2-7/8"6 SPF 8.9,800'-9,815'MD/9,501'-9,515'TVD 2-7/8"6 SPF 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 5/15/2015 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 5/24/2015 24 Test Period —0 119.2 0 N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(torr): Press. 72 0 24-Hour Rate — 0 119.2 0 N/A fj._, i, (/- IS RBDMS4--- Form 10-407 Revised 5/2015 CCpNTI UED ON PAGE 2 4 �� 4 705 Submit ORIGINIAL onl 4 ?// 74--- .-eg `T-/7./L 28.CORE DATA Conventional Cores Yes ❑ No p Sidewall Cores: . ❑ No E !df Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑., Permafrost-Top If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base Attach separate pages to this form, if needed,and submit detailed test Sterling A8 Marker . 3,708' 3,662' information, including reports,per 20 AAC 25.071. Sterling A9 Marker 3,752' 3,705' Sterling Al0 Marker. 3,785' 3,736' Sterling All Marker 3,872' 3,819' Sterling B1 Marker . 3,961' 3,904' Sterling B2 Marker - 4,041' 3,981' Sterling C Marker . 4,636' 4,554' Upper Beluga 4,894' 4,803' Middle Beluga Lower Beluga 5,533' 5,421' Tyonek 6,291' 6,152' Tyonek D-1 7,496' 7,314' 9,096' 8,830' Formation at total depth: 31. List of Attachments:Wellbore schematic,days vs depth, MW vs Depth graphs, Definitive Directional Surveys, Daily Operations Composite Report, Casing and Cement Reports. Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Monty Myers Email: mmyers@hilcorp.com Printed Name: Monty Myers Title: Drilling Engineer Signature Phone: 777-8431 Date: . S. Lot INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled 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.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: 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 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: 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 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records 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. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. 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. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only Kenai Gas Field II Well: KBU 31-18 ACTUAL SCHEMATIC PTD: 215-024 API: 50-133-20649-00 IIiirorp Alaska,I.LC CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" ' 116" Conductor- 109 X-56 Weld 16" Surf 130' tA 40 Driven 10-3/4" Surf.Csg 45.5 L-80 BTC 9.95" Surf 1,476' 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 2,805' 10-3/4" 7-5/8" Intermediate 29.7 L-80 Hydrill 511 6.875" 2,805' 6,338' TUBING Est TOC . ,,„„ 3,354' 41 5" Production 18 L-80 DWC/C HT 4.276" Surf 9,990' IF 14` OPEN HOLE/CEMENT DETAIL . 2 '�(1410-3/4" 142 bbls of 12#lead cement ."Y 165BBL's of cement in 13.5"Hole.Returns to Surface 132 BBL of 13.5#IiteCRETE Lead w/1 ppb Cemnet RA Tag , �, 7-5/8"L •3 7-5/8" 29.7 BBLS of 15.3#tail(No cement to surface,111bbIs losses)of cement in 9-7/8" depths: Hole.TOC 3,354'Calculated CIS - 7;;z c (9ILie'�.A.A 6,899' 6 ' CBL TOC 5" 128 BBL's of 15.3#EZ Block cement. 100%returns. TOC 4,239'Calculated } 6,340' 7,224' 1+ 7,513' JEWELRY DETAIL *, No. Depth ID OD Item 7 841' w. `' 1 18' 4.276" 11.00" Tubing Hanger 'ta 2 5,777' 4.276" 6.875" 10 ft Swell Packer(Water Swell) 8,126' i' " 8,450' k' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) Date Size Status 8,739' ='" m 84-6 8,773' 8,785' 8,524' 8,536' 5/15/15 2-7/8" Open ' 84-6 84-6 8,821' 8,841' 8,570' 8,588' 5/15/15 2-7/8" Open * 86-2 . 8,975' 9,000' 8,715' 8,739' 5/15/15 2-7/8" Open 844 D-1 9,124' 9,144' 8,856' 8,875' 5/14/15 2-7/8" Open 86-2 D-2 9,337' 9,351' 9,058' 9,072' 4/25/15 2-7/8" Open t D-3B 9,585' 9,611' 9,295' 9,320' 4/15/15 3-1/2" Open 9,231' D-1 D-4A 9,766' 9,785' 9,468' 9,487' 4/25/15 2-7/8" Open D-4B 9,800' 9,815' 9,501' 9,515' 4/24/15 2-7/8" Open D-2 I D-4A D-4B # ' im• 5' )0, N PBTD=9,903' MD/9,600'ND TD=10,010'MD/9,703'ND Downhole Revised: 5/15/15 Updated by STP 5/20/15 • • Hilcorp Energy Company Composite Report Well Name: KEU KBU 31-18 Field: Kenai Gas Field County/State: Kenai,Alaska (LAT/LONG): evation(RKB): 18 API#: 50-133-20649-00-00 Spud Date: 3/14/2015 Job Name: 1510327D KBU 31-18 Drilling Contractor AFE#: AFE$: Activity Date Ops Summary 3/9/2015 Rig down TDS&install in cradle,changing out liners/swabs. Performance maintenance on both mud pump engines. Remove windwalls,bridle up and prep derrick to be scoped.;Remove cattle chute,remove"T"bar from tq tube,demob pipeshed and catwalk.;Loaded BOP's,demob TDS from floor,removed windwalls from rig floor,R/D sock and service loop from service loop. Scope down derrick.;Unspool drilling line,prep to lay over mast,R/D pumps and pits. Lay over mast.,Cont R/D pumps and pits,prep and secure mast for trucks,winterize water lines and secure svc lines. Lay felt,liner and mats on KBU 31-18. 3/10/2015 Prep derrick to be removed,Prep doghouse and lower same.Peak trucks on location @ 07:00 hrs.Load out mud pits,mud pumps,top drive HPU connex,;generator skids,dog house,rig water tank,boilers#1 and#2 and matting boards.;Remove iron ruffneck. R/D derrick board wind walls.Crane derrick, carrier and subase,load out same.Load out pony subs,remaining matting boards and misc equip.to KBU 31-18.;With rig matting and pit liner in place,set pony subs,crane in sub base,carrier and set derrick in place.;P/U old containment liner and cleanup around CLU 13.Install iron ruffneck,install derrick board wind walls.Set gen skids,doghouse,rig water tank,top drive HPU,Mud pumps and shaker pit.;lnstall rig fuel lines,electric lines and hydraulic lines.Prep and raise derrick,install lower landings,raise roof on shaker pit.;C/0 air boots for equalizer lines on shaker and degasser pits.R/U pump room lines.Slip and cut 70' drilling line.Prep derrick to scope up.Continue to R/U by hand until trucks arrive @ 7:00 am;;100%rigged down off CLU 13.Rig is currently 95%moved and 40%rigged up on KBU 31-18 3/11/2015 Continue to MIRU on KBU 31-18,Trucks on location @ 07:00,set mud pits 2 and 3,boilers and catwalk,R/U service lines to same.Move satellite offices to new location.;Re-route steam lines for boilers due tight location.With crane,set pipe sheds,install rig floor and pit wind walls,install centrifuge and roof frame.;Stage and R/U satellite offices,change room and parts connex.;R/U Steam lines in pits,cellar and rig floor.Scope derrick up,finish installing torque tube.Install new slide pins in top drive,R/U top drive.R/U mud transfer lines in mud pits.;Patch containment under catwalk.Install water line from water well to rig.R/U pason to offices.;Continue to install top drive.R/U gas buster.Install new protective cover on top drive service loop,R/U service loop and HPU lines.Build dock in containment for liquid mud products.;;Rig is 100%set in place and 75%rigged up. 3/12/2015 Continue to R/U on KBU 31-18. C/O valves in pits,prep to make spud mud. R/U service shacks and power up. Install gas traps,Total Safety install gas alarm system(10/20 H2S, 20/40 LEL).;Troubleshoot top drive,issues with torq and RPM.Get steam circulating thru rig.R/U pason to MWD and mud loggers.;lnstall winter tarps on sub.Continue to work on top drive RPM and torq issues.C/0 valves in pits.R/U floor equipment.C/O link tilt cylinder.Spot test pump and HPU in cellar.;R/U iron ruffneck HPU,centrifuge.Continue to install winter tarps around rig.Continue to troubleshoot top drive elect,communication,RPM working on pason.;Finish installing valves on mud pumps.Finish filling pits with water.Test run mix and charge pumps.;lnstall wear bushing and test plug.Screen up shakers.M/U saver sub,install bails and elevators.M/U kelly hose.Test run mud pumps.Start mixing spud mud.Install 16 3/4"x 20"DSA and 4'spool.;;Rig is 90%rigged up. 3/13/2015 Continue to R/U on KBU 31-18. Repaired top drive rotary and tq sensor. Spotted cmt silos. Offloaded lead and tail cmt.Install clamp cylinder on iron ruffneck. R/U geronimo line;Welder shorten riser.Finish getting rig floor equipment ready.Tighten 4'spacer spool.Lower beam in sub for flowline installation.Install grounds on buildings.Reposition kelly hose.;Reposition top drive hyd service loop to clear derrick.Perform rig acceptance checklist items.Calibrate rig smart check points,adjust C.O.M.RI lockdowns on 16"ID wear ring.;Continue to mix spud mud.Install riser and center over well,R/U flowline.Remve test plug.Prep derrick board for pipe.Start P/U and racking DP in derrick.;Rig accepted on KBU 31-18 @ 18:00 hrs.;Continue to drift,P/U and rack back 24 jts 4 1/2"DP,19 jts HWDP and jars.Tag bottom @ 126';Ready rig floor for P/U BHA.Strap and load tools to rig floor.;Hold pre spud meeting with Drlg crew,DD,MWD,Mud man, Mud logger,support crew,Tour pusher and DSM.;M/U BHA,13 1/2"bit,Mud motor with 1.15 deg AKO(C/O stab blade on mud motor),DM collar,TM collar, scribe mwd to motor with off set @ 160.05 deg.M/U 2 NMFC,2 X0=115'.;M/U stand of HWDP and top drive.Break circulation,displace water from wellbore. Close IBOP,test mud lines to 3000 psi.#1 mud pump pop valve leaking.C/0 same.No leaks.;Test MWD pulser.Tag bottom @ 126'.Spud well.Cleanout conductor from 126 to 130'.Drilling 13 1/2"hole from 130'to 176'pumping 409 gpm,577 psi,45 rpm,torque 4600 ft/lbs.;Circulate hole clean increasing pump to 450 gpm.Rack 1 std HWDP back.P/U 2 6"NMFC. 3/14/2015 M/U 2-6"NMFC,continue drilling 13 1/2"surface hole from 176'to 488'pumping 450 gpm,1080 psi,40 psi diff,47%F/O.WOB 5k.60 rpm,torq 4600 ft/lbs. 7 units BGG;Circulate hole clean pumping 545 gpm,1750 psi.;Pull wiper from 488'to 110'with no issues. 43k up,43k dn;Service crown,top drive,blocks and draworks.;TIH from 110'to 488',washing down last stand.No fill.;Drill from 488'to 951'pumping 545 gpm,1730 psi.WOB 5-12k,75 rpm,torq 5100 ft/lbs.ROP 103 fph.P/U 55K,S/O 50K,ROT 53K.Torq off @ 75 rpm 4900 ft/lbs.MW 9.1 ppg,vis 120.;Drill from 951'to 1520'@ 10 3/4"surface casing point,Mud logger noted from samples we entered shale top @ 1510',;pumping 548 gpm,1760 psi.WOB 5-12k,80 rpm,torq 6300 ft/lbs.P/U 51K,S/O 51K,ROT 49K.Average ROP 71 fph.MW 9.1 ppg,130 vis.No losses, 1.17'above the line and 5.56'right of the line.;Pump hi vis sweep with nut plug marker,cleanup wellbore.Sweep back at calculated stks with 65%increase in cuttings at shakers.Flowcheck well,static.;POH from 1520'to 1392'.Blow down top drive,continue to POH from 1392'to 488'@ previous wiper interval with no issues.Correct diplacement on trip out.;TIH from 488',wash last stand down to TD @ 1520'with no issues,no fill.;Pump 22 bbl sweep(9.1 ppg,310 vis), circulate wellbore clean pumping 537 gpm,1750 psi.sweep back @ calculated stks with 65%increase in cuttings at shakers.;Monitor well(static). Blowdown top drive and mudline to pumps.;;Hauled 317 bbls cuttings to KGF for total of 317 bbls,Hauled 105 bbls class II junk fluid to KGF for total of 105 bbls 3/15/2015 POOH F/1520'-T/175'MD. Stand back DP,HWDP,6"Flex DC's. Hole took proper displacement. Pulled clean entire trip. 50K up, 50K dn,49k rot.;B/O and L/D 8"tools. Drain mtr,B/O bit. Bit had est 15 gal clay balled up from trip out. Bit grade-1,1,ER,C,E,1,PN,TD.;CIean mud and ice off rig floor and handling equipment.;50 gallon diesel spill out of containment. Notify all necessary parties. Cease operations and assist cleanup.;Continue clean mud and ice off rig floor and handling equipment.;Pull wear bushing.;Svc top drive and drawworks;R/U Weatherford casing. Power tongs,long bails,150k elevators,slips,safety clamp and power unit.;Dummy run hanger.;Baker lock and M/U 10 3/4"shoe track with 2 centralizers on shoe jt over 2 stop collars 10'from either end.Install 1 centralizer mid tube on FC jt.Ensure float operating properly.;RIH with 45.5#L-80 BTC 10 3/4"casing from 84'to 1492'with no issues.Fill casing on the fly and every 5 jts.Break circulation @ 737',Install centralizers evey other jt to 306'@ 17 total.;Use optimum torque @ 10200 ft/lbs to base of diamond.36 jts total ran. Correct displacement on trip in with no Iosses.;M/U landing joint and hanger with pup jt per Cameron rep.P/U 67K,S/O 52K.M/U swedge and top drive.Break circulation,set down @ 1500.9',swedge leaking at threads on hanger.;Pull and L/D landing jt,pull and L/D 1 jt of casing,M/U landing jt.Lower into the hole, install dog collar clamp.Break out collar and swedge,threads galled on swedge and collar.C/O same.;UD landing jt and hanger,threads galled on lower collar, install dog collar clamp,C/O collar.Run jt of casing.M/U landing jt,hanger and top drive.;Break circulation staging pump up slowly,pumping 6 bpm at 90 psi. Tag at 1500.9',wash down,tag @ 1505',work pipe in 15'intervals attempting to wash further with no succes,full returns.;;Hauled 170 bbls cuttings to KGF for total of 487 bbls,Hauled 345 bbls class II junk fluid to KGF for total of 450 bbls • 3/16/2015 Continue trying to wash past obstruction @ 1509'(deepest depth). Saw no psi increase when taking wt @ 1509'MD. Washing down @ 6 bpm w/88 psi,37% flow,55k dn,67k up.;R/D Weatherford casing equipment.;L/D jt#36 and M/U hanger. 5/0 and land out w/final set depth of 1476.21'MD. S/O 55k(37k string wt). R/U Drop plug head. R/U to circulate with rig.;Pump 2 lb calcium carbide marker surface to surface to ensure casing and shoe track integrity. Marker came back on time w/calc stks. Calc stks surf/surf 3403-actual 3570 stks w/68 peak units;PJSM,Cement as per detail. Pump 5 bbls H2O,PT lines 4500 psi(good), Rig pump 50 bbls 10#mud push,drop btm plug,SLB pump 142 bbls 12#lead cmt,77 bbls 15.4#tail,drop top plug;Disp w/10 bbls H2O spacer and 128 bbls 9.1 �� spud mud(138 total/134 calc). FCP 500 psi,no bump,hold 5 min bleed back 1/3 bbl,floats held. CIP @ 14:00 hrs 3/16/2015.;0bserved 50 bbls mudpush returned to surface w/48 bbls cmt back to surface. Diverted mudpush/cmt returns to cellar @ 80 bbls into displacement.;Lead Cmt 12#,2.43 yld,Extended type, Mix fluid 14.361 gal/sk. Tail Cmt 15.4#,1.22 yld,Conventional type,Mix fluid 5.513 gal/sk. Cmt pumped @ 5.4 BPM avg. Disp mud @ 6.6 BPM.;Reduced disp rate T/3 bpm last 10 bbls. Shut down pumping @ 13:35 while pumping tail cmt due to feed pump from rig cavitating and unable to feed SLB. Began �/ .t pumping 4 min later w/no issues.;Casing 4 pointed due to lift psi. 43,820 lbs lift w/37,000 dn string wt. No reciprocation of pipe. SLB had minor issues w/psi �0 4 guage. Will troubleshoot after returning to shop.;Flush equipment,blow down lines and clean equipment. Rack out SLB. Vac out cellar.;Remove landing jt. Install packoff. L/D landing jt.;Nipple down riser,flowline,bleeder and hole fill line.;Remove spacer spool and DSA.Install test plug,N/U multi bowl spool. C,SeSir-- Cameron rep packoff hanger to 3700 psi with plastic pack.Set 11"BOP stack in cellar with crane.Clean pits.;Test hanger void per Cameron rep to 300 psi for 5 min.and 3000 psi for 15 min.;N/U 11"spacer spool,remove shipping beams,set BOP stack in place,N/U BOPE,mud cross valves and lines,install BOP anchors.Install koomey lines.Function test BOP.;R/U test equipment with 4 1/2"test jt.Fill stack with water.;;Hauled 59 bbls cuttings to KGF for total of 546 bbls, Hauled 438 bbls class II junk fluid to KGF for total of 888 bbls 3/17/2015 Drain mud from stack,blow through choke line,flush all lines and stack with water.Load all lines and stack with water.RU chart recorder.;Test BOPE. Total Safety serviced and bump tested 10/20 H2S,20/40 LEL.AOGCC Jim Regg waived witness on 3-15-15 @ 09:58 am.Tested components at 250/3500 psi at 5 min each,;tested annular at 250/2500 psi 5 min each.Had 2 fail/pass tests,total test time 6.5 hrs.;RD test equipment,pull test plug,install 9.9375"ID wear ring. Blow down choke line and manifold.;Close blinds,RU chart recorder,test surface casing at 2600 psi for 30 min on chart.Good test.;Service topdrive,CO washpipe,prep rig floor to PU DP from pipeshed.;Drift,PU and single in hole with 156 jnts of 4 1/2"DP 40 jts at a time and rack in derrick.Circulate DP volume each time to flush pipe.;Load tools to rig floor.Start M/U bha#2;;Hauled 37 bbls cuttings to KGF for total of 583 bbls,Hauled 58 bbls class II junk fluid to KGF for total of 946 bbls 3/18/2015 M/U directional BHA#2,9 7/8"MM65 PDC bit,1.50 deg mud motor,smart tools,download MWD,install RA sources and shallow test(OK).MU NMDC with corrosion ring in top.;Cont TIH and tagged soft cement at 1357'.Matt Hogge Hilcorp HSE rep stopped by for a visit and to inspect spill cleanup area.;Break circ and begin wash down drilling cement from 1357'.452 gpm-1421 psi.40 rpm-4630 ft/lbs torque.Drilling hard cement at 1375'.Drilled out float collar on depth at 1390',shoe track and shoe,;rathole to 1529'.then 20'new formation from 1520'to 1540';CBU 1 time at 449 gpm-947 psi,then displaced well from spud mud to +' 9.0 ppg 6%KCL.;Wth good 9.0 ppg KCL mud in/out,racked back one stand,broke off topdrive,RU chart recorder,circ through kill line,closed rams,pumped Y down DP and backside.4 bbls to achieve 240 psi.Shut in;kill line and DP.230 psi at 9.0 ppq=EMW 12.0 ppq.Well bled off from 240 psi and stabilized at 200 psi over a 10 minute period.EMW 11.6 ppg.Bled back.2 bbls.RD test equipment.;Continue directional drilling 9 7/8"hole from 1540'to 1904'pumping 502 gpm, 1125 psi.Diff 75-110 psi.WOB 2-4k,45 rpm,torque 5300 ft/lbs.Note PWD tool not operating correctly.;P/U 59K,S/O 59K,ROT 59K,off bttm torq 4500 ft/lbs. MW 9.1 ppg,vis 52.No Iosses.;Continue directional drilling 9 7/8"hole from 1904'to 2460'pumping 483 gpm,1177 psi,Diff 45 psi.WOB 2-5K,©2200'note seepage,flowcheck well,static loss rate©2.5 bph.;lncrease baracarb 50 from 20 ppb to 30 ppb to control seepage.Pump hi vis sweeps @ 2000'and 2300', sweeps back on time with 40%average increase in returns @ shakers,mostly sand,some shale.;P/U 63K,5/0 60K ROT 62K.BGG 20u,MW 9.2,vis 48. Average ROP 137 fph.;3.06 slide hrs and 2.97 rotate hrs.1.63'above the line and 6.75'left of the line;;Hauled 110 bbls cuttings to KGF for total of 693 bbls, Hauled 468 bbls class II junk fluid to KGF for total of 1414 bbls 3/19/2015 Cont directional drilling 9 7/8"hole from 2460'to 2522'.Sliding wob 5K,480 gpm-1380 psi,160 psi diff,195 Whr ROP,ECD's 9.2 ppg,MW 9.1 ppg,BGG 9 to 43 units.Started a hi-vis sweep around.;Pump sweep around at 480 gpm-1190 psi,50 rpm-4500 ft/lbs off bott torque.Had+/-15%increase in sand to surface.Took survey on bottom.;Start wiper trip from 2522'.Had immediate overpull that would not clean up on elevators.Pump out of hole from 2477'to 1865'(continuous slide section),up wt 60K.Cont trip on elevators from 1865';into surface casing to 1464'with no issues.;Service rig and topdrive,well is static.;Trip in hole on elevators,from 1464'to 2462',MU topdrive and wash last stand down to 2522'.5'of fill on bottom.Made connection.;Cont slide drilling from 2522'to 2896'. Sliding wob 5K,482 gpm-1384 psi,137 to 170 psi diff,199 ft/hr ROP,MW 9.1 ppg/vis 48,ECD's 9.2+,BGG 4 to 52 units.Still sliding 100%.;Rack back one stand,pump 20 bbl hi-vis nut plug sweep around at 504 gpm-1300 psi,80 rpm-5000 fUlbs off bott torque.Had 50%increase in sand,coal and clay to surface.;Cont slide drilling 100%from 2896'to 3143',sliding wob 5K,468 gpm-1352 psi,172 psi diff,165 to 200 ft/hr ROP,MW 9.1 ppg/48 vis,ECD at 9.2+, BGG 8 to 54 units.;Rack back one stand,pump 20 bbl hi-vis nut plug sweep around at 505 gpm-1339 psi,80 rpm-5200 fUlbs off bott torque.Had 40%increase in sand,coal and clay.;Cont slide drilling 100%from 3143'to 3517',sliding wob 5 to 10K,457 gpm-1339 psi,145 psi diff,179 to 200 ft/hr ROP,MW 9.0 ppg/vis 48, ECD at 9.2 ppg,BGG 5 to 38 units.;At 3455'and 3515'pump 20 bbl hi-vis nut plug sweep around at 498 gpm-1339 psi,80 rpm-5250 ft/lbs off bott torque.Had 75%increase in sand,coal and siltstone on first sweep,;60%increase in sand,siltstone,shale on 2nd sweep.P/U 80K,S/O 78K,ROT 79K.Seepage continues @ 2.5 bph.Pump survey,note:magnetic interference.Flow check,well is static.;Pull wiper on elevators from 3517'to 1800'with no issues.Displacement 4.6 bbls over calculated.Flow check,well static.;TIH from 1800'to 3457',safety ream last stand to 3517'.No fill.;Pump survey,magnetic interference at survey depth of 3479',pull 1 std and take another survey to check equipment at survey depth of 3418',clean survey.Work pipe @ 3476',;Notify town engineer,possibly close to KU 13-8,wait on Sperry survey management to clarify recent surveys.Decision made to drill 1 std and take survey checking for magnetic interference.;Cont directional drilling 9 7/8"hole from 3517'to 3589'pumping 485 gpm,1450 psi,Diff 160 psi.Sliding wob 5k.Pump survey at 3541',magnetic interference.;Notify Town engineer of survey results,.36 separation previously and with this survey.51 separation,74'center to center,decision made to drill another stand,survey and check for interference.;Cont directional drilling 9 7/8"hole from 3589'to 3639'pumping 475 gpm,1391 psi.Slide wob 3-5k,survey @ 3603.79',some interference but better,separation.616 with 88.46'center to center.;Cont drilling from 3639'to 3700'.MW 9.1 ppg,vis 53,ECD 9.22 ppg.Seepage contiues @ 2.5 bph.;6.67 slide hrs,1.40 rotate hrs.21.89'below the line and.38'right of the line.;;Hauled 135 bbls cuttings to KGF for total of 829 bbls,Hauled 315 bbls class II junk fluid to KGF for total of 1729 bbls 3/20/2015 Cont directional drilling 9 7/8"hole from 3700'to 4262'.Sliding wob 5K,505 gpm-1512 psi,194 psi diff,102 ft/hr ROP.Rotating wob 5K,503 gpm-1614 psi,60 rpm-7112 ft/lbs on bott torque,;42 to 100 ft/hr on bott torque.MW 9.1 ppg/vis 51,ECD at 9.3 ppg,BGG 16 to 52 units,conn gas 200 to 300 units.Losing fluid to hole after drilling the P5-1_B4 and P5-2_B5 markers.;Pumped 20 bbl hi-vis nutplug sweep at 3887'with a 30%increase in sand and coal at shakers.At 4262'we are losing+/-51 bph to the hole.;Pumped a 20 bbl hi-vis nutplug sweep at 4262'and cont circ hole clean while building a 50 ppb LCM pill with baracarb 50.Load pits 7&8 with water to build volume.Had 50%increase in sand and clay:with sweep to surface.Reduce pump rate to 432 gpm-1143 psi.Obtain survey on bottom,pull up hole and rack one stand back to 4189'.Spot 20 bbl,50 ppb LCM pill outside drill string.;Pull up hole from from 4189'to 1465'(inside surface casing)with no issues tripping on elevators.Calculated hole fill 18 bbls,actual hole fill 46 bbls.Note:total losses @ 207 bbls.;Service rig and topdrive.Upon changing the grabber dies,found the die block broken.Changed out die block.Fluid dropped 6"during monitor without trip tank over 15 minutes.;TIH from 1465' on elevators to 4200'filling pipe @ 3334'. MU topdrive and wash down last stand to 4262'.No fill.Hole took 27.5 bbls over displacment on trip in.;Cont directional drilling 9 7/8"hole from 4262'to 4509'pumping 476 gpm,1447 psi.Diff 115 psi.3-5k wob.60 rpm,6700 ft/lbs.MW 9.1 ppg,vis 50.ECD 9.36 ppg.No Iosses.;Drill thru coal @ 4313'gas peaked @ 479u.Pumped 20 bbl hi-vis nutplug sweep at 4481'with a 50%increase of sand,siltstone and some clay.;Cont directional drilling 9 7/8"hole from 4509'to 4775'pumping 470 gpm,1490 psi.Diff 145 psi.3-6k wob,60 rpm,7000 ft/lbs.P/U 97K,S/O 87K,ROT 93K.Torque off 4700 FT/LBS.;Pumped hi vis nut plug sweep @ 4750'with a 65%increase of sand,siltstone,coal and clay.MW 9.2,vis 53.ECD 9.33 ppg.BGG 29u.No losses.Average ROP 63 fph.;Slide 25-30'every stand to maintain inc and az due to dropping 1.5 deg per 100'.;5.02 slide hrs,6.38 rotate hrs.3.76'above the line and 1.51'left of the line.;;Hauled 104 bbls cuttings to KGF for total of 932 bbls,Hauled 311 bbls class II junk fluid to KGF for total of 2040 bbls • 3/21/2015 Cont directional drilling 9 7/8"hole from 4775'to 5252'.Sliding wob 1 to 5K,470 gpm-1445 psi,13 to 100 psi diff,18 to 64 ft/hr ROP.Rotating wob 3 to 5K,505 gpm-1690 psi,;60 rpm-7600 ft/lbs on bott torque,90 to 100 ft/hr ROP,MW 9.1/vis 50,ECD at 9.3+,BGG 40 to 60 units,conn gas 180 units.Increase pump rate at 4846'with no Iosses.;Pumped hi-vis nutplug sweep at 5005'with 20%increase in cuttings to surface.Had a max of 831 units gas after drilling through the UBB_B zone at 4946'.Received 457 sx cement in silos.;Pumped a sweep while drilling last stand down to 5252'.;Cont circ sweep around with 15%increase in cuttings to surface.Obtain survey on bottom.Flow check well,fluid dropped 1"per min for 10 min.;Pull up hole on elevators,up wt 118K,from 5252'to 4140'with no issues.3.9 bbls over calculated displacement on trip out.;TIH from 4140'to 5190'with no issues,wash last stand to bottom.No fill.3.6 bbls over calculated displacement on trip in.;Cont directional drilling 9 7/8"hole from 5252'to 5396'pumping 505 gpm,1585 psi.Diff 45-100 psi.60 rpm,7800 ft/lbs.2-4K wob.P/U 115K,S/O 99K,ROT 73K.;Off bttm torque 7300 ft/lbs.MW 9.2 ppg,vis 50.ECD 9.32 ppg.Losses @ 2.5 bph due to seepage.;Cont directional drilling 9 7/8"hole from 5396'to 5625'pumping 505 gpm,1680 psi.Diff 45-90 psi.60 rpm,7500 ft/lbs.WOB 3-5k sliding,6-8k rotating.MW 9.1 ppg,vis 53,ECD 9.38 ppg.BGG 30u.;Slide 25-35'every stand to maintain inc and az due to dropping 1.5 deg per 100'.Average ROP 41 fph.No losses. 10.78 slide hrs,5.73 rotate hrs,.41'above the line and 2.07'right of the line.;;Hauled 96 bbls cuttings to KGF for total of 1028 bbls,Hauled 384 bbls class II junk fluid to KGF for total of 2424 bbls 3/22/2015 Cont directional drilling 9 7/8"hole from 5625'to 5951',sliding wob 4 to 7K,502 gpm-1651 psi,86 to 140 psi diff,12 to 47 ft/hr.Rotating wob 4 to 8K,503 gpm- 1789 psi,60 rpm-8400 ft/lbs;on bott torque,70 to 100 ft/hr ROP.BGG 20 units.MW 9.1/vis 53,ECD's at 9.4 ppg.Pumped 20 bbl hi-vis nutplug sweep at 5677' with 20%increase in cuttings to surface.No Iosses.;Cont directional drilling 9 7/8"hole from 5951'to 6182'pumping 504 gpm,1640 psi.Diff 117 psi.60 rpm, 7800 ft/lbs.P/U 115K,5/0 99K,ROT 108K.MW 9.1 ppg,vis 55.ECD 9.3 ppg.No losses.;Pump 20 bbl hi vis nut plug sweep @ 5960',sweep back on time with 15%increase of sand and coal.;Cont directional drilling 9 7/8"hole from 6182'to 6354'@ TD for 7 5/8"casing point in a good siltstone/shale,pumping 502 gpm, 1800 psi.Diff 120 psi.3-5k wob,60 rpm,8900 ft/lbs.;P/U 123K,5/0 110K,ROT 118K.Off bttm torq 7400 ft/lbs.MW 9.2 ppg,vis 53.ECD 9.39 ppg.BGG 21u. Load 20 bbl hi vis nut plug sweep in drill pipe.;Slide 25-35'every stand to maintain inc and az due to dropping 1.5 deg per 100'.Average ROP 32 fph. 13.57 slide hrs,5.74 rotate hrs.1.06'above the line and.44'right of the line.;Circulate and condition,pump hi vis sweep around cleaning up wellbore.Sweep back on time with 20%increase in shale,siltstone.;;Hauled 135 bbls cuttings to KGF for total of 1163 bbls,Hauled 319 bbls class II junk fluid to KGF for total of 2743 bbls 3/23/2015 Flowcheck well,static.Pump survey.6316.96'md,14.26 deg Inc,259.43 deg Azi,6177.97'tvd(0.28'high and 0.42'right of the Iine);POH on elevators from 6354'to 5550',clean.Pump dry job.Blow down top drive.;Cont to POH on elevators from 5550'to 1452'(inside surface casing),up wt 125K.No issues with overpull.Calculated hole fill 32 bbls,actual hole fill 49 bbls.;RU,cut and slip 85'drill line,service rig,check crown saver,;TIH from 1452'to 6205'on elevators.At 6205'encountered tight hole.,MU topdrive,wash/ream last 3 stands to bottom from 6205'to 6354'.;Cont to increase pump rate to 504 gpm-1750 psi,90 rpm-8000 ft/lbs off bott torque,pump 20 bbl hi-vis nutplug sweep around.BGG 7 units,ECD's at 9.3 ppg,MW 9.0/50 vis.10%increase in cuttings.;Pull up hole 5 stands from 6354'to 6044'.Up wt 120K.;MU topdrive,pump and spot 50 bbl LCM hi-vis pill outside drill string.;Pull up hole 10 stands from 6044'to 5425'on elevators, pump dry job,cont POOH from 5425'to 788'@ HWDP with no issues.Flowcheck,dropped 7"in 10 min.Trip out 17 bbls over calculated hole fill.;Std HWDP in derrick,L/D jars,3 xo's,6 3/4"NMFC,pull corrosion ring.PJSM,pull source.Upload data,L/D LVVD and MVVD tools,flt sub,motor and bit.Bit grade= 2,3,CT,A,X,1,ER,TD.;Clear rig floor.R/U and pull 10"ID wear bushing.Close blind rams,remove upper rams and install 7 5/8"casing rams.R/U test equipment. Test 7 5/8"rams to 250/3500 psi 5 min ea.;;Hauled 80 bbls cuttings to KGF for total of 1243 bbls,Hauled 300 bbls class II junk fluid to KGF for total of 3043 bbls 3/24/2015 Finish testing 7 5/8"casing rams at 250/3500 psi for 5 minutes each.R/D test equipment.;Change to long bails,RU fill up hose,RU 7 5/8"casing tongs and handling equipment,stage centralizers and stop rings,dummy run hanger/landing joint,stage CDS-40 x 7 5/8"BTC circ swedges,PJSM.;MU 7 5/8"shoe track assembly,check floats(OK),cont RIH with one XO joint and 84 joints 29.7#7 5/8"Hydril 511 casing.Dog collar each joint.Top fill on the fly and completely fill each 10 jnts.;Up wt 72K,dwn 65K.MU XO joint at 3573'(Hydril 511 to BTC),MU circ swedge/topdrive and CBU 1 time at 220 gpm-5 bpm-171 psi.;Cont RIH with 7 5/8"BTC casing,F/3773'T/6304'filling on the fly,topping off every 10 joints.Up wt 168k s/o 120k @ 6304'.Washed down F6304' T/6319'.;Circ.@ 135 gpm 220 psi.Static Loss Rate=0 Circ.Loss Rate=50bph @ 135gpm.Lost 115 bbls over 3 1/2 hours.Losses reduced from 50 bph to 6 bph.;Continue circ.@ low rate and decrease MW F/9.4 to 9.1 ppg in pit#2.RU SLB plug launcher and hardline.Cont circ.Mud Push II is ready.;;Hauled 28 bbls cuttings to KGF for total of 1271 bbls,Hauled 112 bbls class II junk fluid to KGF for total of 3155 bbls 3/25/2015 Crew change,PJSM with SLB and rig team while circ at 3 bpm-187 psi with hanger 2'off seat.Losses increased from 18 bph to 30 bph.Cont build volume. .fes Increased pump rate to 5 bpm-295 psi;and loss rate decreased from 30 bph to 20 bph or better.;SLB pumped 5 bbls water,tested lines at 1150 psi low and 4000 l psi high.Tests good.Rig pumped 42 bbls 10.0 ppg MUDPUSH II at 5 bpm-295 psi.Shut down and dropped bottom plug.;Lined up SLB pump truck to well.SLB t� mixed and pumped on the fly 132 bbls(457sx)13.5 ppg LiteCRETE lead cement with 1 ppb Cemnet,at 4 to 5 bpm,295 to 175 psi,followed with 29.7 bbls (140sx)15.3;ppg conventional tail cement at 3 to 4 bpm,100 to 80 psi.Shut down and dropped top plug.SLB displaced with 9.3 ppg,6%KCL at 5 to 6 bpm. Wth 10 bbls to go,we landed the hanger(2'off seat)and;slowed to 3 bpm.Plug bumped 289 bbls into displacement(calculated at 287 bbls).Held 1500 psi (FCP 1000 psi)for 3 minutes,bled off to pump truck and floats held.Had 1.5 bbls flowback to truck.;Had no MudPush to surface.Had no cement to surface.Mix v5 water temp 77 degrees.Lost 111 throughout job(total pumped 204 bbls,total returns 93 bbls),did not reciprocate string.;CIP at 12:03 on 3-25-15.Estimated TOC at 3354'.RD and released SLB cementers.;Blow down hardlines,topdrive and mudline.RD SLB hardline and plug launcher.Backout landing joint.Total Safety on location,calibrating and testing gas detection equipment.;MU run tool and packoff assembly on landing joint.Set same in well head.RILD's,plastic pack and test at 250/5000 psi.Good tests.SIMOP's change to short bails.;Close blinds,open upper ram doors,change rams F/7 5/8"T/2 7/8"x 5"variable.Held meeting and dinner with Hilcorp Drilling Manager,Environmental Coordinators,DSM's,Saxon Op's Manager and crews.;lnstall test plug and joint,flood stack, lines and choke manifold,RU test equipment,shell test stack.AOGCC Rep Bob Noble on location at 21:00 hrs to witness testing.;Test BOPE at 250/3500 psi for 5 minutes each.Tested annular at 250/2500 psi.4 1/2"test joint. Test was witnessed by Bob Noble;Rig down test equipment and installed wear bushing;Rig up and pick up 6-3/4 BHA Bit-Motor and MWD;;Hauled 0 bbls cuttings to KGF for total of 1271 bbls,Hauled 132 bbls class II junk fluid to KGF for total of 3285 bbls Hauled 0 bbls of class II cement to KGF;Cumulative 54 Daily Losses downhole 366 3/26/2015 Cont MU directional BHA 3#:6 3/4"EM65D PDC,5"motor w/1.5 deg bend,MWD-PWD tools.MU topdrive and circ through tools to warm up.;Download MVVD, install RA sources and shallow pulse test(OK).;RIH NM flex DC,HWDP and jars.Total BHA length=968.49';Cont TIH on 4 1/2"DP from derrick to make room on rig floor to PU singles,from 968'to 2208'.;PU and single in hole from 2208'to 6115',filling pipe every 2500'.Cont rack and tally DP while empty trip tank periodically.;MU topdrive,circ one DP volume,RU test equipment,test 7 5/8"casing at 3500 psi for 30 min on chart.Good test.RD test equipment.;Cont TIH from 6115'to 6250'and tag up.Drill cement and wiper plugs,202 gpm 800 psi,25 rpm-7400 ft/lbs on bolt torque,MW 9.3 ppg/vis 56,ECD's at 9.7 ppg.;Drilled float equipment/shoe track,200 gpm-840 psi,25 rpm-7400 ft/lbs on bott torque,MW 9.3 ppg/vis 56,ECD's at 9.7 ppg.;Drlg new formation F/6354'to 6374' MD. Pump @280 gpm,1960 psi,5-8k wob,P/U 115k,S/O 110k,112k ROT,7-8k tq on,4k tq off.;Circ.hole clean @ 280 gpm 5k tq 1890psi;Pull to the shoe,rig up and perform FIT-pressured up to 871 psi(EMW 12.0 ppg),good test.;Service rig and topdrive.;Drlg.6374'to 6,565' MD. Pump @292 gpm,1860 psi,5k wob, P/U 125k,5/0 98k,110k ROT,7-8k tq On,4k tq Off.(ECD=10ppg),assembly walking left at 1.38 deg/100'and dropping.49 deg/100';in rotary.ADT:3.11 hrs, AST:1.20 hrs,ART:1.91 hrs. Currently 1.80'low and.35'right of the line.;;Hauled 0 bbls cuttings to KGF for total of 1271 bbls,Hauled 0 bbls class II junk fluid to KGF for total of 3355 bbls 41110 i 3/27/2015 Cont directional drilling 6 3/4"hole from 6551'to 6922',rotating wob 3 to 4K,293 gpm-1882 psi,60 rpm-8400 ft/lbs on bott torque,95 to 100 fUhr ROP,MW 9.3 ppg/48 vis,ECD"s at 10.1 ppg,;BGG 24 to 68 units.Had a max of 2065 units after drilling through the LB_2E zone.Pumped sweeps at 6619'and 6865'with 25% and 20%increase in cuttings to surface.;Cont directional drilling 6 3/4"hole from 6922'to 7173',rotating wob 5K,293 gpm-2058 psi,90 rpm-9300 ft/lbs on bott torque,90 to 100 fUhr ROP,MW 9.3+/50 vis,ECD's at 10.2 ppg,BGG 79 units.;Had a max of 2842 units after drilling through the LB 4C zone.Having issues LV VD LD tools(gamma and PWD),intermittent in and out comm.Hard re-set twice at 7046'and 7172',second re-set failed.;Obtain slow pump rates,pump 20 bbl hi-vis nutplug sweep around at 293 gpm-1950 psi.Had 25%increase in cuttings to surface.Cont circ clean and swap elevators around.;POOH on elevators from 7173'to 7 5/8"casing shoe at 6338'for MWD tool string change.Up wt 150K.;MU topdrive,monitor well,well static,pump dry job,break off topdrive.;Cont POOH inside casing from 6338'to HWDP.;Remove sources from mwd;download data;L/D mwd;check motor and bit;P/U mwd tool and the rest of the BHA;Pick up BHA#4 bit,motor,mwd&PWD component,jars and HWDP to 1139';Hauled 0 bbls cuttings to KGF for total of 1271 bbls,Hauled 320 bbls class II junk fluid to KGF for total of 3675 bbls Distance to plan 3.3Low 8.64Right 3/28/2015 Cont TIH with 6 3/4"directional BHA from 1139'to 6309'.Filled pipe at 2521'and 4071'.;At 6309'MU topdrive and CBU at 258 gpm-1605 psi.MW 9.3 ppg/ECD at 9.9 ppg.Max gas at bottoms up 90 units.then dropped off fairly quick.;RIH from 6309'to 6439',MadPass from 6439'to 6539'for verification of log data with new MWD tools.Log at 120 ft/hr,276 gpm-1558 psi,55 rpm-8255 fifths off bott torque.Logs match up identical.;TIH on elevators from 6539'to 7012',then MadPass from 7012'to 7053'at 120 ft/hr.;RIH 1 stand,wash next stand to bottom with no fill.Make connection and resume drilling 6 3/4"hole from 7173'to 7248',sliding wob 4K,295 gpm-1813 psi,26 to 106 psi diff,7 to 26 fUhr ROP,;BGG 28 units,MW 9.4 ppg/vis 50,ECD's 10.0 ppg.Pumped 20 bbl hi-vis nutplug sweep at 7211'with a 40%increase in cuttings.Had a max of 2554 units gas after drilling the KF_LB_5X zone at 7223'.;Started our planned turn to right at 7173', sliding 3 deg/100'.Making MadPass over slide portions of stands.;Cont Drlg.6 3/4"production section from 7,248'to 7,393 TVD 7215'pumping @ 294 gpm, 1950 psi.Diff 200 psi.5k WOB,90 RPM.Torq on 9K.torq off 6.5K,P/U 145,S/O 104K,ROT 118k.MW 9.4ppg,vis 5;Drillers console lost power troubleshoot problem;Continue working on drillers console(calling out Electrician);Drlg.F/7,393'-T/7,435'pumping @ 294 gpm,1950 psi.Diff 200 psi.5k WOB,90 RPM. Torq on 9K.torq off 6.5K,P/U 145,S/O 104K,ROT 118k.MW 9.4ppg,vis 54 Distance to plan 7.25 high 8.89 right;;Hauled 0 bbls cuttings to KGF for total of 1271 bbls,Hauled 80 bbls class II junk fluid to KGF for total of 3755 bbls. 3/29/2015 Cont drilling the 6 3/4"production section from 7435'to 8040',sliding wob 2 to 4K,294 gpm-1823 psi,122 psi diff,8 to 56 ft/hr ROP.Rotating wob 4K,293 gpm- 2117 psi,60 rpm-9865 ft/lbs on bott;torque,80 to 100 fUhr ROP,MW 9.4 ppg/vis 48,ECD's at 10.4 ppg,BGG 12 to 40 units.Pumped a 20 bbl hi-vis nutplug sweep at 7806'with a 25%increase in cuttings to surface.;Had a max of 2784 units gas after drilling through the UT_2A coal,max of 9864 units after drilling through the UT_2B_coal.Increased MW from 9.4 ppg to 9.5 at 7900',from 9.5 to 9.6 at 7980'.;Start increase MW to 9.7 ppg at 8040'due to excessive gas spikes drilling through coals.MW increases were done while drilling ahead.BGG 22 to 113 units.;Cont drilling the 6 3/4"production section from 8040'to 8065' and had a significant increase in flow and gas(9893 units).Sound alarm,PU off bottom.;Reduced pump rate from 304 gpm to 134 gpm-591 psi,start increase MW from 9.6 ppg to 9.8 ppg.Increase pump rate to 210 gpm-1067 psi,cont circ out gas and increase MW.;Cont drilling from 8065'to 8352',rotating wob 5 to 6K, 308 gpm-2219 psi,90 rpm-9900 ft/lbs on bott torque,40 to 100 ft/hr ROP,MW 9.8 ppg,ECD's 11.1 ppg.,Circ.bottoms up @ 8352' 305 gpm s 50rpms 10.5k TQ 2050psi.;POH F/8352 to 7350'+/- (No Problems);TIH F/7350'to 8290'Washing last 62'to bottom tagged 20'of fill;Circ sweep before going back to drilling(gas units 2000 units);Hauled 0 bbls cuttings to KGF for total of 1271 bbls,Hauled 400 bbls class II junk fluid to KGF for total of 4155 bbls. Distance to Plan:1.33 High 1.18 Left 3/30/2015 Cont circ sweep out of hole after wiper trip at 8352'.214 gpm-1318 psi with a max of 1318 units trip gas.;Cont drilling 6 3/4"hole from 8352'to 8615',rotating wob 5K,304 gpm-2353 psi,65 rpm-10,100 ft/lbs on bott torque,56 to 100 ft/hr ROP,MW 9.9 ppg/vis 46,ECD's at 10.8 ppg,BGG 143 units.;Sliding wob 8K,306 gpm-2329 psi,88 to 220 psi diff,7 to 22 fUhr ROP,MW 9.9 ppg,ECD at 11.1 ppg.Receive casing equipment and 273 sx cement into silo's.;Cont drilling 6 3/4" hole from 8615'to 8908',sliding wob 8K,306 gpm-2401 psi,108 psi diff,10 to 33 fUhr ROP,MW 10.0 ppg/ECD's 11.1 ppg.Rotating wob 5K,306 gpm-2535 psi, 70 rpm-10,500 ft/lbs;on bott torque,100 ft/hr ROP,MW 10.0 ppg/vis 49,ECD's 10.9 ppg.Pumped 20 bbl hi-vis nutplug sweep at 8668'with 25%increase in cuttings to surface.;Cont drilling 6 3/4"hole from 8908'to 8996',and had a significant increase in flow and gas(3200 units).Sound the alarm,PU off bottom.;Circ. out gas and increase MW from a 10.0 ppg to 10.5 ppg pumping @ 257gpm-1414 psi,20 rpm.ECD 10.2;Cont drilling 6 3/4"hole from 8996'to 9,306 sliding wob 3K,303 gpm-2670 psi,170 psi diff,10 ft/hr ROP,MW 10.5 ppg/ECD's 11.7 ppg.Rotating wob 5.5K,302 gpm-2707 psi,75 rpm-11,500 fUlbs;Sweep was pumped @ 9,149'and brought back 40%more cuttings then normal.;Hauled 0 bbls cuttings to KGF for total of 1271 bbls,Hauled 320 bbls class II junk fluid to KGF for total of 4475 bbls. Total AST=3.97 ART=8.4 Total 12.45 Distance to Plan:1.81 low 3.50 Right 3/31/2015 Cont drilling the 6 3/4"hole from 9306'to 9342',rotating wob 5 to 6K,305 gpm-2457 psi,80 rpm-10,900 to 11,500 ft/lbs on bott torque,66 to 115 ft/hr ROP,BGG 600 units,MW 10.5/vis 47,ECD 11.6.;Pump 20 bbl hi-vis nutplug sweep around at 304 gpm-2130 psi,75 rpm-11,000 ft/lbs off bott torque,BGG 700 to 2200 units.;Cont drilling the 6 3/4"hole from 9342'to 9464",increasing MW from 10.6 to 10.7 ppg due to increase in gas and flow.At 9464'did flow check,well flowing.;Stop drilling due to gas,weighting up from a 10.7 to 10.8 ppg.Slowed pump rate down to 250 gpm due to increasing ECD;DrIg.6 3/4"hole from 9464'to t 9747'rotating wob 5 to 6K,250 gpm-2520 psi,70 rpm-12k ft/lbs on bott torque,75 ft/hr ROP,Max 600 units,MW 11.2 vis 49,ECD 12.0.;Drlg.6-3/4"hole F/9747 y' to 9877'decrease pump rate from 250 gpm to 235 due to ECD 12.4;Drlg.6 3/4"hole F/9877'to 10,010(TD) rotating wob 6K,235gpm-2320 psi,70 rpm-12k ft/lbs on bott torque,75 ft/hr ROP,Max 800 units,MW 11.5 vis 49,ECD 12.3.;Circ.sweep Hi-Vis sweep around pumping @ 250 gpm 1960 psi(Beginning ECD 12.32/End ECD 12.22)before short trip.;Pull 5 stands stopped and flow check(No Flow)continue POH F/9978'to 6730'.;F/7128'to 6730'started seeing a little more drag than normal(15k over);Started CBU easing pump rate up to 300 gpm watching the ECD closely (ECD start 12.38 end 12.38);Continue POH F/6730' to 6,338'still seeing some some extra drag;Rig Service;Hauled 0 bbls cuttings to KGF for total of 1271 bbls,Hauled 485 bbls class II junk fluid to KGF for total of 4960 bbls Total AST=0 ART=12.06 Total 12.06 Distance to Plan:23.97 Low 35.74 Right 4/1/2015 TIH F/6338'-T/9000'MD. Tight spot @ 9000',set do 15k. Hole took proper displacement.;Work past tight spot @ 9000'MD. Circulate @ 183 gpm,1630 psi, 24%F/O,25 rpm,11.5k tq,12.25 ECD's w/11.5 MW,230 BGG. Observed moderate amounts of coal @ shakers(2 cm+/-)and rising gas;Circulate hole clean due to coal and rising gas(max gas @ 7395 units). Coal @ shakers subsided 800 stks after btms up.;Continue RIH from 9000'to 10,010;washed last stand to bottom(25'of fill);On bottom circ.a Hi-vis sweep @ 190 gpm 1400 psi SPP(No increase in cuttings when sweep came back)continue circ.until hole was clean; BGG 230 units w/11.5 MW;Increase MW F/11.5-T/11.7 ppg. BGG 125 units w/11.7 ppg. Flow check(static)before POOH;Troubleshoot Top Drive Hydraulics;POOH F/10,010'to 6338(Shoe)no problems.;Monitor well before UD drillpipe.;L/D 4 1/2 drillpipe from 6338'to 4220'stopped and monitored the well before proceeding.;Continued L/D drillpipe.;Flow check the well;Start RIH with the 60 stands from the derrick.;;Hauled 0 bbls cuttings to KGF for total of 1271 bbls,Hauled 80 bbls class II junk fluid to KGF for total of 5040 bbls. 4/2/2015 Continue TIH w/drill pipe out of derrick F/3500'-T/4750'MD.;Cut and slip 120'drilling line. Monitor well via trip tank w/no change. Monitor well post cut and slip(static).;POOH laying down drill pipe F/4750'-T/105'(MWD). Hole took proper displacement.;PJSM, Unload sources. Download MWD.;Continue laying down BHA. B/O bit,drain mtr,remove float and laydown MWD collars. Bit grade 1,1,CT,G,X,I,NO,TD. Monitor well(static).;Remove wear bushing;make dummy run with 5"landing jnt(18.1'load shoulder to RKB).;R/U and Test the Annular&Top Pipe rams with 5"test jnts.(annular 2500/250 top rams 3500/250). 5 min low/10 min high as per Saxon well control policy.;Remove test plug;R/D Testing equipment.;R/U weatherford casing equipment hold PJSM on running 5" production casing;Make up float equipment&test;RIH with 5"casing from 168'to 4,200'fill on the fly,top off every 10 jnts;;Hauled 0 bbls cuttings to KGF for total of 1271 bbls,Hauled 185 bbls class II junk fluid to KGF for total of 5225 bbls. i i 4/3/2015 Continue running 5",L-80,18#,DWC/C production casing F/4200'-T/4869'MD as per detail. Fill every 10 jts.;Circulate and condition mud @ 4869'MD. While attempting to stage up,observed packing off. Work pipe and pumps. Establish circulation @ 135 GPM,430 psi,17%F/O,25 rpm,6.1k tq.;Stage up T/233 gpm,500 psi. Max gas 2745 units(Halliburton). Observed small strings of elastometer from swell packer at shakers. Able to circulate without rotary prior to /IA continuing trip in.;Continue running 5",L-80,18#,DWC/C production casing F/4869'-T/6310'MD as per detail.;Circulate @ 6310'MD. Pump @ 233 gpm,500 psi w/no rotary. Max gas 5862 units.;Continue running 5",L-80,18#,DWC/C production casing F/6310'-T/9990'MD as per detail. Washed down to 9995 w/ /r jt#235 then laydown#235 and m/u hanger and landing jt.;Landout on set depth @ 9990'MD w/120k string wt.;Circ.bottoms up @ 130 gpms beginning 1147 psi 5 ending 840psi;Rig up cement head and lines;hold PJSM on cement job while conditioning mud.;Pump 5bbls of H2O and test lines to 5000 psi;switch over to the rig and pump 20 bbl of 13 ppg mud push II we roppe_cJ_bptto_rrtpjug_folJoyyd by 12,1 bbl_pff 153 15-3_Dog_EZJalsack tail.Pump©5 born 540 sxs 1 34ylrtrnn shutdowns during cmt job,no reciprocation,;dropped bottom plug followed by 176 bbl.of 8.5ppg 4%KCI displaced w/rig 175.5 bbls into displacement plug bumped(176 bbls calc for disp)(CIP @ 00:40 am);FCP 3000psi pressured up to 3500 psi&held for 3 min;bled off 2bbls and checked floats(Good). 100% returns total job,4239'MD TOC. Job went well.;Rig down Schlumberger cementers and L/D landing jnt.;R/U and Install packoff;Test 5"casing to 3500 psi.;lnstall BPV N/D BOP's;Hauled 0 bbls cuttings to KGF for total of 1271 bbls,Hauled 195 bbls class II junk fluid to KGF for total of 5420 bbls. 4/4/2015 N/D BOPE. Remove Catch can,choke and kill lines. R/D gas buster lines. Install trolley beams for transport. R/D koomey lines. Clear cellar.;Nipple up adapter flange. Dry hole tree. Install tree cap. Tested 5 min 500 low/15 min 5000 high(test good). Secure well.;PSI wash cellar and tree. Remove windwalls from rig floor(via crane), L/D and cradle top drive,cattle chute. Continue cleaning mud pits.;Rig released @ 18:00 4-4-2015. Hilconergy Company CompositeSport Well Name: KEU KBU 31-18 Field: Kenai Gas Field County/State: Kenai,Alaska 1(LAT/LONG): svation(RKB): API#: 50-133-20649-00-00 Spud Date: Job Name: 1510327C KBU 31-18 Completion Contractor AFE#: 1510327C AFE$: Activity Date Ops Summary 4/8/2015 PTW and JSA.Mobe to location and spot equipment.Rig up slickline lubricator,pressure test to 250 psi low and 1,000 psi high.,RIH with 4"GR and JB down to 9,850'RKB.POOH and JB was empty.No problems.,Rig down slickline and rig up E-line.PT E-line to 250 psi low and 1,000 psi high.,Trouble shoot CBL tool and panel.Fixed problem.RIH with CBL tool and logged from 9,872'to 5,500'.Found top of cement at 6,340'.,Rig down lubricator. 4/9/2015 Obtain PTW. Hold safety meeting with crews.,Move equipment from staging area to wellsite. Unload flat bed trailer with SLB auxiliary equipment. Pull pit liner. Spot return tank.,Rig down wellhead to top master vavle. Install Flanged 1502 to 5in 10k master valve. MOVE in CTU 12,fluid pump and nitrogen pump. Placed N2 order with air liquide. Scheduled to arrive following morning at 0700 hrs.,Rig up CTU 12 and flow back iron. Hydraulic hoses,fluid hoses., Fluid pack treating lines. Pressure test treating equipment to 250 psi low and 9,000 psi high. Rigged up fittings to IA. Use field triple pump to attempt to place 500 psi on back side. Running low on fluid in field Triplex. Install 1502 on IA gate valve and rig SLB pump to such. Fill IA and pressure test to 500 psi:,IA lr� pressure 502 psi. Holding steading. Close in IA and fill and PT 5in Monobore casing.,9,005 psi on 5in casing and 500 psi on annulus. Start 30 minute test. Pressure after 30 minutes 8,935 psi. Loss of 70 psi over 30 minutes or 2.333 psi per minute. Acceptable pressure drop. Bleed down well to open top tank. Cut vac truck loose for the day.,Rig down SLB iron from tree. Remove flange x 1502. Pick tree up and install on master valve. Pick SLB BOPE and install x over flange and install on tree. Rig up return line from BOPE to choke skid. Location secure. Well valves closed and all ground valves. Crews off location. t Opr 4/10/2015 Fill out PTW and hold safety meeting and reivew SLB JSA.,Air liquide on location filling up SLB N2 equipment. Firing equipment.,Pick injector head,N2 topped off in Pump truck. Grab lubricator,stab on well.,Fluid pack CT volume of 24 bbls. Start BOP draw down test. BOP test as per SLB and API standards and in accordance with sundry. 250 low/4,500 high on all rams and valves. State 24 hr notification sent 4-9-15 at 0806. AOGCC witness waived 4-9-15 0843 by Jim Regg.,RIH perform weight checks as needed. Weights look good. Returns at surface upon running in hole indicating wellbore is full. Cooling down N2., Depth of 8,139'online with N2 at 1,200 scf/min. Tag PBTD at CTMD of 9,872'MD. Mechanical counter reading 9,900 ft MD.,Pick up string weight off bottom. Increased N2 rate to 1,800 scf/min. Good returns at tank.,POOH still blowing. N2 to tank at 1,800 scf/min. Transfer N2 from queen to N2 pump,straight N2 at return tank. Closing in choke to pressure up well as we POOH.,Crews bleeding down N2 lines.Rig down N2 pump. At surface 880 PSI on wellhead. Upper �•/ and lower master closed. Swab closed.,Bleed down CT to open top tank. RDMO. Recovered 202-212 bbls depending on which end of the tank strap is acquired 25 bbls was CT reel volume. Total SCF pumped 234,600 scf or 2,520 gallons. 900 Gallons of N2 left. 4/14/2015 PTW and JSA.Mobe to location and rig up lubricator.PT lubricator to 250 psi low and 4,000 psi high.Well had 850 psi on it. Waiting on WPP tools to come in from Anchorage.Didn't show by noon so start in hole with 3-1/2"HC,6 spf,60 deg phase.Got 40'in hole and found bad spot on line.POOH and cut off 200'of line.Tools were coming in on the 3:30 pm flight.SLB went back to shop to make sure they were right ones.,Came back to location and starting doing the check on tools.Decided to go in hole without the WPP tool.,RIH w/3-1/2"HC,6 spf,60 deg phase pert gun and tie into Halliburton CBL log dated 4/8/15.Ran correlation pass.Having hard time matching up the section we are perfing from 9,610'to 9,584'.Called Chad and discussed.Decision was made to perf from 9,585'to 9,611'off SLB Pipe Tags correlation log dated 4/15/15.Spotted shot from 9.585'to 9.611'.TP-850 psi.Fired shot and no pressure increase.POOH, Rig down lubricator and turn well over to field. 4/24/2015 PTW and JSA.Mobe to location and spot equipment.Rig up lubricator and PT to 250 psi low and 4,000 psi high.Arm gun.Bleed tubing pressure down to 545 psi.,RIH w/WPP,2-7/8"x 15'HC,6 spf,60 deg phase perf gun and tie into Halliburton CBL log dated 4-8-15.Tag at 9,850'.Run correlation log numerous times at different speeds trying to get a match with CBL.Send log to town.Get ok to shoot from 9,800'to 9,815'.Fired gun(at 22:00 hrs)with 419 psi on tubing,BHP- 570 psi and temp 178 deg.Saw no psi increase and WPP tool worked for about a min and quit.POOH.,RIN w/WPP 2-7/8"x 19'HC,6 spf,60 deg phase pert gun and tie into SLB Correlation log dated 4-24-15 at 20:34 hrs.Run correlation log.Spot shot from 9,766'to 9,785'(per Jeremy).Fired gun(at 04:15 hrs)with 397 psi on tubing,BHP-450 psi and temp 163 deg.Saw no psi increase or temp change.Small amount fluid in gun.,Guns were dry. 4/25/2015 Attempted to run in hole.Got 5'and tools stopped.Couldn't go up or down.Tools across tree.Hooked up test pump and pumped approx 20 gals of methanol and ran out.Went to get some more.Tools came free.Decided to check lubricator and also to give SLB crew some rest.Pull up in lubricator.Laid lubricator down and check everything out.All look good.Secured well and turn over to field.,Resting crew.,PTW and JSA.Rig up lubricator and PT to 250 psi low and 4,000 psi high.Arm gun.,RIH w/WPP,2-7/8"x 14'HC,6 spf,60 deg phase pert gun and tie into SLB correlation log dated 4-24-15 at 20:34 hrs.Run correlation log.Spot shot from 9,337'to 9,351'(per Jeremy).Fired gun(at 22:15 hrs)with 525 psi on tubing,BHP-741 psi and temp 152 deg.After shot TP went to 600 psi. Pulled up 50'and BHP-732 psi;Temp-155 deg.Waited 15 min and went thru perfs.BHP-760 psi;Temp-167 deg.Saw no FL.,Rig down lubricator and turn well over to field.TP-677.Tubing pressure was building about same rate as before pert.Guns came out somewhat wet.,POOH. Hilce Energy Company Composite IOort Well Name: KEU KBU 31-18 Field: Kenai Gas Field County/State: Kenai,Alaska Location(LAT/LONG): Elevation(RKB): API#: 50-133-20649-00-00 Spud Date: Job Name: 1521306 KBU 31-18 Add Perfs 3 Zones LB-UT Contractor AFE#: 1521306 AFE$: $99,000 Rpt Date Activity Date Ops Summary 5/15/2015 5/14/2015 PTW and JSA.Mobe to location and spot equipment.Rig up lubricator,pressure test to 250 psi low and 4,000 psi high.Arm gun.,RIH w/2-7/8"x 20'HC,6 spf,60 deg perf gun and tie into Halliburton CBL log dated 4-8-15.Run correlation log and send to town.Get ok to perforate.Spot gun from 9,124'to 9,144'. Fired gun with 1,250 psi on tubing.Pressure went to 1,270 psi.POOH.Gun was wet.,RIH w/2-7/8"x 20'HC,6 spf,60 deg perf gun and tie into Halliburton CBL log dated 4-8-15.Run correlation log and send to town.Get ok to perforate.Spot gun from 8,980'to 9,000'.Had indication that gun had fired with 1,250 psi on tubing.No pressure increase.Got out of hole and gun did not fire.Trouble shot tool string and found shooting GR/CCL had an open in it.Replace tool., RIH w/2-7/8"x 20'HC,6 spf,60 deg perf gun and tie into Halliburton CBL log dated 4-8-15.Spot gun from 8,980'to 9,000'.Fired gun with 1,310 psi.Pressure went to 1,325 psi and in 5 min was back to 1,310 psi.POOH.All shots fired.Gun was wet.,Rig for standby and turn well over to field.Will finish pert job in AM. TP-1,310 psi. 5/16/2015 5/15/2015 PTW and JSA.Rig back up lubricator and pressure test to 250 psi low and 4,000 psi high.,RIH with Halliburton Press/Temp tool and log down to tag depth at 9,832'.Log back up to 8,000'.Found fluid level at 9,342'.TP-1,446 psi.,RIH w/2-7/8"x 5'HC,6 spf,60 deg pert gun and tie into Halliburton Correlation log #2.Spot gun from 8,975'to 8,980'.Fired_gyn with 1,490 psi.Did not see any pressure increase.POOH. All shots fired,gun was wet,RIH w/2-7/8"x 20'HC,6 spf,60 deg pert gun and tie into Halliburton CBL log dated 4-8-15.Run correlation log and send to town.Get ok to perforate.Spot gun from 8,821'to 8,841'. Fired gun with 1,481 psi on tubing.Didn't see any significant pressure increase.POOH.Gun was wet.,RIH w/2-7/8"x 12'HC,6 spf,60 deg pert gun and tie into Halliburton CBL log dated 4-8-15.Run correlation log and send to town.Get ok to perforate.Spot gun from 8,773'to 8,785'.Fired gun with 1,490 psi on tubing.Didn't see any significant pressure increase.POOH.Gun was wet.,Started flowing well with 1,499 psi and got well down to 1,150 psi and started in hole with GPT tool.Before we got to pert well was at 1,000 psi.Shut well in until we got above perfs.Found FL at 9,192'.Started flowing well at about 330 thousand with pressure and rate dropping.Log down thru perfs to 9832'and then back up past top perfs with final rate at about 250 thousand at 941 psi.,Rig down lubricator and turn well over to field.,Shut well in and came out of hole. • 0 --; •- .. .. i ) .r ...., : f Hilcorp Energy Company Kenai Gas Field KGF 41-18 Pad KBU 31-18 50-133-20649-00 II 50-133-20649-00 1. 0 Sperry Drilling , Definitive Survey Report 08 April, 2015 * g: ' F I ,„ 1 E C ... mmr k HALLIBURTON 11 -511111111NNIPIr N FINNINNOMNIN- 111111111 Sperry Drilling II • Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 31-18 Project: Kenai Gas Field ND Reference: Actual @ 84.86usft • Site: KGF 41-18 Pad MD Reference: Actual @ 84.86usft Well: KBU 31-18 North Reference: True - Wellbore: KBU 31-18 Survey Calculation Method: Minimum Curvature • Design: KBU 31-18 Database: Sperry EDM-NORTH US+CANADA Project Kenai Gas Field Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Welt KBU 31-18 Well Position +N/-S 0.00 usft Northing: 2,356,026.01 usft • Latitude: 60°26'35.400 N +E/-W 0.00 usft Easting: 275,392.65 usft, Longitude: 151°14'37.266 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: • 66.86 usft Wellbore KBU 31-18 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (') (nT) BGGM2014 3/11/2015 16.64 73.43 55,325 Design KBU 31-18 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.00 Vertical Section: Depth From(ND) +N/-S +El-W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 275.07 Survey Program Date 4/8/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 198.61 3,417.82 KBU 31-18 MWD+SC+sag1(KBU 31-18 MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 03/12/2015 3,480.02 3,603.79 KBU 31-18 IntermAzm(KBU 31-18) MWD_InterpAzi+sag Fixed:v2:std dec with interpolated azimuth+sag 03/20/2015 3,666.67 9,977.36 KBU 31-18 MWD+SC+sag2(KBU 31-18 MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 03/20/2015 Survey Map Map Vertical MD Inc Azi ND NDSS +NI-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 18.00 0.00 0.00 18.00 -66.86 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 UNDEFINED 198.61 0.66 208.47 198.61 113.75 -0.91 -0.50 2,356,025.11 275,392.14 0.37 0.41 MWD+SC+sag(1) 260.98 0.63 209.35 260.97 176.11 -1.53 -0.84 2,356,024.50 275,391.79 0.05 0.70 MWD+SC+sag(1) 323.62 0.05 195.32 323.61 238.75 -1.86 -1.01 2,356,024.17 275,391.60 0.93 0.84 MWD+SC+sag(1) 386.68 0.02 276.28 386.67 301.81 -1.88 -1.03 2,356,024.15 275,391.59 0.08 0.86 MWD+SC+sag(1) 446.48 0.55 214.34 446.47 361.61 -2.12 -1.20 2,356,023.92 275,391.41 0.90 1.01 MWD+SC+sag(1) 509.16 0.15 277.52 509.15 424.29 -2.35 -1.45 2,356,023.68 275,391.15 0.80 1.24 MWD+SC+sag(1) 570.55 0.25 176.10 570.54 485.68 -2.48 -1.52 2,356,023.56 275,391.08 0.51 1.30 MWD+SC+sag(1) 631.83 0.43 180.91 631.82 546.96 -2.84 -1.52 2,356,023.20 275,391.08 0.30 1.26 MWD+SC+sag(1) 693.14 0.50 172.85 693.13 608.27 -3.34 -1.49 2,356,022.70 275,391.10 0.16 1.19 MWD+SC+sag(1) 755.56 0.44 182.57 755.54 670.68 -3.85 -1.47 2,356,022.19 275,391.11 0.16 1.12 MWD+SC+sag(1) 817.76 0.88 180.89 817.74 732.88 -4.56 -1.48 2,356,021.48 275,391.08 0.71 1.07 MWD+SC+sag(1) 4/8/2015 2:13:53PM Page 2 COMPASS 5000.1 Build 73 • Halliburton . Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 31-18 Project: Kenai Gas Field TVD Reference: Actual @ 84.86usft Site: KGF 41-18 Pad MD Reference: Actual @ 84.86usft Well: KBU 31-18 North Reference: True Wellbore: KBU 31-18 Survey Calculation Method: Minimum Curvature Design: KBU 31-18 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +EI-W Northing EasUng DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 879.77 0.18 177.11 879.75 794.89 -5.14 -1.49 2,356,020.90 275,391.07 1.13 1.03 MWD+SC+sag(1) 941.95 0.68 164.24 941.92 857.06 -5.59 -1.38 2,356,020.45 275,391.16 0.81 0.88 MWD+SC+sag(1) 1,003.16 0.00 262.40 1,003.13 918.27 -5.94 -1.28 2,356,020.10 275,391.26 1.11 0.75 MWD+SC+sag(1) 1,065.29 0.14 31.81 1,065.26 980.40 -5.87 -1.24 2,356,020.16 275,391.30 0.23 0.72 MWD+SC+sag(1) 1,127.50 0.55 51.62 1,127.47 1,042.61 -5.62 -0.97 2,356,020.41 275,391.58 0.68 0.47 MWD+SC+sag(1) 1,190.35 0.00 59.25 1,190.32 1,105.46 -5.44 -0.73 2,356,020.59 275,391.82 0.88 0.25 MWD+SC+sag(1) 1,252.55 0.08 84.27 1,252.52 1,167.66 -5.43 -0.69 2,356,020.59 275,391.86 0.13 0.21 MWD+SC+sag(1) 1,313.45 0.00 95.61 1,313.42 1,228.56 -5.43 -0.65 2,356,020.60 275,391.90 0.13 0.16 MWD+SC+sag(1) 1,376.19 0.33 114.48 1,376.16 1,291.30 -5.50 -0.48 2,356,020.52 275,392.06 0.53 -0.01 MWD+SC+sag(1) 1,438.28 0.27 112.55 1,438.25 1,353.39 -5.63 -0.18 2,356,020.38 275,392.36 0.10 -0.32 MWD+SC+sag(1) 1,481.48 0.13 102.31 1,481.45 1,396.59 -5.68 -0.04 2,356,020.33 275,392.50 0.33 -0.46 MWD+SC+sag(1) 1,556.48 0.17 133.92 1,556.45 1,471.59 -5.78 0.12 2,356,020.23 275,392.66 0.12 -0.63 MWD+SC+sag(1) 1,620.29 0.45 120.09 1,620.26 1,535.40 -5.97 0.41 2,356,020.04 275,392.94 0.45 -0.93 MWD+SC+sag(1) 1,681.88 0.36 142.51 1,681.85 1,596.99 -6.24 0.73 2,356,019.75 275,393.27 0.29 -1.28 MWD+SC+sag(1) 1,743.79 0.34 138.17 1,743.75 1,658.89 -6.53 0.97 2,356,019.46 275,393.50 0.05 -1.55 MWD+SC+sag(1) 1,805.85 0.26 231.30 1,805.81 1,720.95 -6.76 0.99 2,356,019.23 275,393.51 0.71 -1.58 MWD+SC+sag(1) 1,867.62 0.97 242.60 1,867.58 1,782.72 -7.09 0.41 2,356,018.92 275,392.93 1.16 -1.04 MWD+SC+sag(1) 1,929.29 1.63 254.45 1,929.23 1,844.37 -7.56 -0.89 2,356,018.47 275,391.61 1.15 0.22 MWD+SC+sag(1) 1,992.02 2.23 260.03 1,991.93 1,907.07 -8.01 -2.96 2,356,018.05 275,389.54 1.00 2.24 MWD+SC+sag(1) 2,053.96 2.89 259.52 2,053.81 1,968.95 -8.51 -5.68 2,356,017.61 275,386.81 1.07 4.90 MWD+SC+sag(1) 2,115.72 3.67 258.98 2,115.46 2,030.60 -9.17 -9.15 2,356,017.02 275,383.33 1.26 8.30 MWD+SC+sag(1) 2,177.02 4.28 261.67 2,176.62 2,091.76 -9.87 -13.34 2,356,016.39 275,379.13 1.04 12.41 MWD+SC+sag(1) 2,240.01 5.00 260.67 2,239.40 2,154.54 -10.66 -18.37 2,356,015.70 275,374.08 1.15 17.36 MWD+SC+sag(1) 2,301.75 6.05 200.72 2,300.85 2,215.99 -11.62 -24.24 2,356,014.85 275,368.20 1.70 23.12 MWD+SC+sag(1) 2,364.02 6.75 262.87 2,362.73 2,277.87 -12.60 -31.11 2,356,014.00 275,361.31 1.19 29.87 MWD+SC+sag(1) 2,426.46 7.62 263.50 2,424.68 2,339.82 -13.53 -38.86 2,356,013.22 275,353.54 1.40 37.52 MWD+SC+sag(1) 2,486.33 8.65 263.39 2,483.95 2,399.09 -14.50 -47.28 2,356,012.41 275,345.11 1.72 45.81 MWD+SC+sag(1) 2,548.08 9.41 262.41 2,544.93 2,480.07 -15.70 -56.90 2,356,011.39 275,335.47 1.26 55.29 MWD+SC+sag(1) 2,612.92 10.34 262.15 2,608.81 2,523.95 -17.19 -67.92 2,356,010.10 275,324.42 1.44 66.13 MWD+SC+sag(1) 2,672.75 11.02 261.67 2,667.61 2,582.75 -18.75 -78.89 2,356,008.75 275,313.42 1.15 76.93 MWD+SC+sag(1) 2,736.46 11.66 260.97 2,730.07 2,645.21 -20.65 -91.28 2,356,007.09 275,301.00 1.03 89.09 MWD+SC+sag(1) 2,798.02 12.49 261.14 2,790.27 2,705.41 -22.65 -104.00 2,356,005.33 275,288.25 1.35 101.59 MWD+SC+sag(1) 2,860.10 13.41 260.62 2,850.77 2,765.91 -24.86 -117.73 2,356,003.38 275,274.47 1.49 115.07 MWD+SC+sag(1) 2,922.38 13.88 260.43 2,911.29 2,826.43 -27.27 -132.22 2,356,001.24 275,259.94 0.76 129.30 MWD+SC+sag(1) 2,984.12 14.59 260.84 2,971.14 2,886.28 -29.74 -147.20 2,355,999.05 275,244.92 1.16 144.00 MWD+SC+sag(1) 3,046.50 15.31 260.93 3,031.40 2,946.54 -32.29 -163.09 2,355,996.80 275,228.98 1.15 159.60 MWD+SC+sag(1) 3,105.86 16.05 260.86 3,088.55 3,003.69 -34.83 -178.93 2,355,994.56 275,213.10 1.25 175.15 MWD+SC+sag(1) 3,170.23 16.62 260.52 3,150.33 3,065.47 -37.76 -196.80 2,355,991.97 275,195.18 0.90 192.69 MWD+SC+sag(1) 3,232.36 17.29 259.50 3,209.76 3,124.90 -40.91 -214.64 2,355,989.16 275,177.28 1.18 210.19 MWD+SC+sag(1) 3,294.11 17.86 260.16 3,268.62 3,183.76 -44.20 -232.99 2,355,986.22 275,158.87 0.98 228.17 MWD+SC+sag(1) 4/8/2015 2:13:53PM Page 3 COMPASS 5000.1 Build 73 0 Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 31-18 Project: Kenai Gas Field ND Reference: Actual @ 84.86usft Site: KGF 41-18 Pad MD Reference: Actual @ 84.86usft Well: KBU 31-18 North Reference: True Wellbore: KBU 31-18 Survey Calculation Method: Minimum Curvature Design: KBU 31-18 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azl ND TVDSS +NI-S +EI W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,356.33 18.72 257.64 3,327.70 3,242.84 -47.97 -252.15 2,355,982.82 275,139.65 1.88 246.92 MWD+SC+sag(1) 3,417.82 18.41 258.75 3,385.99 3,301.13 -51.97 -271.31 2,355,979.17 275,120.42 0.76 265.65 MWD+SC+sag(1) 3,480.02 17.45 257.94 3,445.17 3,360.31 -55.84 -290.06 2,355,975.66 275,101.60 1.59 283.99 MWD_InterpAzi+sag(2) 3,541.69 17.54 257.09 3,503.99 3,419.13 -59.84 -308.17 2,355,972.00 275,083.42 0.44 301.67 MWD_InterpAzi+sag(2) 3,603.79 18.39 256.25 3,563.06 3,478.20 -64.26 -326.80 2,355,967.93 275,064.71 1.43 319.84 MWD_InterpAzi+sag(2) 3,666.67 17.88 255.42 3,622.81 3,537.95 -69.05 -345.78 2,355,963.50 , 275,045.64 0.91 338.32 MWD+SC+sag(3) 3,728.61 17.67 257.04 3,681.80 3,596.94 -73.55. -364.14 2,355,959.35 275,027.20 0.87 356.21 MWD+SC+sag(3) 3,791.29 17.25 258.86 3,741.59 3,656.73 -77.48 -382.53 2,355,955.77 275,008.74 1.10 374.18 MWD+SC+sag(3) 3,851.86 16.36 259.65 3,799.57 3,714.71 -80.75 -399.73 2,355,952.83 274,991.48 1.52 391.03 MWD+SC+sag(3) 3,914.44 16.46 260.22 3,859.60 3,774.74 -83.84 -417.14 2,355,950.06 274,974.02 0.30 408.10 MWD+SC+sag(3) 3,976.61 16.54 259.66 3,919.21 3,834.35 -86.92 -434.53 2,355,947.31 274,956.58 0.29 425.14 MWD+SC+sag(3) 4,038.79 16.19 259.92 3,978.87 3,894.01 -90.03 -451.77 2,355,944.53 274,939.28 0.58 442.04 MWD+SC+sag(3) 4,101.03 16.08 259.45 4,038.66 3,953.80 -93.13 -468.79 2,355,941.75 274,922.21 0.27 458.72 MWD+SC+sag(3) 4,162.30 16.13 258.97 4,097.53 4,012.67 -96.31 -485.48 2,355,938.89 274,905.46 0.23 475.07 MWD+SC+sag(3) 4,223.21 16.15 258.57 4,156.04 4,071.18 -99.61 -502.09 2,355,935.91 274,888.79 0.19 491.32 MWD+SC+sag(3) 4,286.01 15.64 258.81 4,216.44 4,131.58 -102.98 -518.95 2,355,932.85 274,871.87 0.82 507.82 MWD+SC+sag(3) 4,347.97 15.43 258.22 4,276.13 4,191.27 -106.28 -535.22 2,355,929.86 274,855.54 0.42 523.73 MWD+SC+sag(3) 4,410.09 15.69 258.05 4,335.98 4,251.12 -109.71 -551.52 2,355,926.74 274,839.18 0.42 539.67 MWD+SC+sag(3) 4,471.98 15.67 258.45 4,395.56 4,310.70 -113.12 -567.90 2,355,923.64 274,822.74 0.18 555.68 MWD+SC+sag(3) 4,533.85 15.34 258.42 4,455.18 4,370.32 -116.43 -584.10 2,355,920.63 274,806.48 0.53 571.52 MWD+SC+sag(3) 4,595.62 15.04 258.33 4,514.79 4,429.93 -119.69 -599.96 2,355,917.67 274,790.57 0.49 587.03 MWD+SC+sag(3) 4,657.59 15.40 258.78 4,574.59 4,489.73 -122.92 -615.90 2,355,914.75 274,774.56 0.61 602.62 MWD+SC+sag(3) 4,719.03 15.00 259.82 4,633.88 4,549.02 -125.91 -631.73 2,355,912.05 274,758.68 0.79 618.13 MWD+SC+sag(3) 4,781.90 14.88 260.08 4,694.62 4,609.76 -128.74 -647.69 2,355,909.53 274,742.67 0.22 633.77 MWD+SC+sag(3) 4,844.67 15.33 260.28 4,755.23 4,670.37 -131.53 -663.81 2,355,907.04 274,726.51 0.72 649.58 MWD+SC+sag(3) 4,906.27 15.50 260.18 4,814.61 4,729.75 -134.31 -679.94 2,355,904.57 274,710.32 0.28 665.41 MWD+SC+sag(3) 4,966.83 15.38 259.77 4,872.98 4,788.12 -137.12 -695.82 2,355,902.06 274,694.39 0.27 680.97 MWD+SC+sag(3) 5,029.84 14.67 259.46 4,933.84 4,848.98 -140.06 -711.89 2,355,899.42 274,678.28 1.13 696.72 MWD+SC+sag(3) 5,092.84 14.57 259.72 4,994.80 4,909.94 -142.93 -727.53 2,355,896.85 274,662.58 0.19 712.04 MWD+SC+sag(3) 5,154.47 14.46 260.70 5,054.46 4,969.60 -145.56 -742.75 2,355,894.51 274,647.32 0.44 726.97 MWD+SC+sag(3) 5,216.69 14.45 260.23 5,114.71 5,029.85 -148.13 -758.06 2,355,892.22 274,631.96 0.19 742.00 MWD+SC+sag(3) 5,278.76 14.28 260.43 5,174.84 5,089.98 -150.72 -773.25 2,355,889.92 274,616.73 0.29 756.89 MWD+SC+sag(3) 5,340.37 14.33 259.70 5,234.54 5,149.68 -153.35 -788.24 2,355,887.58 274,601.69 0.30 771.60 MWD+SC+sag(3) 5,402.88 14.63 259.35 5,295.07 5,210.21 -156.19 -803.61 2,355,885.03 274,586.27 0.50 786.66 MWD+SC+sag(3) 5,465.35 14.59 258.45 5,355.52 5,270.66 -159.22 -819.07 2,355,882.29 274,570.75 0.37 801.79 MWD+SC+sag(3) 5,526.75 14.85 258.80 5,414.90 5,330.04 -162.30 -834.37 2,355,879.50 274,555.40 0.45 816.75 MWD+SC+sag(3) 5,589.58 14.54 258.93 5,475.68 5,390.82 -165.38 -850.00 2,355,876.72 274,539.71 0.50 832.06 MWD+SC+sag(3) 5,651.89 14.98 256.62 5,535.93 5,451.07 -168.74 -865.51 2,355,873.65 274,524.14 1.18 847.21 MWD+SC+sag(3) 5,714.11 15.34 257.36 5,595.98 5,511.12 -172.40 -881.37 2,355,870.29 274,508.22 0.66 862.68 MWD+SC+sag(3) 5,776.55 15.39 258.36 5,656.19 5,571.33 -175.88 -897.54 2,355,867.11 274,491.98 0.43 878.48 MWD+SC+sag(3) 4/8/2015 2:13:53PM Page 4 COMPASS 5000.1 Build 73 • Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 31-18 Project: Kenai Gas Field TVD Reference: Actual @ 84.86usft Site: KGF 41-18 Pad MD Reference: Actual @ 84.86usft Well: KBU 31-18 North Reference: True Wellbore: KBU 31-18 Survey Calculation Method: Minimum Curvature Design: KBU 31-18 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) morn (ft) Survey Tool Name 5,838.74 15.61 259.04 5,716.12 5,631.26 -179.14 -913.84 2,355,864.17 274,475.63 0.46 894.43 MWD+SC+sag(3) 5,900.11 15.37 259.73 5,775.26 5,690.40 -182.16 -929.95 2,355,861.45 274,459.47 0.49 910.21 MWD+SC+sag(3) 5,962.76 15.20 259.47 5,835.70 5,750.84 -185.14 -946.19 2,355,858.78 274,443.17 0.29 926.12 MWD+SC+sag(3) 6,024.48 15.26 257.53 5,895.25 5,810.39 -188.37 -962.08 2,355,855.85 274,427.23 0.83 941.66 MWD+SC+sag(3) 6,086.42 15.15 258.15 5,955.02 5,870.16 -191.79 -977.96 2,355,852.72 274,411.28 0.32 957.18 MWD+SC+sag(3) 6,148.60 14.83 258.11 6,015.08 5,930.22 -195.10 -993.70 2,355,849.71 274,395.49 0.51 972.56 MWD+SC+sag(3) 6,210.54 14.61 257.87 6,074.99 5,990.13 -198.38 -1,009.09 2,355,846.73 274,380.03 0.37 987.61 MWD+SC+sag(3) 6,272.07 14.77 259.22 6,134.51 6,049.65 -201.47 -1,024.38 2,355,843.92 274,364.69 0.61 1,002.56 MWD+SC+sag(3) 6,316.96 14.26 259.43 6,177.97 6,093.11 -203.56 -1,035.44 2,355,842.05 274,353.59 1.14 1,013.39 MWD+SC+sag(3) 6,394.25 13.88 258.36 6,252.94 6,168.08 -207.17 -1,053.88 2,355,838.78 274,335.09 0.60 1,031.44 MWD+SC+sag(3) 6,456.13 14.65 258.96 6,312.91 6,228.05 -210.17 -1,068.83 2,355,836.07 274,320.09 1.27 1,046.06 MWD+SC+sag(3) 6,518.63 15.91 259.12 6,373.20 6,288.34 -213.30 -1,085.00 2,355,833.24 274,303.86 2.02 1,061.89 MWD+SC+sag(3) 6,579.57 15.87 260.71 6,431.81 6,346.95 -216.22 -1,101.42 2,355,830.63 274,287.39 0.72 1,078.00 MWD+SC+sag(3) 6,642.01 15.90 261.14 6,491.87 6,407,01 -218.92 -1,118.30 2,355,828.26 274,270.46 0.19 1,094.57 MWD+SC+sag(3) 6,704.20 15.73 261.01 6,551.70 6,466,84 -221.55 -1,135.04 2,355,825.94 274,253.67 0.28 1,111.02 MWD+SC+sag(3) 6,766.51 15.84 261.64 6,611.66 6,526.80 -224.10 -1,151.80 2,355,823.70 274,236.87 0.33 1,127.48 MWD+SC+sag(3) 6,828.67 15.40 262.10 6,671.53. 6,586.67 -226.47 -1,168.37 2,355,821.65 274,220.26 0.74 1,143.77 MWD+SC+sag(3) 6,889.80 15.07 262.12 6,730.51 6,645.65 -228.68 -1,184.28 2,355,819.74 274,204.31 0.54 1,159.43 MWD+SC+sag(3) 6,950.91 15.03 261.90 6,789.52 6,704.66 -230.88 -1,199.99 2,355,817.84 274,188.56 0.11 1,174.89 MWD+SC+sag(3) 7,013.78 15.18 262.69 6,850.22 6,765.36 -233.08 -1,216.23 2,355,815.95 274,172.29 0.41 1,190.86 MWD+SC+sag(3) 7,076.57 15.20 263.64 6,910.82 6,825.96 -235.04 -1,232.56 2,355,814.30 274,155.92 0.40 1,206.96 MWD+SC+sag(3) 7,137.84 14.81 263.22 6,970.00 6,885.14 -236.85 -1,248.32 2,355,812.78 274,140.13 0.66 1,222.50 MWD+SC+sag(3) 7,200.76 15.51 269.90 7,030.73 6,945.87 -237.81 -1,264.72 2,355,812.13 274,123.72 2.99 1,238.75 MWD+SC+sag(3) 7,263.45 15.94 277.01 7,091.08 7,006.22 -236.78 -1,281.65 2,355,813.48 274,106.81 3.15 1,255.70 MWD+SC+sag(3) 7,325.39 16.17 283.70 7,150.61 7,065.75 -233.70 -1,298.47 2,355,816.88 274,090.05 3.01 1,272.73 MWD+SC+sag(3) 7,387.43 16.70 288.66 7,210.12 7,125.26 -228.80 -1,315.31 2,355,822.10 274,073.31 2.42 1,289.94 MWD+SC+sag(3) 7,447.84 18.31 294.82 7,267.73 7,182.87 -222.04 -1,332.15 2,355,829.17 274,056.60 4.06 1,307.31 MWD+SC+sag(3) 7,511.80 18.65 295.79 7,328.40 7,243.54 -213.37 -1,350.48 2,355,838.18 274,038.44 0.72 1,326.33 MWD+SC+sag(3) 7,570.48 18.46 296.44 7,384.03 7,299.17 -205.15 -1,367.24 2,355,846.72 274,021.83 0.48 1,343.76 MWD+SC+sag(3) 7,635.18 17.84 297.33 7,445.51 7,360.65 -196.04 -1,385.22 2,355,856.17 274,004.03 1.05 1,362.47 MWD+SC+sag(3) 7,697.83 17.53 296.55 7,505.20 7,420.34 -187.42 -1,402.19 2,355,865.11 273,987.23 0.62 1,380.13 MWD+SC+sag(3) 7,759.73 19.06 297.74 7,563.97 7,479.11 -178.55 -1,419.47 2,355,874.31 273,970.12 2.54 1,398.13 MWD+SC+sag(3) 7,821.92 19.02 298.63 7,622.75 7,537.89 -168.96 -1,437.35 2,355,884.22 273,952.42 0.47 1,416.79 MWD+SC+sag(3) 7,883.93 18.83 298.83 7,681.41 7,596.55 -159.30 -1,454.99 2,355,894.22 273,934.97 0.32 1,435.21 MWD+SC+sag(3) 7,945.72 19.02 300.29 7,739.86 7,655.00 -149.41 -1,472.42 2,355,904.43 273,917.73 0.83 1,453.45 MWD+SC+sag(3) 8,007.18 18.51 300.74 7,798.05 7,713.19 -139.37 -1,489.45 2,355,914.79 273,900.89 0.86 1,471.30 MWD+SC+sag(3) 8,069.79 18.41 301.13 7,857.44 7,772.58 -129.18 -1,506.46 2,355,925.30 273,884.09 0.25 1,489.14 MWD+SC+sag(3) 8,132.39 18.04 301.62 7,916.90 7,832.04 -118.99 -1,523.17 2,355,935.81 273,867.57 0.64 1,506.69 MWD+SC+sag(3) 8,194.55 17.85 302.51 7,976.04 7,891.18 -108.82 -1,539.40 2,355,946.28 273,851.53 0.54 1,523.76 MWD+SC+sag(3) 8,256.19 19.27 300.85 8,034.47 7,949.61 -98.53 -1,556.10 2,355,956.88 273,835.03 2.46 1,541.30 MWD+SC+sag(3) 4/8/2015 2:13:53PM Page 5 COMPASS 5000.1 Build 73 • • Halliburton i Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 31-18 Project: Kenai Gas Field TVD Reference: Actual @ 84.86usft Site: KGF 41-18 Pad MD Reference: Actual @ 84.86usft Well: KBU 31-18 North Reference: True Wellbore: KBU 31-18 Survey Calculation Method: Minimum Curvature Design: KBU 31-18 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) MOO, (ft) Survey Tool Name 8,318.95 18.98 300.51 8,093.77 8,008.91 -88.04 -1,573.79 2,355,967.71 273,817.55 0.49 1,559.84 MWD+SC+sag(3) 8,380.19 18.73 301.30 8,151.72 8,066.86 -77.87 -1,590.77 2,355,978.19 273,800.76 0.58 1,577.66 MWD+SC+sag(3) 8,441.94 17.94 301.95 8,210.34 8,125.48 -67.69 -1,607.31 2,355,988.68 273,784.42 1.32 1,595.03 MWD+SC+sag(3) 8,504.22 18.06 302.33 8,269.57 8,184.71 -57.45 -1,623.61 2,355,999.23 273,768.32 0.27 1,612.17 MWD+SC+sag(3) 8,566.45 17.68 302.40 8,328.80 8,243.94 -47.23 -1,639.73 2,356,009.75 273,752.39 0.61 1,629.14 MWD+SC+sag(3) 8,627.45 19.02 301.38 8,386.69 8,301.83 -37.09 -1,656.04 2,356,020.20 273,736.27 2.26 1,646.28 MWD+SC+sag(3) 8,689.77 18.89 301.81 8,445.63 8,360.77 -26.48 -1,673.28 2,356,031.13 273,719.23 0.31 1,664.39 MWD+SC+sag(3) 8,751.88 19.24 299.81 8,504.34 8,419.48 -16.10 -1,690.71 2,356,041.84 273,702.01 1.19 1,682.67 MWD+SC+sag(3) 8,813.80 19.31 300.73 8,562.79 8,477.93 -5.79 -1,708.36 2,356,052.47 273,684.56 0.50 1,701.16 MWD+SC+sag(3) 8,875.40 19.35 301.55 8,620.91 8,536.05 4.75 -1,725.81 2,356,063.35 273,667.31 0.45 1,719.48 MWD+SC+sag(3) 8,935.36 18.73 302.44 8,677.59 8,592.73 15.11 -1,742.40 2,356,074.02 273,650.92 1.14 1,736.92 MWD+SC+sag(3) 8,999.81 18.35 303.19 8,738.70 8,653.84 26.22 -1,759.63 2,356,085.45 273,633.91 0.70 1,755.05 MWD+SC+sag(3) 9,063.02 18.76 297.86 8,798.63 8,713.77 36.42 -1,776.94 2,356,095.97 273,616.79 2.76 1,773.20 MWD+SC+sag(3) 9,124.21 18.49 299.13 8,856.61 8,771.75 45.74 -1,794.11 2,356,105.61 273,599.80 0.80 1,791.13 MWD+SC+sag(3) 9,186.59 18.66 299.95 8,915.74 8,830.88 55.53 -1,811.40 2,356,115.73 273,582.70 0.50 1,809.22 MWD+SC+sag(3) 9,248.60 18.79 299.96 8,974.47 8,889.61 65.47 -1,828.65 2,356,126.00 273,565.64 0.21 1,827.28 MWD+SC+sag(3) 9,310.22 18.48 300.50 9,032.86 8,948.00 75.39 -1,845.66 2,356,136.23 273,548.82 0.58 1,845.10 MWD+SC+sag(3) 9,370.33 17.82 301.91 9,089.98 9,005.12 85.08 -1,861.68 2,356,146.23 273,532.99 1.32 1,861.91 MWD+SC+sag(3) 9,433.69 17.70 304.16 9,150.32 9,065.46 95.62 -1,877.88 2,356,157.06 273,516.99 1.10 1,878.98 MWD+SC+sag(3) 9,497.38 17.55 304.37 9,211.02 9,126.16 106.47 -1,893.82 2,356,168.22 273,501.26 0.26 1,895.81 MWD+SC+sag(3) 9,558.17 16.57 305.79 9,269.14 9,184.28 116.72 -1,908.41 2,356,178.73 273,486.86 1.75 1,911.26 MWD+SC+sag(3) 9,618.68 16.55 307.32 9,327.14 9,242.28 126.99 -1,922.27 2,356,189.26 273,473.21 0.72 1,925.97 MWD+SC+sag(3) 9,682.03 16.65 307.54 9,387.85 9,302.99 137.99 -1,936.64 2,356,200.53 273,459.05 0.19 1,941.25 MWD+SC+sag(3) 9,744.66 16.19 309.14 9,447.92 9,363.06 148.97 -1,950.52 2,356,211.77 273,445.37 1.03 1,956.06 MWD+SC+sag(3) 9,806.11 16.54 310.76 9,506.88 9,422.02 160.09 -1,963.79 2,356,223.14 273,432.31 0.94 1,970.26 MWD+SC+sag(3) 9,867.52 16.14 311.51 9,565.81 9,480.95 171.45 -1,976.81 2,356,234.75 273,419.52 0.74 1,984.22 MWD+SC+sag(3) 9,929.94 15.82 313.06 9,625.82 9,540.96 183.01 -1,989.52 2,356,246.54 273,407.02 0.85 1,997.91 MWD+SC+sag(3) 9,977.36 15.68 314.23 9,671.46 9,586.60 191.89 -1,998.83 2,356,255.60 273,397.88 0.73 2,007.97 MWD+SC+sag(3) 10,010.00 15.68 314.23 9,702.89. 9,618.03 198.05 -2,005.16 2,356,261.87 . 273,391.68 . 0.00 2,014.81 PROJECTED to TD brian.wheeler@hallibunon.ME.n.a.....`°'.* Car Taylor Checked By: com C.ZOI,o.m111.°.... Approved By: Y Y ...--7,„H-7-,:, ,,--.�� Date: 4/8/2015 2:13:53PM Page 6 COMPASS 5000.1 Build 73 • . KBU 31-18 Days vs Depth o 500 j . \"AKBU 31-18 Actual 1000 KBU 3148 Plan 1500 i. 2000 2500 3000 3500 - 4000 4500 Y 5000 a. -o 5500 m 6000 6500 7000 7500 8000 8500 9000 -, 9500 -- 10000 10500 11000 - 0 5 10 15 20 25 30 Days • KBU 31-18 MW vs Depth 0 KBU 31-18 Plan KBU 31-18 1000 r Actual 2000 3000 4000 5000 1 :::: 8000 9000 10000 11000 12000 8.0 9.0 10.0 11.0 12.0 13.0 14.0 Mud Density(ppg) ! • Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. KBU 31-18 Date 16-Mar-15 County Kenai Peninsula Borough State Alaska Supv. / Shane Barber CASING RECORD 5 ci-e- i C., s;/t.:, TD 1520.00 Shoe Depth: 1476.20 PBTD: 1391.29 Casing(Or Liner)Detail _ Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 103/4 _ BTC WFD 1.89 1,476.21 1,474.32 21nts 10 3/4 45.5 L-80 BTC 81.58 1,474.32 1,392.74 Fit Clr 10 3/4 BTC WFD 1.45 1,392.74 1,391.29 35 10 3/4 45.5 1-80 BTC 1,366.34 1,391.29 24.95 Hgr w/pup 10 3/4 45.5 1-80 BTC Seaboard 2.75 24.95 22.20 Landing jnt 10 3/4" BTC 22.20 22.20 0.00 Totals Csg Wt.On Hook: 55,000 Type Float Collar: Model 402 No.Hrs to Run: 12 Csg\M.On Slips: 37,000 Type of Shoe: Bull Nose/303 Casing Crew: WFD Fluid Description: 9.1 ppg Spud Mud,PV 34,YP 27 Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: 0 Centralizer Placement 2 bowspring on shoe jnt,1 centralizer middle bakerlok jnt, 14 centralizers every other jnt(17 total) CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 10 Volume pumped(BBLs). 50 Lead Slurry Type: Extended Density(ppg) 12 Volume pumped(BBLs) 142 Mixing/Pumping Rate(bpm): 5.4 Tail Slurry Type: Conventional Density(ppg) 15.4 Volume pumped(BBLs) 77 Mixing/Pumping Rate(bpm): 5.4 N Post Flush(Spacer) 1,5 Type:Fresh Water Density(ppg) 8.3 Rate(bpm): 5.5 Volume: 10 a Displacement: _j N L Type: Spud Mud Density(ppg) 9.1 Rate(bpm): 6.6 Volume(actual/talc 134/138 r' _,,,,1 FCP(psi): 500 Pump used for disp: SLB Plug Bumped? _Yes X No Bump press PJ Casing Rotated? Yes X No Reciprocated? _Yes X No %R uring job - 70 Cement returns to surface? x Yes No Spacer returns? X Yes No Vol to Surf: 48 Cement In Place At: 14:00:00 PM Date: 3/16/2015 Estimated TOC: 0 Method Used To Determine TOC: PSIG/PH samples Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry w Type: a Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): 1,5 Post Flush(Spacer) o Type: Density(ppg) Rate(bpm): Volume: NDisplacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? _Yes No Bump press Casing Rotated? Yes _No Reciprocated? Yes_No %Returns during job Cement returns to surface? Yes_No Spacer returns? Yes_No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: WELLHEAD Make Type Serial No. Size W.P. Test Head To PSIG MIN OK Remarks: This particular report pertains to the Surface Casing and Cement job for KBU 31-18 • • Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. KBU 31-18 Date 25-Mar-15 County Kenai Peninsula Borough State Alaska Supv. Rance Pederson CASING RECORD 1".j. ca6.5 is.) TD 6354.00 Shoe Depth: 6338.54 PBTD: 6252.00 Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 75/8 BTC WFD 1.66 6,338.54 6,336.88 2 Jilts 7 5/8 29.7 L-80 BTC _ 83.38 6,336.88 6,253.50 t� Flt Or 7 5/8 BTC WFD 1.33 6,253.50 6,252.17 q 7/8 D la 1 7 5/8 29.7 L-80 BTC _ 41.98 6,252.17 6,210.19 85 7 5/8 29.7 L-80 Hydril 511 3,405.09 6,210.19 2,805.10 69 7 5/8 29.7 L-80 BIC 2,783.38 2,805.10 _ 21.72 1 Pup Joint 7 5/8 29.7 L-80 BTC 2.17 21.72 19.55 Hanger 103/4"x7s/8" 0.55 19.55 19.00 Totals Csg Wt.On Hook: 170,000 Type Float Collar: Model 402 No.Hrs to Run: 15.5 Csg Wt.On Slips: Type of Shoe: Bull Nose/303 Casing Crew: WFD Fluid Description: 9.3 ppg 6%kcl/polymer,PV 13,YP 18 Liner hanger Info(Make/Model): Liner top Packer?: Yes X No Liner hanger test pressure: 0 Centralizer Placement: 1 bowspring every other joint(76),up to 1558' CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 10 Volume pumped(BBLs) 42 Lead Slurry Type: LiteCRETE Density(ppg) 13.5 Volume pumped(BBLs) 132 Mixing/Pumping Rate(bpm): 5 Tail Slurry Type: Conventional Tail Density(ppg) 15.3 Volume pumped(BBLs) 29.7 Mixing/Pumping Rate(bpm): 4 N Post Flush(Spacer) N Type: Density(ppg) Rate(bpm): Volume: n: LL Displacement: Type: 6%kcl Density(ppg) 9.3 Rate(bpm): 6 Volume(actual/calculated): 289/287 FCP(psi): 1000 Pump used for disp: Schlumberger Plug Bumped? X Yes No Bump press 1500 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job L.4s' Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: Cement In Place At: 12:03 Date: 3/25/2015 Estimated TOC: 3,354 i✓ Method Used To Determine TOC: Volume Calc vs Hole Depth Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry w Type: a Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): oPost Flush(Spacer) o Type: Density(ppg) Rate(bpm): Volume: iii)N Displacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes _No Reciprocated? _Yes_No %Returns during job Cement returns to surface? Yes_No Spacer returns? Yes No Vol to Surf: Cement In Place At Date: Estimated TOC: Method Used To Determine TOC: WELLHEAD Make Seaboard Type MBS System Serial No. Size 11 W.P. 5000 Test Head To 5000 PSIG 15 MIN Yes OK Remarks: This particular report pertains to the Intermediate Casing and Cement • i Hikorp Energy Company CASING&CEMENTING REPORT Lease&Well No. KBU 31-18 Date 4-Apr-14 County KPB State Alaska Supv. Shane Barber/Lenward Toussant CASING RECORD --/ f .' C4-S%"-i TD 10010.00 Shoe Depth: 9990.60 PBTD: (/ 9903.32 Casing(Or Liner)Detail Setting Depths No.of Jts. Size M. Grade THD Make Length Bottom Top SHOE 5" 18 DWC/C Weatherford 2.40 9,990.60 9,988.20 2 5" 18 L-80 DWC/C US STEEL 83.03 9,988.20 9,905.17 Float collar _ 5" 18 DWC/C Weatherford 1.85 9,905.17 _ 9,903.32 100 _ 5" 18 L-80 DWC/C US STEEL 4,104.49 9,903.32 _ 5,798.83 Swell Pkr _ 5" 18 L-80 DWC/C US STEEL 20.95 5,798.83 5,777.88 140 5" 18 L-80 DWC/C US STEEL 5,755.88 5,777.88 22.00 Pup 5" 18 L-80 DWC/C US STEEL 3.30 22.00 _ 18.70 Hgr 18 DWC/C Seaboard 0.70 18.70 18.00 RKB 18 18.00 18.00 0.00 Totals Csg M.On Hook: 139,000 Type Float Collar: Weatherford No.Hrs to Run: 24 Csg Wt.On Slips: 54 Type of Shoe: Weatherford Casing Crew: Weatherford Fluid Description: 4%KCL Polymer Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: 96 AT 41'F/shoe to 6087'MD CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 13 Volume pumped(BBLs) 20 Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry / Type: Class G EZ block Sw n(r e�,,-�,v.- a Density(ppg) 15.3 Volume pumped(BBLs) 128.1 Mixing/Pumping Rate(bpm): 5 G� 7 I- Post Flush(Spacer) y Type: Density(ppg) Rate(bpm): Volume: w LL Displacement: Type: 4%KCL Density(ppg) 8.5 Rate(bpm): 5 Volume(actual/calculated): 17.5/176 FCP(psi): 3000 Pump used for disp: SLB pump truck Plug Bumped? X Yes No Bump press 3500 (A 1* IA Casing Rotated? Yes X No Reciprocated'? _Yes x No %Returns during job 100 Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: 0 s-00 r'S4- Cement In Place At 0:40 Date: 4/4/2015 Estimated TOC: 4,239 Method Used To Determine TOC: Calculated w/10%washout OH,washout%determined by sweeps Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry w Type: a Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): 1- (0 W Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: w Displacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes_No %Returns during job Cement returns to surface? Yes_No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0%excess: 83.7 Total Volume cmt Pumped: 128.1 Cmt returned to surface: 0 Calculated cement left in wellbore: 128.1 OH volume Calculated: 72.9 OH volume actual: 80.19 Actual%Washout: 10 a • • 21 5024 II Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 11',..,,i. el.[ .I. 1.1 I Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED DATE 05/21/15 Ca/ /2o15 ;vl. K.BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II RECEIVED 333 W 7th Ave Ste 100 Anchorage, AK MAY 21 2015 99501 DATA TRANSMITTAL KBU 31-18 AOGGC KBU 31-18 Elog and Mudlog prints and digital data Prints: 5" Formation Log MD 2"/5" ROP-DGR-EWR-ALD-CTN MD 2" Formation Log MD 2"/5" DGR-EWR-ALD-CTN TVD 2" Gas Ratio Log MD END OF WELL REPORT 2" Drilling Engineering Log MD CD1: digital Elog Data 2 5 8 4 6 CGM 4/9,(20152:41 PM File folder ;, Definitive Survey 4/9/2015 2:41 PM File folder , DLIS+LAS 4+9/20152:41 PM File folder EMF 4x9./'20152:41 PM File folder . PDF 4+"9/20152:41 PM Filefclder t. TIFF 4x`9.+20152:42 PM Filefclder CD2: digital Mudlog Data 2 5 8 4 5 Files Currently cn the Disc 5) . EMF Lcg Vievver 4./23/2015 9:41 AM File folder Halliburtcn Log Viewer 4/23/2015 9:41 AM File folder 41, KBU 31-18 FINAL LOGS 4/23/2015 9:40 AM File folder KBU 31-18 LAS EXPORTS 4/23/2015 9:40 AM File folder 0 KBU 31-18 FINAL END OF'NELL REPORT 4/22/2015 2:25 PM PDF Document 2:344 KB Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received nval242.42,0L, (/J}2Date: VOINIMMIR 110 OF T • ,' �\\I ce THE STATE Alaska Oil and Gas o f Conservation Commission ALAsKA 333 West Seventh Avenue N x - = Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER Main: 907 279 1433 Kip ALAs1 Fax: 907.276.7542 www.aogcc.aalaska.gov Chad Helgeson Operations Manager a-- Hilcorp Alaska, LLC 3 800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Beluga/Upper Tyonek Gas Pool—Tyonek Gas Pool 1, KBU 31-18 Sundry Number: 315-229 Dear Mr. Helgeson: 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 21 sday of April, 2015 Encl. iii‘ ill 6RE STATE OF ALASKA 4.4 APR IED ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGGC 20 MC 25.280 1.Type of Request: Abandon D Plug for Redrill 0 Perforate New Pod 0 Repair Well ❑ Change Approved Program ❑ Suspend❑ Plug Perforations 0 Perforate 0• Pull Tubing ❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate D Alter Casing ❑ Omer. ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number. Exploratory ❑ Development 215-024 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ • 6.API Number. Anchorage,Alaska 99503 50-133-20649-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.510A ' Kenai Beluga Unit(KBU)31-18 • Will planned perforations require a spacing exception? Yes ❑ No 0. 9.Property Designation(Lease Number): 10.Field/Pool(s): Unit Tract 14(Fee ADL-22330) • Kenai Gas Field/Beluga/Upper Tyonek Gas Pool-Tyonek Gas Pool 1 • 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): 10,010 9,703 9,903 9,600 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 130' 16" 130' 130' Surface 1,476' 10-3/4" 1,476' 1,476' 5,210psi 2,470psi Intermediate 6,338' 7-5/8" 6,338' 6,198' 6,890psi 4,790psi Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 5" 18#/L-80 9,990' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Swell Packer;N/A 5,777'MD-5,657'TVD;N/A 12.Attachments: Description Summary of Proposal ❑✓ 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: 04/22/15 Commencing Operations: Oil ❑ Gas 0 J. WDSPL ❑ Suspended El 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR El SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson Email chelgesontc hilcorp.com Printed Name Chad Helgeson ! Title Operations Manager / Signature (�,r-jY� � O Phone 907-777-8405 Date /7//S COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 15 -21-9 Plug 21- Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: ®,_ 0 /' APPROVED BY Approved by:af47,?„.„,,L___ COMMISSIONER THE COMMISSION Date: 4.. .24_ /5---- t1-1-/7-/S' Submit Form and Form 10-403(Revised 10/2012) Approved applicatioryiyR Ifpr�f�gr�i�thf fr nre. date of approval. t� e upii t� / - RBDMS APR 2 2 2015 II ('LU�+J �'\\��jj�' //•^\1 ,Attachments � • . Well Prognosis Well: KBU 31-18 Date: 4/17/2015 Ilileorp Alaska,LL Well Name: KBU 31-18 API Number: 50-133-20649-00-00 Current Status: New Gas Well Leg: N/A Estimated Start Date: 4/22/15 Rig: N/A Reg.Approval Req'd: 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-024 First Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(C) Second Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(C) Current Bottom Hole Pressure: — 1,250 psi @ 9,589' TVD (Calculated based on surface pressure) Maximum Expected BHP: — 3,922 psi @ 3,922' TVD (Based on offset wells, EMW= 9.6ppg) Max. Allowable Surface Pressure: —2,990 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Kenai Gas Field well KBU 31-18 was drilled as a Grass roots monobore completion in April 2015 to target gas sands in the Beluga and Tyonek formations. The initial perforations were made in the Tyonek D-3C Sand and found the zone to be tight gas. The purpose of this work/sundry is to perforate the well in zones potentially could have commercial quantities of gas in the next 30 days. This well is in the Kenai Gas Field following Conservation Order 510A, (no well spacing ✓ restrictions within 1500' of the unit boundary and allows commingling from the Beluga/Upper Tyonek Pool to the Kenai Deep Tyonek Pool). E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/4,000 psi high. a. Tree connection is 9.5" OTIS 2. If necessary, bleed pressure down as requested by the RE to establish a drawdown on the formation. RA markers are shown on attached schematic. 3. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Tyonek D-2 ±9,337' ±9,351' 14' 6 Tyonek D-4A ±9,769' ±9,788' 19' 6 Tyonek D-4B ±9,800' ±9,815' 15' 6 a. Bleed tubing pressure to 500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Cement Bond Log. e. Use Gamma/CCL/to correlate. Utilize Press/Temp tool f. Record tubing pressures before and after each perforating run. g. CO 510A(no well spacing restrictions within 1500' of the unit boundary) 4. RD E-line. 5. Turn well over to production. . • Well Prognosis Well: KBU 31-18 Date: 4/17/2015 Hilcorp Alaska,LL) E-line Procedure(Contingency): 6. If zone produces sand and/or water. 7. MIRU E-line, PT lubricator to 4,000 psi Hi, 250 Low. a. Tree connection is 9.5" OTIS. 8. RIH and set 5" CIBP at depth above zone. Or 9. RIH and set 5" Casing Patch across the zone. 10. Perforate next sand using steps outlined above (1-5). (Additional sands listed on proposed completion schematic). Attachments: Proposed Well Schematic • • Kenai Gas Field Well: KBU 31-18 • El PTD: 215-024 API: 50-133-20649-00 Hi!carp Alaska,LLC CASING DETAIL Size Type Wt Grade Conn. ID Top Btm it 16" 1 16" - 109 X-56 Weld 16" Surf 130' k'`' p>>110! Driven ' Conductor10 3/4" Surf.Csg 45.5 L-80 BTC 9.95" Surf 1,476' 10-3/4" i 7 S/8" Intermediate 29.7 L 80 BTC 6.875" Surf 2,805' 7-5/8" Intermediate 29.7 L-80 Hydrill 511 6.875" 2,805' 6,338' Est TOC= TUBING 3,354' 4 5" Production 18 L-80 DWC/C HT 4.276" Surf 9,990' 41 li 4,1 * ,a" OPEN HOLE/CEMENT DETAIL 10-3/4" 142 bbls of 12#lead cement 4 165BBL's of cement in 13.5"Hole.Returns to Surface y;F` 132 BBL of 13.5#IiteCRETE Lead w/1 ppb Cemnet 42 y 7-5/8" 29.7 BBLS of 15.3#tail(No cement to surface,111bbls losses)of cement in 9-7/8"Hole.TOC 3,354'Calculated f 5„ 128 BBL's of 15.3#EZ Block cement. 100%returns. TOC 4,239' e0, Calculated a . M TP. WIIC ' 0. JEWELRY DETAIL 0.'" No. Depth ID OD Item . ° 1 18' 4.276" 11" Tubing Hanger + 't'+- 2 5,777' 4.276" 6.875" 10 ft Swell Packer(Water Swell) ., a x PERFORATION DETAIL ` ' °� 2 i Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Calc.psi Date Status 7-5/8" #• ' y. 84-6 8,774' 8,793' 8,525' 8,543' 3836 Permitted If Necessary 1, it 84-6 8,821' 8,883' 8,570' 8,628' 3856 Permitted If Necessary 86-2 8,975' 9,090' 8,715' 8,824' 3922 Permitted If Necessary D-1 9,124' 9,283' 8,856' 9,007' 2000 Permitted If Necessary RA Tag t_, D-2 9,337' 9,351' 9,058' 9,066' 700 Proposed 2-7/8" depths: i i, 6,899' D-3B 9,584' 9,610' 9,294' 9,319' 1,950 4/15/15 3.5" 131N 7,224', r i D-3D 9,692' 9,704' 9,397' 9,409' 4,200 Proposed 2-7/8" 7,513', yN D-4A 9,769' 9,788' 9,471' 9,489' 700 Proposed 2-7/8" 7,841, D-4B 9,800' 9,815' 9,508' 9,514' 700 Proposed 2-7/8" 8,126', jii 8,450', 8,739', kw' 9,231' 4 �� `may.` !; *; PBTD=9,903' MD/9,600'TVD TD=10,010' MD/9,703'ND Updated by CAH 4/15/2015 • S Schwartz, Guy L (DOA) From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Wednesday,April 15, 2015 3:56 PM To: Schwartz, Guy L(DOA) Cc: Jeremy Mardambek Subject: Kenai Gas Field KBU 31-18 (Sundry# 315-208) Peri adds Attachments: KBU 31-18 Well Schematic 04-15-15.doc;IA Casing Annulus MIT 4-13-15.pdf Guy, We perforated our 1st zone in our new drill well KBU 31-18(PTD#215-024)which was in the Tyonek Gas Pool 1 and we expected it to perform like our other wells we drilled in 2014 at KGF, however it did not react the same as the other wells. Because we were expecting gas with a decent bottom hole pressure, I did not include the other low pressure zones in the Tyonek Pool that could have been perforated. Since our results from perforating the D-3B Sand were not what we were expecting, i was wondering if I could get verbal approval to add 2 additional zones that are in the Tyonek Gas Pool 1. They are the Tyonek D-4B (9,800-9,815),Tyonek D-4A(9,769-9,788)and the D-2 (9,337-9,351'). These are shown on the attached schematic. In the future we will be including all these sands in the well when we put together the sundry so I don't have to ask for verbal approvals. Please let me know if these additions would require an additional sundry. We would follow the same steps in the approved Sundry for the perforating with pressure testing, etc. I have also attached the annulus pressure test we completed on Monday of the IA on this well. Sorry to be using up these favors, and we will get better in our permitting,so we aren't duplicating our work. Thanks Chad Helgeson i 0 . Kenai Gas Field Well: KBU 31-18 PTD: 215-024 API: 50-133-20649-00 Hik,rp Alaska,LLC CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 10-3/4" 16" 1 a Conductor- 16' Driven 109 X-56 Weld 16„ Surf 130 7 10 3/4" Surf.Csg 45.5 L-80 BTC 9.95" Surf 1,476' 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 2,805' ' �t 7-5/8" Intermediate 29.7 L-80 Hydrill 511 6.875" 2,805' 6,338' Est TOC= TUBING 3,354' ,i., /,,,t �.', 5" Production 18 L-80 DWC/C HT 4.276" Surf 9,990' k,. ' OPEN HOLE/CEMENT DETAIL ' ' 10-3/4" 142 bbls of 12#lead cement • 165BBL's of cement in 13.5"Hole.Returns to Surface ' 132 BBL of 13.5#IiteCRETE Lead w/1 ppb Cern net + 7-5/8" 29.7 BBLS of 15.3#tail(No cement to surface,111bbIs losses)of ,. ; =)� cement in 9-7/8"Hole.TOC 3,354'Calculated • ; {,;,t 5„ 128 BBL's of 15.3#EZ Block cement. 100%returns. TOC 4,239' A Calculated r.. a,r ' ' JEWELRY DETAIL • `,Y No. Depth ID OD Item , 1 18' 4.276" 11" Tubing Hanger 2 5,777' 4.276" 6.875" 10 ft Swell Packer(Water Swell) P 1' 1, • 2 7-5/8" PERFORATION DETAIL 't Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Calc.psi Date Status 84-6 8,774' 8,793' 8,525' 8,543' 3836 Permitted If Necessary RA Tag 84-6 8,821' 8,883' 8,570' 8,628' 3856 Permitted If Necessary depths: 86-2 8,975' 9,090' 8,715' 8,824' 3922 Permitted If Necessary �i2 4', D-1 9,124' 9,283' 8,856' 9,007' 2000 Permitted If Necessary 7,513', '/ D-2 9337 9351 9058 9066 700 Proposed 2-7/8" PJN 7,841', D-3B 9,584' 9,610' 9,294' 9,319' 1950 4/15/15 3.5" PJN 8,126', r' ./ D-4A 9769 9788 9471 9489 700 Proposed 2-7/8" PJN 8,450', ` 8,739', 47. D-4B 9800 9815 9508 9514 700 Proposed 2-7/8" PJN 9,231' 5" :i,, PBTD=9,903'MD/9,600'ND TD= 10,010' MD/9,703'ND Updated by CAH 4/15/2015 • 212y Seth Nolan Hilcorp Alaska, LLC �� GeoTech 3800 Centerpoint Drive Anchorage,AK 99503 Tele: 907 777-8308 EC E I`V,E D ,th.k.t.1.1.[ Fax: 907 777-8510 RE-mail: snolan@hilcorp.com APR 162015 AOGCC DATE 04/15/2015 To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 31-18 7 boxes: Dry Cuttings Transmitted herewith are cuttings from KBU 31-18 WELL SAMPLE INTERVAL KBU 31-18 130'—1330' KBU 31-18 1330'—2650' KBU 31-18 2650'—3940' KBU 31-18 3940'—5740' KBU 31-18 5740'—7450' KBU 31-18 7450'—9190' KBU 31-18 9190'—10000' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received ;•. Date: • • • , OF Tlit�t. 4, \�� s� THE STATE Alaska Oil and Gas _ � ofA LA s KA Conservation Commission = � = 333 West Seventh Avenue Alaska 99501-3572 Anchorage, GOVERNOR BILL WALKER Main: 907.279.1433 OF ALAS Y'� Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager 1,5'- 0a1? Hilcorp Alaska, LLC , 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Beluga/Upper Tyonek Gas and Tyonek Gas Pools, KBU 31-18 Sundry Number: 315-208 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner ‘ 1( DATED this 7 day of April, 2015 Encl. • III RECEIVED STATE OF ALASKA APR 0 8 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon D Plug for Redrill 0 Perforate New Pod 0 Repair Well 0 Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate 0 • Pull Tubing ❑ Time Extension ❑ Operations Shutdown 0 Re-enter Susp.Well ❑ Stimulate❑ Alter Casing ❑ Other. e T to L [] 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number. Exploratory ❑ Development 0• 215-024 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20649-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? (C.O.510 ` Kenai Beluga Unit(KBU)31-18 Will planned perforations require a spacing exception? Yes ❑ No 0 • 9.Property Designation(Lease Number): 10.Field/Pool(s): / ✓ Unit Tract 14(Fee ADL-22330) Kenai Gas Field/Beluga/Upper Tyonek Gas Pool-Tyonek Gas Pool 1 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): 10,010 9,703 9,903 9,600 - N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 130' 16" 130' 130' Surface 1,476' 10-3/4" 1,476' 1,476' 5,210psi 2,470psi Intermediate 6,338' 7-5/8" 6,338' 6,198' 6,890psi 4,790psi Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 5" 18#/L-80 9,990' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Swell Packer;N/A 5,777'MD-5,657'ND;N/A 12.Attachments: Description Summary of Proposal 0 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: 04/13/15 Oil ❑ Gas 0- WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ 0 WAG 0 Abandoned 0 Commission Representative: GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson Email chelgeson a hilcorq.com Printed Name al---f's-777. Cad Helgeson Title Operations Manager Signature Phone 907-777-8405 Date 1/7//5— COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 316'- toy Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance 0 Other: t/ (�h;+; te,A-erw,) Spacing Exception Required? Yes ❑ No U Subsequent Form Required: / i C� f APPROVED BY A / Approved by: COMMISSIONER THE COMMISSION Date::e�L� C' /6 y�9'N Submit Form and Form 10-403(Revised 1 a'012) ' Slta''VV LBDMS<JW APR 9 2015/ /< �'-Ls � , H • . Well Prognosis Well: KBU 31-18 Date: 4/7/2015 IliIcorp Alaska.LL Well Name: KBU 31-18 API Number: 50-133-20649-00-00 Current Status: New Gas Well Leg: N/A Estimated Start Date: 4/13/15 Rig: N/A Reg.Approval Req'd: 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-024 First Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (C) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (C) Current Bottom Hole Pressure: -0 psi @ 9,589' ND (No open perforations) Maximum Expected BHP: - 3,922 psi @ 3,922' TVD (Based on offset wells, EMW= 9.6ppg) Max. Allowable Surface Pressure: -2,990 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Kenai Gas Field well KBU 31-18 was drilled as a Grass roots monobore completion in April 2015 to target gas sands in the Beluga and Tyonek formations. The purpose of this work/sundry is to perforate the well for the initial completion in the Tyonek D sands and Lower Beluga. Notes Regarding Wellbore Condition • Plan to tag with slickline before running E-line. l i.1C4t J �E►s'�� • Will run Cement Bond Log before perforating. Y44_5-rs • Pressure test casing to 9,000 psi and chart for 30 min. - �� - v.a- ��s • MIRU Coil Tubing and perform BOPE Test to 250/4,500 psi to displace well over to Nitrogen. • Well will be displaced with Nitrogen before initial perforating at+/-850 psi SITP. E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/4,000 psi high. Note that the well is pressurized with Nitrogen approximately 850 psi. a. Tree connection is 9.5" OTIS 2. If necessary, bleed Nitrogen pressure down as requested by the RE to establish a drawdown on the formation. RA markers are shown on attached schematic. 3. RIH and perforate the following interval: Zone Sands Top (MD) Btm (MD) FT SPF (74- Tyonek D-3B ±9,584' ±9,610' 26' 6 �i /� I a. Bleed tubing pressure to 850 psi before perforating. /CI> b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Cement Bond Log(pending Tie-in log). e. Use Gamma/CCL/to correlate. Utilize Press/Temp tool if available. • • Well Prognosis Well: KBU 31-18 Date: 4/7/2015 'Mean)Alaska,LU f. Record tubing pressures before and after each perforating run. g. CO 510A(no well spacing restrictions within 1500' of the unit boundary) 4. RD E-line. 5. Turn well over to production. E-line Procedure(Contingency): 6. If zone produces sand and/or water. 7. MIRU E-line, PT lubricator to 4,000 psi Hi, 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be +/- 2,500 psi (remaining gas or applied Nitrogen pressure). 8. RIH and set 5" CIBP at depth above zone. Or 9. RIH and set 5" Casing Patch across the zone. 10. Perforate next sand using steps outlined above (1-5). (Additional sands listed on proposed completion • (5::(c5,4(1 C--? 14P4) Attachments: As-built Well Schematic /..?(-1t-;'_lC Proposed Well Schematic •S . Kenai Gas Field Well: KBU 31-18 11 PTD: 215-024 API: 50-133-20649-00 Hikorp Alaska,LLC CASING DETAIL Size Type Wt Grad Conn. ID Top Btm 16" 1 16" Conductor— 109 X-56 Weld 16" Surf 130' [. Driven 10-3/4" Surf. Csg 45.5 L-80 BTC 9.95" Surf 1,476' 10-3/4" 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 2,805' 7-5/8" Intermediate 29.7 L-80 Hydrill 511 6.875" 2,805' 6,338' Est TOC= 3,354' TUBING 5" Production 18 L-80 DWC/C HT 4.276" Surf 9,990' • OPEN HOLE/CEMENT DETAIL 142 bbls of 12#lead cement 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface 132 BBL of 13.5#IiteCRETE Lead w/1 ppb Cemnet 7-5/8" 29.7 BBLS of 15.3#tail(No cement to surface,111bbls losses)of cement in 9-7/8"Hole.TOC 3,354'Calculated 5„ 128 BBL's of 15.3#EZ Block cement. 100%returns. TOC 4,239' Calculated JEWELRY DETAIL No. Depth ID OD Item • 1 18' 4.276" 11" Tubing Hanger 2 5,777' 4.276" 6.875" 10 ft Swell Packer(Water Swell) ,�. 2B 7-5/8" RA Tag depths: s 6,908', 7,233', 7,522', 7,852', um 8,136', 8,461', 8,751', - 9,244' 5", PBTD=9,903' MD/9,600'TVD TD=10,010' MD/9,703'TVD Updated by CAH 4/6/2015 Kenai Gas Field • PROPOSED 0 Well: KBU 31-18 PTD: 215-024 API: 50-133-20649-00 Hileorp Alaska,LLC CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16"44.x . ' 1 .4 „ Conductor- 16 109 X-56 Weld 16" Surf 130' Driven + , 10-3/4" Surf. Csg 45.5 L-80 BTC 9.95" Surf 1,476' 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 2,805' 10-3/4" :j 7-5/8" Intermediate 29.7 L-80 Hydrill 511 6.875" 2,805' 6,338' Est TOC= TUBING 3,354' 5" Production 18 L-80 DWC/C HT 4.276" Surf 9,990' - OPEN HOLE/CEMENT DETAIL ' 10-3/4" 142 bbls of 12#lead cement 165BBL's of cement in 13.5"Hole.Returns to Surface 132 BBL of 13.5#IiteCRETE Lead w/1 ppb Cemnet 7-5/8" 29.7 BBLS of 15.3#tail(No cement to surface,ilibbls losses)of cement in 9-7/8"Hole.TOC 3,354'Calculated 5„ 128 BBL's of 15.3#EZ Block cement. 100%returns. TOC 4,239' Calculated . JEWELRY DETAIL No. Depth ID OD Item 1 18' 4.276" 11" Tubing Hanger 2 5,777' 4.276" 6.875" 10 ft Swell Packer(Water Swell) 26 X ,,,,,,, ,,,_,/,/te t „T._,,,,,,/ a,G � -. .,-"`"-ily.1,41--14444:1 6, . /P v &--- 7-5/8' PERFORATION DETAIL P Aik 1 Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) Calc.psi Date Status 84-6 8,774' 8,793' 8,525' 8,543' 3836 Future If Necessary RA Tag 84-6 8,821' 8,883' 8,570' 8,628' 3856 Future If Necessary depths: 86-2 8,975' 9,090' 8,715' 8,824' 3922 Future If Necessary 7,233', D-1 9,124' 9,283' 8,856' 9,007' 2000 , 5/15/15 If Necessary 7,522', • D-3B 9,584' 9,610' 9,294' 9,319' 1950 1 4/13/15 Proposed • 7,852', 8,136', 8,461', 8,751', -1 _-- �‘6Z.--c7 d ">`' 9,244' /J 5" ' ;. ' PBTD=9,903' MD/9,600'TVD TD= 10,010' MD/9,703'ND Updated by CAH 4/7/2015 r • 0 0\��\�j/,-'sv THE STATE Alaska Oil and Gas �w _?��- 9� Of Conservation Commission �-= - � ALASI:A ;. 1 si} z____ z ,_,�__ 333 West Seventh Avenue �. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OA; " ,�. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Monty M. Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Beluga/Upper Tyonek Gas Pool, KBU 31-18 Hilcorp Alaska, LLC Permit No: 215-024 (revised) Surface Location: 413' FEL, 707' FNL, SEC. 18, T4N, R11W, SM, AK Bottomhole Location: 398' FNL, 2471' FWL, SEC. 18, T4N, R11W, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to drill the above referenced development well. This permit supersedes and replaces the permit previously issued for this well dated February 25, 2015. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 1-',A•ti /a -e-e---14,____ Cathy P. Foerster Chair DATED this i 14-ky of March, 2015. RECEIVED STATE OF ALASKA A OIL AND GAS CONSERVATION C01111,N MAR 0 6 2015 PERMIT TO DRILL Revised 20 AAC 25.005 AOGCO 1a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone Q • 1c.Specify if well is proposed for: Drill ' ❑✓ Lateral ❑ Stratigraphic Test ❑ Development-Gas E i Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. .Q2235244 Kenai Beluga Unit(KBU)31-18 - 6- 3.Address: 6.Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive,Suite 1400 Anchorage AK 99503 MD: 10,000' • TVD: 9,683' • Kenai Gas Field 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): 4.1.(.- Beluga/Upper Tyonek Gas Pool Surface: ' 413'FEL,707'FNL,Sec 18,T4N,R11W,SM,AK - Unit Tract '(Fee Lease 40281212) 2_2_3:?-177),, ?r f , et,cc.Tyonek Gas Pool 1 - Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 777'FNL, 1439'FEL,Sec 18,T4N,R11W,SM,AK N/A 3/15/2015 Total Depth: 9.Acres in Property: 14. Distance to Nearest Property: 398'FNL,2471'FWL,Sec 18,T4N,R11W,SM,AK • 2494.04 acres 5,100' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 85 ft • 15.Distance to Nearest Well Open Surface: x-275392 • y- 2356026 - Zone-4 GL Elevation above MSL: 67 ft • to Same Pool: 1,234' 16.Deviated wells: Kickoff depth: 2,000 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 19 degrees Downhole: 4300 psi Surface: 3332 psi 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) 13-1/2" 10-3/4" 45.5 L-80 Buttress 1,500' Surf Surf 1,500' • 1,500' 929 ft3 9-7/8" 7-5/8" 29.7 L-80 BTC 6,100' Surf Surf 6,100' . 5,900' 858 ft3 6-3/4" 5" 18 L-80 DWC 10,000' Surf Surf 10,000' , 9,683' 730 ft3 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): Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑✓ BOP Sketch ❑ Drilling Program❑ Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Monty M Myers Email mmyers@hilcorp.com Printed Name M o K4 7 ,A,1 M re r, S Title Drilling Engineer e::: ,5:::, Signature -�. • Phone 907-777-8431 Date 3 (. 2 0 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: 216-02.4 rtviSeci• 50-r 3'20 fvy 9-O c -00 Date: 2,12.5/2-6 1 6 requirements. Conditions of approval: If bo is checked,well not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Other: .)E 35-o 0 s. av (G5 Z S ele,g��p es req'd: Yes❑ No[✓� Mud log req'd:Yes❑ No[ I J O!�•�- H25 measures: Yes❑ No[, " Directional svy req'd:Yes[✓` Nor] bit/cit.-Fe,/ w 4 tV Spacing exception req'd: Yes❑ NoR Inclination-only svy req'd:Yes❑ No© r * Sew /1 v-.a 1j APPROVED BY Si Approved by: — ♦ COMMISSIONER THEE COMMISSION Date:3^,/' /\ !dam ov Submit Form and Form 10-401(Revised 10/2012) QsRrrlitGiIicPJ 7'br�1, the fr the date of approval(20 AAC 25.0 (g)) Attachments in Duplicate /1j.,/�T' 3, el-,/S' • Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com Rileorp Alaska,LLC March 6th, 2015 Commissioner RECEIVED Alaska Oil & Gas Conservation Commission 333 W. 7t"Avenue MAR 0 6 2015 Anchorage, Alaska 99501 ACC Re: KBU 31-18 Dear Commissioner, Enclosed for review and approval is a revision to the Permit to Drill for KBU 31-18. The"as-built"surface location plat is attached and differs from the"as-staked"surface plat by<10 ft. A revised directional plan is included that reflects this slight change of surface location. The directional plan was also slightly modified to reduce anti-collision concerns of previous plan. The most recent version (WP 4.0) is attached. There is no change to TPH or BHL. ` I If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska,LLC Page 1 of 1 • s SECTION LINE NTS 2"ALUMINUM CAP. i GLA ' O *CAUTION* T«vS 1 s SB 0..... 'q HIGH PRESSURE S76 s17 �O LATERAL GAS CIA PIPELINE TO 41-7 LA SECTION 18, T4N, 11W S.M., AK- 1937 N 2356515.90 E 275647.08 I • \O1 -' EXISTING DRAINAGE � RETENTION BASIN 707'FNL(NTS) \ KBU 24-7X KBU 41-18X KBU 14-8 UI1-17X KBU 21-18 V TBM04-15-22 KBU 31-18 AS-BUILT NAD27 ELEV:66.66' 16" CONDUCTOR 10.2'X10.7' GRID N: 2356026.010 SHUT DOWN BLDG.— a 11.8'X 12.6' GRID E:275392.650 CONTROL BLDG. 0. LATITUDE: 60°26'35.3997"N 14.2'X16.3' i� BLDG. LONGITUDE: 151°14'37.2662"W ,/r v ELEV.: 66.86 FT.(MSL) 10.4'X20.0' BLDG. A0.3 1-2"ALUMINUM CAP -'S KBU 33-7 c\A S `'' \ 6.4'X 10.0' k ` 1 , A BLDG. -12.0'X 40. ' EDGE OF V .N c,�� ® OFFICE PAD ,41 'Pr�‘S ` BLDG. 14.4'x 16.8' ® ��1 h --S 8.2'BLDG. 4 13'FEL(NTS)-N-.-- BLDG. A WATER WELL ��J BLDG. .6.11-17 4 • KBU 24-7 INJECTION WELL 3 30• 12.3'X12.3' A 4 I-- BLDG. K.U.41-18 z I> Az el w EDGE OF t?,, z p� EXISTING PAD K.U.13-8 g) EQUIP. 'a, -Z1JjJ z BLDG. CONTACTOR BLDG. 9.3'X9.3' z A 5 r PRODUCTION 30Ie — 4 BLDG. 0 •� g' �)� FACILITIES - \ i� l / METER\ p U KU 12-17 / o LDG. \ W KENAI GAS FIELD HYDRATIONGEL .`A\� L9.3'x9.6' Cl)PAD 41-18 UTILITY TANK HEATER BLDG. P ' S 1I �*•49TH%\ *�j j% j N 0 R TH 1.BASIS OF HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD27 y��/,y*//J/J64 _ % ZONE 4 DETERMINED BY A DIRECT TIE TO USC&GS TRI STA AUDRY HAVING A j , '•.STAN A. MCLANE i i °i1111111111111111111j0:IiiiIIIIIIIII��IIIN" PUBLISHED POSITION OF LAT.60°30'50.559"N LONG.151°16'37.445"W s • 4637-S _ N:2382045.42 E:269866.75 i -••. 25 FED 15 2)BASIS OF VERTICAL DATUM IS MEAN SEA LEVEL. i� `'b •••••'••�P� SCALE 3)SOUTHWEST CORNER SEC.6 COORDINATE DETERMINED FROM DIRECT _ i1' ESSIANAV `�, SURVEY TIE TO THE TO EXISTING BLM WC FORE NW CORNER SEC.7 AND 1 I II\\\\ i 100 200 WC Y4 CORNER SECTIONS 6&7 RECOVERED AND NOT THE PROTRACTED I I FEET 1 SECTION CORNER VALUES. PROJECT KBU 31-18 WELL ON KGF PAD 41-18 REVISION: 0 // Consulting Inc DRAWN BY: ICB Mii . AS BUILT SURFACE LOCATION DIAGRAM DATE: 2/25/15 II NAD27 SCALE: 1"=100' PROJECT NO. 157002 ENGINEERING I MAPPING I SURVEYING/TESTING BOOK NO. - P.O.BOX 468 SOLDOTNA,AK.99669 LOCATION SHEET VOICE:(907)283-4218 FAX:(907)2833265 EMAIL:SAMCLANE@MCLANECG.COM I il.corp Alaska,LLC S18 T4N R11 W SEWARD MERIDIAN, ALASKA 1 OF 1 1 • Hilcorp Energy Company Kenai Gas Field KGF 41-18 Pad Plan: KBU 31-18 KBU 31-18 Plan: KBU 31-18 WP4 Standard Proposal Report 27 February, 2015 r.,-.. -. HALLIBURTON Sperry Drilling Services PT6ect: Kenai Gas FieldWE DETAILS: Plan: 1-18 NAD 1927(NADCON CONUS) Alaska Zone 04 HALLIBURTON Site: KGF 41-18 Pad Ground Level: 66.86 Well: Plan: KBU 31-18 +N/-S +E/-W Northing Easting Latittude Longitude Slot Sperry Drilling 0.00 0.00 2356026.01 275392.65 60.4431666 -151.2436851 Wellbore: KBU 31-18 Plan: KBU 31-18 WP4 REFERENCE INFORMATION ' Co-ordinate(N/E)Reference: Well Plan:KBU 31-18,True North DDI=5.219Vertical(TVD)Reference: Actual @ 84.86usft - Measured Depth Reference: Actual @ 84.86usft Calculation Method: Minimum Curvature -500- - FORMATION TOP DETAILS T o- r TVDPathVDssPath MDPath Formation - 3977.86 3893.00 4036.18 Sterling - 4240.86 4156.00 4308.52 Sterling 5.2 500- 500 4529.86 4445.00 4607.77 Sterling Pool 6 4775.86 4691.00 4862.50 Upper Beluga 1000- 1000 5414.86 5330.00 5524.17 Middle Beluga - 6143.86 6059.00 6279.03 Lower Beluga - 7283.86 7199.00 7461.68 Upper Tyonek 10 3/4" 1500- 8770.86 8686.00 9033.49 Tyonek D1 8952.86 8868.00 9225.88 Tyonek D2 9224.86 9140.00 9513.39 Tyonek D3B 2000- 2000 9383.86 9299.00 9681.46 Tyonek D4 2500- 2500 3000- 3000 35p0 3500- c pp0 co 4000-Sterling n - o --Sterling 5.2 LO 4500 4500--Sterling Pool 6 a _ - Upper Beluga- 00 0) - 50 p 5000- 0 - c) 500 C - Middle Beluga 5500- D = 6000 F 6000- --Lower Beluga- - 7 5/8" 6500- -_ 10p0 KBU 31-18 tgtl wp3 7000- -- Upper Tyonek- - -5"00 7500- _ 6p00 8000- - g500 8500- _, Tyonek D1 .000 9000--Tyonek D2 KBU 31-18 tgt2 wp3 -- -Tyonek D3B 95p0 - Tyonek 04- 9500- 5" 10000- KBU 31-18 WP4 IIIIIIIiIIIII 1 11 1 1 IIIiiIIIIII1 1 1 1 1 I 1 1 i i I i I 1 1 I I111I I 1 1 1 IIIIIiiii -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 n Ililcorp Vertical Section at 275.07° (1250 usft/in) HALLIBURTON Project: Kenai Gas Field + SECTION DE• n,....---,orvmnrr Site: KGF 41-18 Pad Sec MD Inc Azi ND TVDSS +N/-S +E/-W Northing Fasting DLeg TFace VSec Target Well: Plan:KBU 31-18 1 18.00 0.00 0.00 18.00 -66.86 0.00 0.00 2356026.01 275392.85 0.00 0.00 0.00 Wellbore: KBU 31-18 2 2000.00 0.00 0.00 2000.00 1915.14 0.00 0.00 2358028.01 275392.65 0.00 0.00 0.00 1100 Plan: KBU 31-18 WP4 3 2501.39 15.04 258.88 2495.65 2410.79 -12.65 -64.20 2358014.58 275328.22 3.00 258.86 62.83 4 7149.11 15.04 258.86 6984.13 6899.27 -245.75 -1247.64 2355803.87 274140.65 0.00 0.00 1221.03 CASING DETAILS 5 7453.22 18.98 299.22 7275.86 7191.00 -229.17 -1329.83 2355822.00 274058.79 4.00 91.65 1304.36 KBU 31.18 1gt1 wp3 1000 8 7461.83 18.91 300.26 7284.00 7199.14 -227.78 -1332.25 2355823.43 274056.39 4.00 102.54 1306.90 TVD MD Name Size 7 9513.39 18.91 300.26 9224.86 9140.00 107.21 -1906.50 2356189.19 273488.60 0.00 0.00 1908.51 KBU 31-181012 wp3 1500.00 1500.00 10 3/4" 10-3/4 8 10000.00 18.91 300.26 9685.21 9600.35 188.66 -2042.70 2358251.20 273353.93 0.00 0.00 2051.20 6357.28 6500.00 7 5/8" 7-5/8 900 9685.21 10000.00 5" 5 REFERENCE INFORMATION SURVEY PROGRAM 800 Co-ordinate(N/E)Reference:Well Plan:KBU 31-18,True North Date:2015-01-28T00:00:00 Validated:Yes Version: DDI=5.219 Vertical(TVD)Reference:Actual l/84.86usft Measured Depth Reference:Actual @ 84.86usft Depth From Depth To Survey/Plan Tool Calculation Method:Minimum Curvature 18.00 1500.00 KBU 31-18 WP4 MWD+SC+sag 700 1500.00 6500.00 KBU 31-18 WP4 MWD+SC+sag 6500.00 10000.00 KBU 31-18 WP4 MWD+SC+sag WELL DETAILS:Plan:KBU 31-18 600 Ground Level: 66.88 +N/-S +E/-W Northing EastInn Latittude Longitude 0.00 0.00 2356026.01 275392.65 80.4431666 -151.2436851 500 S_ 400 S o KBU 31.18WP4 v i 300 i -j- i Stott Dir 37100':2000'MD,2000TVD 5.. 200 1.,. End Dir:2503'MD,2497 TVD 1 1 • 1 • too 4"? SIM Dir 4./100':7157 MD,6991'TVD • �I2 I v 0 1;131.131-18 C wy3 50 w a End Dir:7471'MD,7292'TVD ig DD Poly 95%cont. ti. I ,+ 5 `, 4 g o 2000`10 3/4" 1 S -100 hyo I 0 8 0 7 5/m o $ 0 4111°111113 / KBU 31-18 tett wp3 % o ' o -200 0 DG Poly 95%cont. 0 8 0 0 -300 - -000 T M Azimuths to True North Magnetic North:16.41" Magnetic Field -500 Strength:55295.2snT Dip Angle:73.43° Date:11/18/2015 Model:BGGM2014 -600 111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111J -2200 -2100 -2000 -1900 -1800 -1700 -1600 -1500 -1400 -1300 -1200 -1100 -1000 -900 -800 -700 -600 -500 -400 -300 -200 I West(-)/East(+)(250 usft/in) ill`-I1ICOrp HALLIBURTON KBU 13-8 I.U41-]8 � v 300— o I 2</ o Sperry Drilling Services KBU 41-18X ,,, I `O�� 0 Project: Kenai Gas Field - KBU 4-8\\ r\I' Site: KGF 41-18 Pad - 2000 I '0 43-07Y KBU 32-08 Well: Plan: KBU 31-18 - Wellbore: KBU 31-18 5 200— : 32-07WPI.0 1.°30'`' , Plan: KBU 31-18 WP4 _ 1000 KBU 11.17X c 0 1000 + 100— 7j - i o 10000 1 - 5333— KU 11-17 0 0— 2000 _ KBU 31-18 WP4 / 4800— _ 5553 -100— '- KU 13-8 1000 • i00 4267— -400 -333 -267 -200 -133 . -67 0 67 - West(-)/East(+)(100 usft/in) - 8000 - KBU 32-08 3733- - KBU 32-07 WP1.0 - -'000 KBU 13-8 3200— g000 - •,000 - 6000 C 0000 2667— Spoo o - KBU 43-07Y co 9301 5000 -v 5000 - 00 0 2133— 30 - _ 4000 9000 KBU 14-8 v - 6p00 000 1600- - 600 O - 5000 3000 5p00 3 30 _ 000 00 1067— 90Oo �b - 0648 00 - KBU 41-18X ,.2000 3 '�00 KU 11-17 i 533— KBU3I-18 WP4 / eo i J w`' °� - o00 % 0 o0 0— o, r:,a0oO- a4 -.553 n 1000 7915 0 o o T M Azimuths to True North - KBU 11-17X Magnetic North:16A10- ° 0 Magnetic Field 533— Strength:55295.2snT - Dip Angle:73.43° Date:11/1B/2015 Model:BGGM2014 - - I II I I I II I I I I II I I H I I I 1 I I I I 1 I I I l I I l i I 1 I I I l 1 I I I l 1 I I I I i l l -2133 -1600 -1067 -533 0 533 1067 1600 2133 2667 3200 West(-)/East(+)(800 usft/in) [lilvorp S 4110 Halliburton ALL'B Li RTO NI Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 31-18 Company: Hilcorp Energy Company TVD Reference: Actual @ 84.86usft • Project: Kenai Gas Field MD Reference: Actual @ 84.86usft • Site: KGF 41-18 Pad North Reference: True Well: Plan:KBU 31-18 Survey Calculation Method: Minimum Curvature • Wellbore: KBU 31-18 Design: KBU 31-18 WP4 Project Kenai Gas Field Map System: US State Plane 1927(Exact solution) • System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) . Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site KGF 41-18 Pad Site Position: Northing: 2,356,042.86 usft Latitude: 60.4431928 From: Lat/Long Easting: 275,008.97usft Longitude: -151.2458107 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.08° Well Plan:KBU 31-18 Well Position +N/-S 0.00 usft Northing: 2,356,026.01 usft Latitude: 60.4431666 +E/-W 0.00 usft Easting: 275,392.65 usft Longitude: -151.2436851 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: . 66.86 usft Wellbore KBU 31-18 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 11/18/2015 16.41 73.43 55,295 Design KBU 31-18 WP4 Audit Notes: Version: Phase: PLAN Tie On Depth: 18.00 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 275.07 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°I100usft) (°/100usft) (°l100usft) (°) 18.00 0.00 0.00 18.00 -66.86 0.00 0.00 0.00 0.00 0.00 0.00 2,000.00 0.00 0.00 2,000.00 1,915.14 0.00 0.00 0.00 0.00 0.00 0.00 2,501.39 15.04 258.86 2,495.65 2,410.79 -12.65 -64.20 3.00 3.00 0.00 258.86 7,149.11 15.04 258.86 6,984.13 6,899.27 -245.75 -1,247.64 0.00 0.00 0.00 0.00 7,453.22 18.98 299.22 7,275.86 7,191.00 -229.17 -1,329.83 4.00 1.30 13.27 91.65 7,461.83 18.91 300.26 7,284.00 7,199.14 -227.78 -1,332.25 4.00 -0.84 12.05 102.54 9,513.39 18.91 300.26 9,224.86 9,140.00 107.21 -1,906.50 0.00 0.00 0.00 0.00 10,000.00 18.91 300.26 9,685.21 9,600.35 186.66 -2,042.70 0.00 0.00 0.00 0.00 2/27/2015 1:43:12PM Page 2 COMPASS 5000.1 Build 73 0 0 Halliburton -I>ALLIBU ' Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 31-18 Company: Hilcorp Energy Company TVD Reference: Actual @ 84.86usft Project: Kenai Gas Field MD Reference: Actual @ 84.86usft Site: KGF 41-18 Pad North Reference: True Well: Plan:KBU 31-18 Survey Calculation Method: Minimum Curvature Wellbore: KBU 31-18 Design: KBU 31-18 WP4 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -66.86 18.00 0.00 0.00 18.00 -66.86 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 100.00 0.00 0.00 100.00 15.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 200.00 0.00 0.00 200.00 115.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 300.00 0.00 0.00 300.00 215.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 400.00 0.00 0.00 400.00 315.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 500.00 0.00 0.00 500.00 415.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 600.00 0.00 0.00 600.00 515.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 700.00 0.00 0.00 700.00 615.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 800.00 0.00 0.00 800.00 715.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 900.00 0.00 0.00 900.00 815.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 1,000.00 0.00 0.00 1,000.00 915.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 1,100.00 0.00 0.00 1,100.00 1,015.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 1,200.00 0.00 0.00 1,200.00 1,115.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 1,300.00 0.00 0.00 1,300.00 1,215.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 1,400.00 0.00 0.00 1,400.00 1,315.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 1,500.00 0.00 0.00 1,500.00 1,415.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 10 314" 1,600.00 0.00 0.00 1,600.00 1,515.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 1,700.00 0.00 0.00 1,700.00 1,615.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 1,800.00 0.00 0.00 1,800.00 1,715.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 1,900.00 0.00 0.00 1,900.00 1,815.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 2,000.00 , 0.00 0.00 2,000.00 1,915.14 0.00 0.00 2,356,026.01 275,392.65 0.00 0.00 Start Dir 3°/100':2000'MD,2000'TVD 2,100.00 3.00 258.86 2,099.95 2,015.09 -0.51 -2.57 2,356,025.55 275,390.07 3.00 2.51 2,200.00 6.00 258.86 2,199.63 2,114.77 -2.02 -10.27 2,356,024.18 275,382.35 3.00 10.05 2,300.00 9.00 258.86 2,298.77 2,213.91 -4.54 -23.07 2,356,021.90 275,369.50 3.00 22.58 2,400.00 12.00 258.86 2,397.08 2,312.22 -8.07 -40.95 2,356,018.72 275,351.56 3.00 40.07 2,501.39 15.04 258.86 2,495.65 2,410.79 -12.65 -64.20 2,356,014.58 275,328.22 3.00 62.83 2,502.56 15.04 258.86 2,496.78 2,411.92 -12.70 -64.50 2,356,014.53 275,327.92 0.00 63.13 End Dir :2503'MD,2497'TVD 2,600.00 15.04 258.86 2,590.88 2,506.02 -17.59 -89.31 2,356,010.11 275,303.03 0.00 87.41 2,700.00 15.04 258.86 2,687.46 2,602.60 -22.61 -114.78 2,356,005.57 275,277.47 0.00 112.33 2,800.00 15.04 258.86 2,784.03 2,699.17 -27.62 -140.24 2,356,001.04 275,251.92 0.00 137.25 2,900.00 15.04 258.86 2,880.60 2,795.74 -32.64 -165.70 2,355,996.51 275,226.37 0.00 162.17 3,000.00 15.04 258.86 2,977.18 2,892.32 -37.65 -191.16 2,355,991.97 275,200.82 0.00 187.09 3,100.00 15.04 258.86 3,073.75 2,988.89 -42.67 -216.63 2,355,987.44 275,175.27 0.00 212.01 3,200.00 15.04 258.86 3,170.32 3,085.46 -47.68 -242.09 2,355,982.91 275,149.71 0.00 236.93 3,300.00 15.04 258.86 3,266.90 3,182.04 -52.70 -267.55 2,355,978.37 275,124.16 0.00 261.85 3,400.00 15.04 258.86 3,363.47 3,278.61 -57.71 -293.01 2,355,973.84 275,098.61 0.00 286.76 3,500.00 15.04 258.86 3,460.05 3,375.19 -62.73 -318.48 2,355,969.31 275,073.06 0.00 311.68 3,600.00 15.04 258.86 3,556.62 3,471.76 -67.75 -343.94 2,355,964.77 275,047.51 0.00 336.60 3,700.00 15.04 258.86 3,653.19 3,568.33 -72.76 -369.40 2,355,960.24 275,021.96 0.00 361.52 3,800.00 15.04 258.86 3,749.77 3,664.91 -77.78 -394.86 2,355,955.71 274,996.40 0.00 386.44 3,900.00 15.04 258.86 3,846.34 3,761.48 -82.79 -420.33 2,355,951.17 274,970.85 0.00 411.36 4,000.00 15.04 258.86 3,942.91 3,858.05 -87.81 -445.79 2,355,946.64 274,945.30 0.00 436.28 2/27/2015 1:43:12PM Page 3 COMPASS 5000.1 Build 73 • 0 Halliburton LLIB Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 31-18 Company: Hilcorp Energy Company TVD Reference: Actual @ 84.86usft Project: Kenai Gas Field MD Reference: Actual @ 84.86usft Site: KGF 41-18 Pad North Reference: True Well: Plan:KBU 31-18 Survey Calculation Method: Minimum Curvature Wellbore: KBU 31-18 Design: KBU 31-18 WP4 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,893.00 4,036.18 15.04 258.86 3,977.86 3,893.00 -89.62 -455.00 2,355,945.00 274,936.05 0.00 445.30 Sterling 4,100.00 15.04 258.86 4,039.49 3,954.63 -92.82 -471.25 2,355,942.11 274,919.75 0.00 461.20 4,200.00 15.04 258.86 4,136.06 4,051.20 -97.84 -496.72 2,355,937.57 274,894.20 0.00 486.12 4,300.00 15.04 258.86 4,232.64 4,147.78 -102.85 -522.18 2,355,933.04 274,868.64 0.00 511.04 4,308.52 15.04 258.86 4,240.86 4,156.00 -103.28 -524.35 2,355,932.65 274,866.47 0.00 513.16 Sterling 5.2 4,400.00 15.04 258.86 4,329.21 4,244.35 -107.87 -547.64 2,355,928.50 274,843.09 0.00 535.96 4,500.00 15.04 258.86 4,425.78 4,340.92 -112.88 -573.10 2,355,923.97 274,817.54 0.00 560.88 4,600.00 15.04 258.86 4,522.36 4,437.50 -117.90 -598.57 2,355,919.44 274,791.99 0.00 585.80 4,607.77 15.04 258.86 4,529.86 4,445.00 -118.29 -600.54 2,355,919.09 274,790.00 0.00 587.74 Sterling Pool 6 4,700.00 15.04 258.86 4,618.93 4,534.07 -122.92 -624.03 2,355,914.90 274,766.44 0.00 610.72 4,800.00 15.04 258.86 4,715.51 4,630.65 -127.93 -649.49 2,355,910.37 274,740.89 0.00 635.64 4,862.50 15.04 258.86 4,775.86 4,691.00 -131.06 -665.41 2,355,907.54 274,724.92 0.00 651.21 Upper Beluga 4,900.00 15.04 258.86 4,812.08 4,727.22 -132.95 -674.95 2,355,905.84 274,715.33 0.00 660.56 5,000.00 15.04 258.86 4,908.65 4,823.79 -137.96 -700.42 2,355,901.30 274,689.78 0.00 685.48 5,100.00 15.04 258.86 5,005.23 4,920.37 -142.98 -725.88 2,355,896.77 274,664.23 0.00 710.40 5,200.00 15.04 258.86 5,101.80 5,016.94 -147.99 -751.34 2,355,892.24 274,638.68 0.00 735.32 5,300.00 15.04 258.86 5,198.37 5,113.51 -153.01 -776.81 2,355,887.70 274,613.13 0.00 760.24 5,400.00 15.04 258.86 5,294.95 5,210.09 -158.02 -802.27 2,355,883.17 274,587.58 0.00 785.16 5,500.00 15.04 258.86 5,391.52 5,306.66 -163.04 -827.73 2,355,878.64 274,562.02 0.00 810.08 5,524.17 15.04 258.86 5,414.86 5,330.00 -164.25 -833.88 2,355,877.54 274,555.85 0.00 816.10 Middle Beluga 5,600.00 15.04 258.86 5,488.10 5,403.24 -168.05 -853.19 2,355,874.10 274,536.47 0.00 835.00 5,700.00 15.04 258.86 5,584.67 5,499.81 -173.07 -878.66 2,355,869.57 274,510.92 0.00 859.92 5,800.00 15.04 258.86 5,681.24 5,596.38 -178.08 -904.12 2,355,865.04 274,485.37 0.00 884.84 5,900.00 15.04 258.86 5,777.82 5,692.96 -183.10 -929.58 2,355,860.50 274,459.82 0.00 909.76 6,000.00 15.04 258.86 5,874.39 5,789.53 -188.12 -955.04 2,355,855.97 274,434.26 0.00 934.68 6,100.00 15.04 258.86 5,970.96 5,886.10 -193.13 -980.51 2,355,851.44 274,408.71 0.00 959.60 6,200.00 15.04 258.86 6,067.54 5,982.68 -198.15 -1,005.97 2,355,846.90 274,383.16 0.00 984.51 6,279.03 15.04 258.86 6,143.86 6,059.00 -202.11 -1,026.09 2,355,843.32 274,362.97 0.00 1,004.21 Lower Beluga 6,300.00 15.04 258.86 6,164.11 6,079.25 -203.16 -1,031.43 2,355,842.37 274,357.61 0.00 1,009.43 6,400.00 15.04 258.86 6,260.69 6,175.83 -208.18 -1,056.90 2,355,837.83 274,332.06 0.00 1,034.35 6,500.00 15.04 258.86 6,357.26 6,272.40 -213.19 -1,082.36 2,355,833.30 274,306.51 0.00 1,059.27 7 5/8" 6,600.00 15.04 258.86 6,453.83 6,368.97 -218.21 -1,107.82 2,355,828.77 274,280.95 0.00 1,084.19 6,700.00 15.04 258.86 6,550.41 6,465.55 -223.22 -1,133.28 2,355,824.23 274,255.40 0.00 1,109.11 6,800.00 15.04 258.86 6,646.98 6,562.12 -228.24 -1,158.75 2,355,819.70 274,229.85 0.00 1,134.03 6,900.00 15.04 258.86 6,743.55 6,658.69 -233.25 -1,184.21 2,355,815.17 274,204.30 0.00 1,158.95 7,000.00 15.04 258.86 6,840.13 6,755.27 -238.27 -1,209.67 2,355,810.63 274,178.75 0.00 1,183.87 7,100.00 15.04 258.86 6,936.70 6,851.84 -243.28 -1,235.13 2,355,806.10 274,153.19 0.00 1,208.79 7,149.11 15.04 258.86 6,984.13 6,899.27 -245.75 -1,247.64 2,355,803.87 274,140.65 0.00 1,221.03 2/27/2015 1:43:12PM Page 4 COMPASS 5000.1 Build 73 • • Halliburton -IALLIBIJRTC Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 31-18 Company: Hilcorp Energy Company TVD Reference: Actual @ 84.86usft Project: Kenai Gas Field MD Reference: Actual @ 84.86usft Site: KGF 41-18 Pad North Reference: True Well: Plan:KBU 31-18 Survey Calculation Method: Minimum Curvature Wellbore: KBU 31-18 Design: KBU 31-18 WP4 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +EI-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,906.62 7,156.72 15.04 260.03 6,991.48 6,906.62 -246.11 -1,249.58 2,355,803.55 274,138.70 4.00 1,222.93 Start Dir 4°/100':7157'MD,6991'TVD 7,200.00 15.12 266.68 7,033.27 6,948.41 -247.41 -1,260.74 2,355,802.46 274,127.51 4.00 1,233.94 7,300.00 16.02 281.25 7,129.64 7,044.78 -245.47 -1,287.31 2,355,804.90 274,100.99 4.00 1,260.57 7,400.00 17.77 293.65 7,225.35 7,140.49 -236.65 -1,314.83 2,355,814.23 274,073.64 4.00 1,288.76 7,452.32 18.96 299.13 7,275.01 7,190.15 -229.31 -1,329.57 2,355,821.85 274,059.04 4.00 1,304.10 KBU 31-18 tgtl 7,453.22 18.98 299.22 7,275.86 7,191.00 -229.17 -1,329.83 2,355,822.00 274,058.79 4.00 1,304.36 KBU 31-18 tgtl wp3 7,461.68 18.91 300.24 7,283.86 7,199.00 -227.81 -1,332.21 2,355,823.41 274,056.43 4.00 1,306.86 Upper Tyonek 7,461.83 18.91 300.26 7,284.00 7,199.14 -227.78 -1,332.25 2,355,823.43 274,056.39 4.00 1,306.90 7,470.51 18.91 300.26 7,292.21 7,207.35 -226.37 -1,334.68 2,355,824.89 274,053.99 0.00 1,309.45 End Dir :7471'MD,7292'TVD 7,500.00 18.91 300.26 7,320.11 7,235.25 -221.55 -1,342.94 2,355,829.86 274,045.83 0.00 1,318.09 7,600.00 18.91 300.26 7,414.72 7,329.86 -205.22 -1,370.93 2,355,846.72 274,018.15 0.00 1,347.42 7,700.00 18.91 300.26 7,509.32 7,424.46 -188.89 -1,398.92 2,355,863.57 273,990.47 0.00 1,376.74 7,800.00 18.91 300.26 7,603.93 7,519.07 -172.56 -1,426.91 2,355,880.43 273,962.80 0.00 1,406.07 7,900.00 18.91 300.26 7,698.53 7,613.67 -156.24 -1,454.90 2,355,897.28 273,935.12 0.00 1,435.39 8,000.00 18.91 300.26 7,793.13 7,708.27 -139.91 -1,482.89 2,355,914.13 273,907.45 0.00 1,464.72 8,100.00 18.91 300.26 7,887.74 7,802.88 -123.58 -1,510.88 2,355,930.99 273,879.77 0.00 1,494.04 8,200.00 18.91 300.26 7,982.34 7,897.48 -107.25 -1,538.87 2,355,947.84 273,852.09 0.00 1,523.36 8,300.00 18.91 300.26 8,076.95 7,992.09 -90.92 -1,566.86 2,355,964.69 273,824.42 0.00 1,552.69 8,400.00 18.91 300.26 8,171.55 8,086.69 -74.59 -1,594.85 2,355,981.55 273,796.74 0.00 1,582.01 8,500.00 18.91 300.26 8,266.15 8,181.29 -58.26 -1,622.84 2,355,998.40 273,769.07 0.00 1,611.34 8,600.00 18.91 300.26 8,360.76 8,275.90 -41.94 -1,650.83 2,356,015.25 273,741.39 0.00 1,640.66 8,700.00 18.91 300.26 8,455.36 8,370.50 -25.61 -1,678.82 2,356,032.11 273,713.71 0.00 1,669.99 8,800.00 18.91 300.26 8,549.97 8,465.11 -9.28 -1,706.81 2,356,048.96 273,686.04 0.00 1,699.31 8,900.00 18.91 300.26 8,644.57 8,559.71 7.05 -1,734.80 2,356,065.81 273,658.36 0.00 1,728.64 9,000.00 18.91 300.26 8,739.17 8,654.31 23.38 -1,762.79 2,356,082.67 273,630.69 0.00 1,757.96 9,033.49 18.91 300.26 8,770.86 8,686.00 28.85 -1,772.17 2,356,088.31 273,621.42 0.00 1,767.78 Tyonek D1 9,100.00 18.91 300.26 8,833.78 8,748.92 39.71 -1,790.79 2,356,099.52 273,603.01 0.00 1,787.28 9,200.00 18.91 300.26 8,928.38 8,843.52 56.04 -1,818.78 2,356,116.37 273,575.33 0.00 1,816.61 9,225.88 18.91 300.26 8,952.86 8,868.00 60.26 -1,826.02 2,356,120.73 273,568.17 0.00 1,824.20 Tyonek D2 9,300.00 18.91 300.26 9,022.99 8,938.13 72.36 -1,846.77 2,356,133.23 273,547.66 0.00 1,845.93 9,400.00 18.91 300.26 9,117.59 9,032.73 88.69 -1,874.76 2,356,150.08 273,519.98 0.00 1,875.26 9,500.00 18.91 300.26 9,212.19 9,127.33 105.02 -1,902.75 2,356,166.93 273,492.31 0.00 1,904.58 9,513.25 18.91 300.26 9,224.72 9,139.86 107.18 -1,906.46 2,356,169.17 273,488.64 0.00 1,908.47 KBU 31-18 tgt2 9,513.39 18.91 300.26 9,224.86 9,140.00 107.21 -1,906.50 2,356,169.19 273,488.60 0.00 1,908.51 Tyonek D3B-KBU 31-18 tgt2 wp3 9,600.00 18.91 300.26 9,306.80 9,221.94 121.35 -1,930.74 2,356,183.79 273,464.63 0.00 1,933.91 2/27/2015 1:43:12PM Page 5 COMPASS 5000.1 Build 73 • • Halliburton LLI B U RTC]N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 31-18 Company: Hilcorp Energy Company TVD Reference: Actual @ 84.86usft Project: Kenai Gas Field MD Reference: Actual @ 84.86usft Site: KGF 41-18 Pad North Reference: True Well: Plan:KBU 31-18 Survey Calculation Method: Minimum Curvature Wellbore: KBU 31-18 Design: KBU 31-18 WP4 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 9,299.00 9,681.46 18.91 300.26 9,383.86 9,299.00 134.65 -1,953.54 2,356,197.52 273,442.09 0.00 1,957.79 Tyonek D4 9,700.00 18.91 300.26 9,401.40 9,316.54 137.68 -1,958.73 2,356,200.64 273,436.95 0.00 1,963.23 9,800.00 18.91 300.26 9,496.00 9,411.14 154.01 -1,986.72 2,356,217.49 273,409.28 0.00 1,992.56 9,900.00 18.91 300.26 9,590.61 9,505.75 170.33 -2,014.71 2,356,234.35 273,381.60 0.00 2,021.88 9,976.42 18.91 300.26 9,662.90 9,578.04 182.81 -2,036.10 2,356,247.23 273,360.45 0.00 2,044.29 KBU 31-18 BHL •10,000.00 18.91 300.26 9,685.21 • 9,600.35 • 186.66 -2,042.70 2,356,251.20 273,353.93 0.00 2,051.20 Total Depth:10000'MD,9684'TVD-5" Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) KBU 31-18 BHL 0.00 0.00 9,662.86 229.31 -2,009.12 2,356,293.20 273,388.30 -plan misses target center by 53.75usft at 9976.42usft MD(9662.90 TVD,182.81 N,-2036.10 E) -Circle(radius 100.00) KBU 31-18 tgt2 wp3 0.00' 0.00 9,224.86 107.21 -1,906.50 2,356,169.19 273,488.60 -plan hits target center -Circle(radius 100.00) KBU 31-18 tgtl wp3 0.00 0.00 7,275.86 -229.17 -1,329.83 2,355,822.00 274,058.79 -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 1,500.00 1,500.00 10 3/4" 10-3/4 12-1/4 6,500.00 6,357.26 7 5/8" 7-5/8 9-7/8 10,000.00 9,685.21 5" 5 6-1/8 2/27/2015 1:43:12PM Page 6 COMPASS 5000.1 Build 73 • • Halliburton oe-IALLIBURTO Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 31-18 Company: Hilcorp Energy Company TVD Reference: Actual @ 84.86usft Project: Kenai Gas Field MD Reference: Actual @ 84.86usft Site: KGF 41-18 Pad North Reference: True Well: Plan:KBU 31-18 Survey Calculation Method: Minimum Curvature Wellbore: KBU 31-18 Design: KBU 31-18 WP4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (1 (°) 9,033.49 8,770.86 Tyonek D1 0.00 4,862.50 4,775.86 Upper Beluga 0.00 5,524.17 5,414.86 Middle Beluga 0.00 4,308.52 4,240.86 Sterling 5.2 0.00 9,681.46 9,383.86 Tyonek D4 0.00 9,513.39 9,224.86 Tyonek D3B 0.00 6,279.03 6,143.86 Lower Beluga 0.00 9,225.88 8,952.86 Tyonek D2 0.00 4,607.77 4,529.86 Sterling Pool 6 0.00 4,036.18 3,977.86 Sterling 0.00 7,461.68 7,283.86 Upper Tyonek 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-5 +E/-W (usft) (usft) (usft) (usft) Comment 2,000.00 2,000.00 0.00 0.00 Start Dir 3°/100':2000'MD,2000'TVD 2,502.56 2,496.78 -12.70 -64.50 End Dir :2503'MD,2497'TVD 7,156.72 6,991.48 -246.11 -1,249.58 Start Dir4°/100':7157'MD,6991'TVD 7,470.51 7,292.21 -226.37 -1,334.68 End Dir :7471'MD,7292'TVD 10,000.00 9,685.21 186.66 -2,042.70 Total Depth:10000'MD,9684'TVD 2/27/2015 1:43:12PM Page 7 COMPASS 5000.1 Build 73 1 • • Hilcorp Energy Company Kenai Gas Field KGF 41-18 Pad Plan: KBU 31-18 KBU 31-18 KBU 31-18 WP4 II perry Drilling Services Clearance Summary Anticollision Report 02 March,2015 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:KGF 41-18 Pad-Plan:KBU 31-18-KBU 31-18-KBU 31-18 WP4 Well Coordinates: 2,356,026.01 N,275,392.65 E(60°26'35.40"N,151°14'37.27"W) Datum Height:Actual @ 84.86usft Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited,Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version:5000.1 Build:73 Scan Type: NO GLOBAL FILTER:Using user defined selection&filtering criteria Scan Type: 25.00 HALLIBURTON Sperry Drilling Services I SURVEY PROGRAM • Hilcorp Energy Company ANTI-COLLISION SETTINGS Date:2015-01-28T00:00:00 Validated:Yes Version: Calculation Method:Minimum Curvature Interpolation Method:MD,interval:25.00 Error System:ISCWSA Depth Range From:18.00 To 10000.00 Scan Method:Closest Approach 3D Centre Distance:1198.20 Error Surface:Elliptical Conic Reference:Plan:KBU 31-18 WP4(Plan:KBU 31-18/KBU 31-18) Warning Method: Error Ratio GLOBAL FILTER APPLIED:All wellpaths within 200'0 100/1000 of reference KBU 43-07Y KBU 14. KBU 32-07 WP1.0 KBU 13-81 1 o _�1KBU 41-18X1 .'� ♦ 40 __3I KBU 32-081 330 of ,r li KBU 43-07Y_ 1 KU 11-171 , ♦ U �i�l.: 4W�_,\\ �KU 11-171 330 /�'ilir�er� � '+30 7,4'44 I ! ii ii • 601 KBU 11-17X1 'd�'�ij��+Ilr'+1 N.:�� p.•,; \ 4ti .. , ,,, ,,,,,, treW:Akethig N. 27o _ f .1!'i �i�'��+�t!,�/ " `.; 'il, • �l ��Illl�ll. 96 From Colour To MD 270 �� ♦��';�t gyp. iii Mt: 1[ 1 �! n t' \ J v si 1 t.,1111 1 1 1',41 1 �, 1,1 I i;firINBl441 ,d�' ,Qr • ,1�'11,1r�1(X1 1� 't 1KU41-181 18 100 ��10 1, 1 �j i.77 �'yr � �( ;r,.•;:: i 1(', �h�i�.I A 100 500 �� , ;. 1 ' 1. 11 111 i,4,, r i 1.✓ igpfj�',,,,,, 1 ) ` ttl ' x 500 1000 240 A ��Adel t J 120 I ,� �� i1511�1� ti�p1 moi / ' 1000 2000 ,ilei •a�r�1�',��i44Ii �.. r ,/1l IKU 13-81 Ott 120 4027 @ti ra�CI•411 4 ' , 240 y2000 2500 -i``� 4►1 4}, \A ��‘� r. 2500 2750 2141�4 la 1 1,b�,,t-la: 51�1411� i � 150 r ' 2750 3000 180 -'( 3000 3250 210`� 150 3250 3500 Azimuth from North[°)vs Centre to Centre Separation[50 usftfin] 3500 3750 180 3750-- -4000 4000 5000 5000 7500 Azimuth from North[0]vs Centre to Centre Separation[200 usft/in] SECTION DETAILS Details:Plan:KBU 31-18 NAD 1927(NADCON CONUS) Alaska Zone 04 Sec MD Inc Ad ND +N/-5 «El-W Dleg TFece VSect Target Ground Level: 66.86 1 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 0.00 +N/S +EJ-W Northing Fasting Letittude Longitude Slot 22000.00 0.00 0.00 2000.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2356026.01 275392.65 60.4431666 -151.2436851 32501.39 15.04 258.86 2495.65 -12.85 -64.20 3.00 258.86 62.83 47149.11 15.04 258.88 6984.13 -245.75 -1247.64 0.00 0.00 1221.03 57453.22 18.98 299.22 7275.86 -229.17 -1329.83 4.00 91.85 1304.38 00531-181011 np3 87461.83 18.91 300.28 7264.00 -227.78 -1332.25 4.00 102.54 1306.90 REFERENCE INFORMATION 79513.39 18.91 300.26 9224.88 107.21 -1908.50 0.00 0.00 1908.51 KBU 31-181°12 wp3 80000 00 16.91 300.26 9685.21 188.68 -2042.70 0.00 0.00 2051.20 Co-ordinate(N/E)Reference:Well Plan:KBU 31-18,True North Vertical(ND)Reference:Actual @ 84.86usft Section(VS)Reference:Slot-(0.O0N,0.00E) Measured Depth Reference:Actual @ 04.88usft Calculation Method:Minimum Curvature • • Hilcorp Energy Company HAL.Lt@URTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18-KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:KGF 41-18 Pad-Plan:KBU 31-18-KBU 31-18-KBU 31-18 WP4 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning(41: �k ' Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft KGF 41-18 Pad 'y KU 11-17-KU 11-17-KU 11-17 1,348.71 46.21 1,348.71 37.18 1,382.36 5.120 Centre Distance Pass- f1 KU 11-17-KU 11-17-KU 11-17 1,350.00 46.21 1,350.00 37.15 1,383.52 5.100 Ellipse Separation Pass- KU11-17-KU 11-17-KU 11-17 1,400.00 51.27 1,400.00 40.02 1,428.56 4.556 Clearance Factor Pass- KU 13-8-KU 13-8-KU 13-8 3,249.59 48.24 71249.59 -84.32 3,171.36 0.3611 "litre Distance . X.-- KU 13-8-KU 13-8-KU 13-8 II ..3,250.00 48.24 infp.00 -84.33 3,171.75 MIL 0.364 t tearance Factor a KU 13-8-KU 13.8-KU 13-8 inagrftfla 48.69 ,Alinina -84.88 3,195.89 1111110 0.365 Ellipse Separation a KU 41-18-KU 41-18-KU 41-18 3,273.70 143.78 3,273.70 17.44 3,254.64 1.138 Centre Distance Pass- KU 41-18-KU 41-18-KU 41-18 3,350.00 145.14 3,350.00 15.56 3,328.33 1.120 Ellipse Separation Pass- KU 41-18-KU 41-18-KU 41-18 3,375.00 146.17 3,375.00 15.57 3,352.47 1.119 Clearance Factor Pass- Survey tool program From To Survey/Plan Survey Tool (stiff) (usft) 18.00 1,500.00 KBU 31-18 WP4 MWD+SC+sag 1,500.00 6,500.00 KBU 31-18 WP4 MWD+SC+sag 6,500.00 10,000.00 KBU 31-18 WP4 MWD+SC+sag Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. . Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 02 March,2015-17:44 Page 2 of 4 COMPASS • • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18-KBU 31-18 WP4 Direction and Coordinates are relative to True North Reference. SII Vertical Depths are relative to Actual @ 84.86usft. Northing and Fasting are relative to Plan:KBU 31-18. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00°,Grid Convergence at Surface is: -1.08°. Ladder Plot I ,' 1 • II 0 , 1050 I I ,, 0 iI In IA o f (h ____J____ J J C ri o r �1 VI LEGEND 2 700 , 03 I Q i = 0) -i- KU11-17,KU11-17,KU11-17VO CO 11 J $ KU13-8,KU138,KU138V0 J 2 J -0- KU 41-18,KU 41-1 8,KU 41-1 8 VO C -a- KBU31-18WP4 CD IN �./ I ✓ 350 I �� ' o • • • • • I • t , I ,,f L � C. ,, UCD 1 0 0 1500 3000 4500 6000 7500 Measured Depth(1500 usft/in) 02 March,2015-17:44 Page 3 of 4 COMPASS '�I Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18-KBU 31-18 WP4 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor I I - 1� " aT 10.00 T 8.75 1 I_ — 1— ----------R I —I c 7.50- !� .._ _. T — _ • _ O ....._ . . - 6.25--- I. t --_—�.-�^-- --..... LEGEND • m Ii c 5.00-- — 0-—' _.._._ - � of�._ I__,_ .. -B-KU11-17,KU11-17,KU11-17V0 o _. I `L $KU138,KU138,KU138V0 co �.. ,. \1. o. I� $KBU 31 818WP4 18,KU41-18V0 , + __ 3.75 \ \� -- — i - - \\ I,I ► i _ "0 0 rI 2.50 ----"- --....._F. , 0 ------_ . —.__ _ s, ' ii.< Collision Avoidance Req '� ---Normo Zone-StoPDri -- `` \� _ . l 1.25 sr..r.Fj _' ,...r _. ._.(._ 1 I ..:. e. , I +`. s 0.00 i- i i , + , , Th I , , 1 i 1111111111 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 „ 1 1 1 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 Mead rei Depth(1500 usft/ln) 02 March.2015- 17:44 Page 4 of 4 COMPASS • Hilcorp Energy Company Kenai Gas Field KGF 41-18 Pad Plan: KBU 31-18 KBU 31-18 KBU 31-18WP4 Sperry Drilling Services Anticollision Report 02 March,2015 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: KGF 41-18 Pad-Plan:KBU 31-18-KBU 31-18-KBU 31-18 WP4 Well Coordinates:2,356,026.01 N,275,392.65 E(60°26'35.40"N,151°14'37.27"W) Datum Height:Actual @ 64.86usft Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build:73 Scan Type: NO GLOBAL FILTER:Using user defined selection&filtering criteria Interpolation Interval: 25.00 HALLIBURTON • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation Is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 18.00 18.00 0.00 98.00 98.00 0.00 309.56 0.96 308.60 -129.55 -129.55 322.888 Pass- 25.00 25.00 0.01 98.00 98.00 0.00 308.13 0.97 307.16 -129.55 -129.55 318.780 Pass- 50.00 50.00 0.04 98.00 98.00 0.00 304.26 0.99 303.27 -129.55 -129.55 305.907 Pass- 75.00 75.00 0.06 98.00 98.00 0.00 302.42 1.02 301.39 -129.55 -129.55 295.719 Pass- 88.76 88.76 0.08 101.90 101.90 0.08 302.26 1.12 301.14 -129.55 -129.55 270.813 Pass- 100.00 100.00 0.09 113.14 113.14 0.30 302.26 1.35 300.90 -129.55 -129.55 223.318 Pass- 125.00 125.00 0.15 138.14 138.14 0.80 302.26 1.91 300.35 -129.55 -129.55 158.278 Pass- 150.00 150,00 0.20 163.14 163.14 1.30 302.26 2.47 299.79 -129.55 -129.55 122.578 Pass- 175.00 175.00 0.26 188.14 188.14 1.80 302.26 3.02 299.23 -129.55 -129.55 100.018 Pass- 200.00 200.00 0.32 213.14 213.14 2.30 302.26 3.58 298.68 -129.55 -129.55 84.472 Pass- 225.00 225.00 0.37 238.14 238.14 2.80 302.26 4.13 298.12 -129.55 -129.55 73.108 Pass- 250.00 250.00 0.43 263.14 263.14 3.30 302.26 4.69 297.57 -129.55 -129.55 64.439 Pass- 275.00 275.00 0.49 288.14 288.14 3.80 302.26 5.25 297.01 -129.55 -129.55 57.608 Pass- 300.00 300.00 0.54 313.14 313.14 4.30 302.26 5.80 296.45 -129.55 -129.55 52.087 Pass- 325.00 325.00 0.60 338.14 338.14 4.80 302.26 6.36 295.90 -129.55 -129.55 47.531 Pass- 350.00 350.00 0.65 363.14 363.14 5.30 302.26 6.92 295.34 -129.55 -129.55 43.709 Pass- 375.00 375.00 0.71 388.14 388.14 5.80 302.26 7.47 294.78 -129.55 -129.55 40.455 Pass- 400.00 400.00 0.77 413.14 413.14 6.30 302.26 8.03. 294.23 -129.55 -129.55 37.652 Pass- 425.00 425.00 0.82 438.14 438.14 6.80 302.26 8.58 293.67 -129.55 -129.55 35.212 Pass- 450.00 450.00 0.88 463.14 463.14 7.30 302.26 9.14 293.12 -129.55 -129.55 33.070 Pass- 475.00 475.00 0.94 488.14 488.14 7,80 302.26 9.70 292.56 -129.55 -129.55 31.173 Pass- 500.00 500.00 0.99 513.14 513.14 8.57 302.26 10.52 291.74 -128.55 -129.55 28.745 Pass- 525.00 525.00 1.05 538.14 538.14 9.57 302.26 11.57 290.68 -129.55 -129.55 26.121 Pass- 550.00 550.00 1.10 563.14 563.14 10.57 302.26 12.63 289.63 -129.55 -129.55 23.936 Pass- 575.00 575.00 1.16 588.14 588.14 11.57 302.26 13.68 288.57 -129.55 -129.55 22.089 Pass- 600.00 600.00 1.22 613.14 613.14 12.57 302.26 14.74 287.52 -129.55 -129.55 20.506 Pass- 625.00 625.00 1.27 638.14 638.14 13.57 302.26 15.80 286.46 -129.55 -129.55 19.135 Pass- 650.00 650.00 1.33 663.14 663.14 14.57 302.26 16.85 285.40 -129.55 -129.55 17.936 Pass- 675.00 675.00 1.38 688.14 688.14 15.57 302.26 17.91 284.35 -129.55 -129.55 16.878 Pass- 700.00 700.00 1.44 713.14 713.14 16.57 302.26 18.96 283.29 -129.55 -129.55 15.938 Pass- 02 March,2015-17:49 Page 2 of28 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 725.00 725.00 1.50 738.14 738.14 17.57 302.26 20.02 282.24 -129.55 -129.55 15.097 Pass- 750.00 750.00 1.55 763.14 763.14 18.57 302.26 21.08 281.18 -129.55 -129.55 14.341 Pass- 775.00 775.00 1.61 788.14 788.14 19.57 302.26 22.13 280.12 -129.55 -129.55 13.656 Pass- 800.00 800.00 1.67 813.14 813.14 20.57 302.26 23.19 279.07 -129.55 -129.55 13.034 Pass- 825.00 825.00 1.72 838.14 838.14 21.57 302.26 24.25 278.01 -129.55 -129.55 12.466 Pass- 850.00 850.00 1.78 863.14 863.14 22.57 302.26 25.30 276.95 -129.55 -129.55 11.946 Pass- 875.00 875.00 1.83 888.14 888.14 23.57 302.26 26.36 275.90 -129.55 -129.55 11.467 Pass- 900.00 900.00 1.89 913.14 913.14 24.57 302.26 27.41 274.84 -129.55 -129.55 11.026 Pass- 925.00 925.00 1.95 938.14 938.14 25.57 302.26 28.47 273.79 -129.55 -129.55 10.617 Pass- 950.00 950.00 2.00 963.14 963.14 26.57 302.26 29.53 272.73 -129.55 -129.55 10.237 Pass- 975.00 975.00 2.06 988.14 988.14 27.57 302.26 30.58 271.67 -129.55 -129.55 9.883 Pass- 1,000.00 1,000.00 2.12 1,013.14 1,013.14 28.57 302.26 31.64 270.62 -129.55 -129.55 9.553 Pass- 1,025.00 1,025.00 2.17 1,038.14 1,038.14 29.57 302.26 32.70 269.56 -129.55 -129.55 9.245 Pass- 1,050.00 1,050.00 2.23 1,063.14 1,063.14 30.57 302.26 33.75 268.50 -129.55 -129.55 8.955 Pass- 1,075.00 1,075.00 2.28 1,088.14 1,088.14 31.57 302.26 34.81 267.45 -129.55 -129.55 8.684 Pass- 1,100.00 1,100.00 2.34 1,113.14 1,113.14 32.57 302.26 35.86 266.39 -129.55 -129.55 8.428 Pass- 1,125.00 1,125.00 2.40 1,138.14 1,138.14 33.57 302.26 36.92 265.34 -129.55 -129.55 8.187 Pass- 1,150.00 1,150.00 2.45 1,163.14 1,163.14 34.57 302.26 37.98 264.28 -129.55 -129.55 7.959 Pass- 1,175.00 1,175.00 2.51 1,188.14 1,188.14 35.57 302.26 39.03 263.22 -129.55 -129.55 7.744 Pass- 1,200.00 1,200.00 2.56 1,213.14 1,213.14 36.57 302.26 40.09 262.17 -129.55 -129.55 7.540 Pass- 1,225.00 1,225.00 2.62 1,238.14 1,238.14 37.57 302.26 41.14 261.11 -129.55 -129.55 7.346 Pass- 1,250.00 1,250.00 2.68 1,263.14 1,263.14 38.57 302.26 42.20 260.06 -129.55 -129.55 7.162 Pass- 1,275.00 1,275.00 2.73 1,288.14 1,288.14 39.57 302.26 43.26 259.00 -129.55 -129.55 6.987 Pass- 1,300.00 1,300.00 2.79 1,313.14 1,313.14 40.57 302.26 44.31 257.94 -129.55 -129.55 6.821 Pass- 1,325.00 1,325.00 2.85 1,338.14 1,338.14 41.57 302.26 45.37 256.89 -129.55 -129.55 6.662 Pass- 1,350.00 1,350.00 2.90 1,363.14 1,363.14 42.57 302.26 46.43 255.83 -129.55 -129.55 6.511 Pass- 1,375.00 1,375.00 2.96 1,388.14 1,388.14 43.57 302.26 47A8 254.77 -129.55 -129.55 6.366 Pass- 1,400.00 1,400.00 3.01 1,413.14 1,413.14 44.57 302.26 48.54 253.72 -129.55 -129.55 6.227 Pass- 1,425.00 1,425.00 3.07 1,438.14 1,438.14 45.57 302.26 49.59 252.66 -129.55 -129.55 6.095 Pass- 1,450.00 1,450.00 3.13 1,463.14 1,463.14 46.57 302.26 50.65 251.61 -129.55 -129.55 5.967 Pass- 1,475.00 1,475.00 3.18 1,488.14 1,488.14 47.57 302.26 51.71 250.55 -129.55 -129.55 5.846 Pass- 02 March,2015-17:49 Page 3 of 28 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,190.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 1,500,00 1,500.00 3.24 1,513.14 1,513.14 48.57 302.26 52.76 249.49 -129.55 -129.55 5.729 Pass- 1,525.00 1,525.00 3.27 1,538.14 1,538.14 49.57 302.26 53.56 248.69 -129.55 -129.55 5.643 Pass- 1,550.00 1,550.00 3.30 1,563.14 1,563.14 50.57 302.26 54.59 247.67 -129.55 -129.55 5.537 Pass- 1,575.00 1,575.00 332 1,588.14 1,588.14 51.57 302.26 55.62 246.64 -129.55 -129.55 5.434 Pass- 1,600.00 1,600.00 3.35 1,613.14 1,613.14 52.57 302.26 '56.65 245.61 -129.55 -129.55 5.336 Pass- 1,625.00 1,625.00 3.36 1,638.14 1,638.14 53.57 302.26 57.65 244.60 -129.55 -129.55 5.243 Pass- 1,650.00 1,650.00 3.36 1,663.14 1,663.14 54.57 302.26 56.66 243.60 -129.55 -129.55 5.153 Pass- 1,675.00 1,675.00 3.36 1,688.14 1,688.14 55.57 302.26 59.66 242.60 -129.55 -129.55 5.066 Pass- 1,700.00 1,700.00 3.37 1,713.14 1,713.14 56.57 302.26 60.66 241.59 -129.55 -129.55 4.983 Pass- 1,725.00 1,725.00 3.38 1,738.14 1,738.14 57.57 302.26 61.67 240.59 -129.55 -129.55 4.901 Pass- 1,750.00 1,750.00 3.38 1,763.14 1,763.14 58.57 302.26 62.68 239.58 -129.55 -129.55 4.822 Pass- 1,775.00 1,775.00 3.39 1,788.14 1,788.14 59.57 302.26 63.69 238.57 -129.55 -129.55 4.746 Pass- 1,800.00 1,800.00 3.40 1,813.14 1,813.14 60.57 302.26 64.69 237.56 -129.55 -129.55 4.672 Pass- 1,825.00 1,825.00 3.41 1,638.14 1,838.14 61.57 302.26 65.70 236.55 -129.55 -129.55 4.600 Pass- 1,850.00 1,850.00 3.42 1,863.14 1,863.14 62.57 302.26 66.71 235.54 -129.55 -129.55 4.531 Pass- 1,875.00 1,875.00 3.43 1,688.14 1,888.14 63.57 302.26 67.73 234.53 -129.55 -129.55 4.463 Pass- 1,900.00 1,900.00 3.44 1,913.14 1,913.14 64.57 302.26 68.74 233.52 -129.55 -129.55 4.397 Pass- 1,925.00 1,925.00 3.46 1,938.14 1,938.14 65.57 302.26 69.75 232.50 -129.55 -129.55 4.333 Pass- 1,950.00 1,950.00 3.47 1,963.14 1,963.14 66.57 302.26 70.77 231A9 -129.55 -129.55 4.271 Pass- 1,975.00 1,975.00 3.49 1,988.14 1,988.14 67.57 302.26 71.78 230.48 -129.55 -129.55 4.211 Pass- 2,000.00 2,000.00 3.50 2,013.14 2,013.14 68.57 302.26 72.80 229.46 -129.55 -129.55 4.152 Pass- 2,025.00 2,025.00 3.52 2,038.14 2,038.14 69.57 302.11 73.81 228.30 129.29 -129.56 4.093 Pass- 2,050.00 2,049.99 3.53 2,063.13 2,063.13 70.57 301.68 74.81 226.87 129.25 -129.61 4.033 Pass- 2,075.00 2,074.98 3.55 2,088.12 2,088.12 71.56 300.96 75.80 225.16 129.18 -129.68 3.970 Pass- 2,100.00 2,099.95 3.57 2,113.09 2,113.09 72.56 299.96 76.78 223.17 129.07 -129.79 3.907 Pass- 2,125.00 2,124.91 3.59 2,138.05 2,138.05 73.56 298.67 77.75 220.91 128.94 -129.92 3.841 Pass- 2,150.00 2,149.85 3.61 2,162.99 2,162.99 74.56 297.09 78.71 218.38 128.77 -130.09 3.774 Pass- 2,175.00 2,174.76 3.63 2,187.90 2,187.90 75.56 295.23 79.66 215.57 128.57 -130.29 3.706 Pass- 2,200.00 2,199.63 3.65 2,212.77 2,212.77 76.55 293.10 80.60 212.50 128.34 -130.52 3.636 Pass- 2,225.00 2,224.48 3.68 2,237.62 2,237.62 77.54 290.68 81.53 209.15 128.07 -130.79 3.565 Pass- 2,250.00 2,249.29 3.70 2,262.43 2,262.43 78.54 287.99 82.44 205.54 127.76 -131.09 3.493 Pass- 02 March,2015-17:49 Page 4 of 28 COMPASS Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41.18 �� Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Wet Uncertainty Data for Offset Wet Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 2,275.00 2,274.05 3.73 2,287.19 2,287.19 79.53 285.03 83.35 201.68 127.42 -131.44 3A20 Pass- 2,30000 2,298.77 3.76 2,311.91 2,311.91 80.52 281.80 84.24 197.56 127.03 -131.82 3.345 Pass- 2,325.00 2,323.43 3.80 2,336.57 2,336.57 81.50 278.30 85.12 193.18 126.61 -132.25 3.269 Pass- 2,35000 2,348.04 3.84 2,361.18 2,361.18 82.49 274.55 86.00 188.55 126.13 -132.72 3.192 Pass- 2,375.00 2,372.60 3.88 2,385.74 2,385.74 83.47 270.54 86.86 183.68 125.61 -133.25 3.115 Pass- 2,400.00 2,397.08 3.92 2,410.22 2,410.22 84.45 266.29 87.72 178.57 125.03 -133.82 3.036 Pass- 2,425.00 2,421.50 3.98 2,434.64 2,434.64 85.43 261.79 88.57 17322 124.40 -134.46 2.956 Pass- 2,450.00 2,445.85 4.03 2,458.99 2,458.99 86.40 257.07 89.42 167.65 123.71 -135.15 2.875 Pass- 2,475.00 2,470.12 4.09 2,483.26 2,483.26 87.37 252.12 90.27 161.85 122.94 -135.91 2.793 Pass- 2,500.00 2,494.31 4.15 2,507.45 2,507.45 88.34 246.96 91.11 155.85 122.11 -136.75 2.711 Pass- 2,525.00 2,518.45 4.22 2,531.59 2,531.59 69.30 241.72 92.14 149.58 121.21 -137.64 2.623 Pass- 2,550.00 2,542.59 4.30 2,555.73 2,555.73 9027 236.53 93.19 143.34 120.28 -138.58 2.536 Pass- 2,575.00 2,566.74 4.36 2,579.88 2,579.88 91.24 231.41 94.24 137.17 119.30 -139.56 2.456 Pass- 2,600.00 2,590.88 4.45 2,604.02 2,604.02 9220 226.37 95.30 131.07 11828 -140.58 2.375 Pass- 2,625.00 2,615.03 4.54 2,628.17 2,628.17 93.17 221.39 96.37 125.02 117.21 -141.64 2.297 Pass- 2,650.00 2,639.17 4.63 2,652.31 2,652.31 94.13 216.50 97.45 119.05 116.10 -142.76 2222 Pass- 2,675.00 2,663.31 4.72 2,676.45 2,676.45 95.10 211.70 98.54 113.16 114.93 -143.92 2.148 Pass- 2,700.00 2,687.46 4.81 2,700.60 2,700.60 96.06 206.98 99.63 107.35 113.71 -145.14 2.077 Pass- 2,725.00 2,711.60 4.90 2,724.74 2,724.74 97.03 202.36 100.74 101.63 112.44 -146.42 2.009 Pass- 2,750.00 2,735.74 5.00 2,748.88 2,748.88 98.00 197.85 101.85 96.00 111.10 -147.76 1.943 Pass- 2,775.00 2,759.89 5.10 2,773.03 2,773.03 98.96 193.45 102.98 90.47 109.71 -149.15 1.879 Pass- 2,800.00 2,784.03 5.20 2,797.17 2,797.17 99.93 189.17 104.11 85.06 108.24 -150.61 1.817 Pass- 2,825.00 2,808.17 531 2,821.31 2,821.31 100.89 185.02 10526 79.77 106.72 -152.14 1.758 Pass- 2,850.00 2,832.32 5.41 2,845.46 2,845.46 101.86 181.01 106.41 74.60 105.12 -153.74 1.701 Pass- 2,875.00 2,856.46 5.52 2,869.60 2,869.60 102.82 177.14 107.58 69.57 103.45 -155.40 1.647 Pass- 2,900.00 2,880.60 5.62 2,893.74 2,893.74 103.79 173.43 108.75 64.69 101.71 -157.14 1.595 Pass- 2,925A0 2,904.75 5.74 2,917.89 2,917.89 104.76 169.89 109.93 59.96 99.90 -158.96 1.545 Pass- 2,950.00 2,928.89 5.85 2,942.03 2,942.03 105.72 166.53 111.12 55.41 98.01 -160.85 1.499 Pass- 2,975.00 2,953.03 5.96 2,966.17 2,966.17 106.69 163.35 112.31 51.03 96.04 -162.81 1.454 Pass- 3,000.00 2,977.18 6.07 2,990.32 2,990.32 107.65 160.37 113.51 46.86 94.00 -164.85 1.413 Pass- 3,025.00 3,001.32 6.19 3,014.46 3,014.46 108.62 157.60 114.72 42.89 91.89 -166.97 1.374 Pass- 02 March,2015-17:49 Page 5 of 28 COMPASS • • Hilcorp Energy Company H ALLI B U RTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 3,050.00 3,025.46 6.31 3,038.60 3,038.60 109.58 155.06 115.92 39.14 89.70 -169.16 1.338 Pass- 3,075.00 3,049.61 6.42 3,062.75 3,062,75 110.55 152.75 117.12 35.63 87.44 -171.41 1.304 Pass- 3,100,00 3,073.75 6.54 3,086.89 3,086.89 111.52 150.68 118.32 32.36 85.12 -173.74 1.273 Pass- 3,125.00 3,097.89 6.66 3,111.03 3,111.03 112.48 148.87 119.52 29.35 82.74 -176.12 1.246 Pass- 3,150.00 3,122.04 6.78 3,135.18 3,135.18 113.45 147.32 120.70 26.62 80.30 -178.56 1.221 Pass- 3,175.00 3,146.18 6.91 3,159.32 3,159.32 114.41 146.05 121.88 24.17 77.82 178.96 1.198 Pass- 3,200.00 3,170.32 7.03 3,183.46 3,183.46 115.38 145.05 123.03 22.02 75.29 176.43 1.179 Pass- 3,225.00 3,194.47 7.15 3,207.61 3,207.61 116.34 144.34 124.18 20.16 72.74 173.86 1.162 Pass- 3,250.00 3,218.61 728 3,231.75 3,231.75 117.31 143.91 125.30 18.61 70.16 171.31 1.149 Pass- 3,273.70 3,241.50 7.39 3,254.64 3,254.64 118.23 143.78 126.35 17.44 67.71 168.86 1.138 Pass- 3,275.00 3,24275 7.40 3,255.89 3,255.69 118.28 143.78 126.40 17.38 67.58 168.72 1.137 Pass- 3,300,00 3,266.90 7.52 3,280.04 3,280.04 119.24 143.94 127.48 16.46 65.00 166.14 1.129 Pass- 3,325.00 3,291.04 7.65 3,304.18 3,304.18 120.21 144.40 128.54 15.85 62.42 163.57 1.123 Pass- 3,350.00 3,315.19 7.78 3,328.33 3,328.33 121.17 145.14 129.58 15.56 59.87 161.02 1.120 Pass- 3,375.00 3,339.33 7.90 3,352.47 3,352.47 122.14 146.17 130.59 15.57 57.35 158.50 1.119 Pass- 3,400.00 3,363.47 8.03 3,376.61 3,376.61 123.10 147.47 131.58 15.89 54.87 156.02 1.121 Pass- 3,425.00 3,367.62 8.16 3,400.76 3,400.76 124.07 149.05 132.55 16.49 52.44 153.58 1.124 Pass- 3,450.00 3,411.76 8.29 3,424.90 3,424.90 125.04 150.89 133.50 17.38 50.06 151.21 1.130 Pass- 3,475.00 3,435.90 8.42 3,449.04 3,449.04 126.00 152.98 134.43 18.54 47.75 148.89 1.138 Pass- 3,500.00 3,460.05 8.55 3,473.19 3,473.19 126.97 155.31 135.35 19.97 45.50 146.64 1.148 Pass- 3,525.00 3,484.19 8.68 3,497.33 3,497.33 127.93 157.88 136.25 21.63 43.32 144.46 1.159 Pass- 3,550.00 3,508.33 8.81 3,521.47 3,521.47 128.90 160.67 137.14 23.53 41.21 142.35 1.172 Pass- 3,575.00 3,532.48 8.94 3,545.62 3,545.62 129.86 163.67 138.02 25.65 39.18 140.32 1.186 Pass- 3,600.00 3,556.62 9.07 3,569.76 3,569.76 130.83 166,87 138.88 27.98 37.22 136.36 1.201 Pass- 3,625.00 3,580.76 920 3,593.90 3,593.90 131.80 170.25 139.75 30.50 35.34 136.48 1.218 Pass- 3,650.00 3,604.91 9.34 3,618.05 3,618.05 132.76 173.81 140.60 33.21 33.53 134.67 1.236 Pass- 3,675.00 3,629.05 9.47 3,642.19 3,642.19 133.73 177.54 141.46 36.08 31.80 132.94 1.255 Pass- 3,700.00 3,653.19 9.60 3,666.33 3,666.33 134.69 181.42 142.31 39.11 30.14 13128 1.275 Pass- 3,725.00 3,677.34 9,73 3,690.48 3,690.48 135.66 185.45 143.16 4229 28.55 129.69 1.295 Pass- 3,750.00 3,701.48 9.87 3,714.62 3,714.62 136.62 189.61 144.01 45.60 27.03 128.17 1.317 Pass- 3,775.00 3,725.62 10.00 3,738.76 3,736.76 137.59 193.90 144.86 49.05 25.57 126.72 1.339 Pass- 02 March,2015-17:49 Page 6 0128 COMPASS i • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (tisk) Bearing Bearing Factor Warning 3,800.00 3,749.77 10.13 3,762.91 3,762.91 138.56 198.32 145.71 52.61 24.18 125.33 1.361 Pass- I 3,825.00 3,773.91 10.27 3,787.05 3,787.05 139.52 202.84 146.56 56.28 22.86 124.00 1.384 Pass- 3,850.00 3,798.05 10.40 3,811.19 3,811.19 140.49 207.47 147.42 60.05 21.59 122.73 1.407 Pass- 3,875.00 3,822.20 10.54 3,835.34 3,835.34 141.45 212.19 148.27 63.92 20.37 121.51 1.431 Pass- 3,900.00 3,846.34 10.67 3,859.48 3,859.48 142.42 217.01 149.13 67.87 19.21 120.35 1.455 Pass- 3,925.00 3,870.48 10.81 3,883.62 3,883.62 143.38 221.91 150.00 71.91 18.10 119.24 1.479 Pass- 3,950.00 3,894.63 10.94 3,907.77 3,907.77 144.35 226.89 150.87 76.02 17.04 118.18 1.504 Pass- 3,975.00 3,918.77 11.08 3,931.91 3,931.91 145.32 231.94 151.74 80.21 16.02 117.17 1.529 Pass- 4,000.00 3,942.91 11.21 3,956.05 3,956.05 146.28 237.07 152.61 84.46 15.05 116.19 1.553 Pass- 4,025.00 3,967.06 11.35 3,980.20 3,980.20 147.25 242.26 153.49 88.77 14.12 115.26 1.578 Pass- 4,050.00 3,991.20 11.49 4,004.34 4,004.34 148.21 247.51 154.37 93.14 1323 114.37 1.603 Pass- 4,075.00 4,015.35 11.62 4,028.49 4,028.49 149.18 252.82 155.26 97.56 12.38 113.52 1.628 Pass- 4,100.00 4,039A9 11.76 4,052.63 4,052.63 150.15 258.18 156.15 102.04 11.56 112.70 1.653 Pass- 4,125.00 4,063.63 11.90 4,076.77 4,076.77 151.11 263.60 157.04 106.56 10.77 111.91 1.679 Pass- 4,150.00 4,087.78 12.03 4,100.92 4,100.92 152.08 269.06 157.93 111.12 10.02 111.16 1.704 Pass- 4,175.00 4,111.92 12.17 4,125.06 4,125.06 153.04 274.56 158.83 115.73 9.29 110.44 1.729 Pass- 4,200.00 4,136.06 12.31 4,149.20 4,149.20 154.01 280.11 159.73 120.38 8.60 109.74 1.754 Pass- 4,225.00 4,160.21 12.45 4,173.35 4,173.35 154.97 285.70 160.64 125.06 7.93 109.07 1.779 Pass- 4,250.00 4,184.35 12.58 4,197.49 4,197.49 155.94 291.32 161.55 129.78 729 108.43 1.603 Pass- 4,275.00 4,208.49 12.72 4,221.63 4,221.63 156.91 296.98 162.46 134.52 6.67 107.81 1.828 Pass- 4,300.00 4,232.64 12.86 4,245.78 4,245.78 157.87 302.68 163.37 139.30 6.08 107.22 1.853 Pass- 4,325.00 4,256.78 13.00 4,269.92 4,269.92 158.84 308.40 164.29 144.11 5.50 106.65 1.877 Pass- 4,350.00 4,280.92 13.13 4,294.06 4,294.06 159.80 314.16 16521 148.95 4.95 106.09 1.902 Pass- 4,375.00 4,305.07 13.27 4,318.21 4,318.21 160.77 319.94 166.13 153.81 4.42 105.56 1.926 Pass- 4,400.00 4,329.21 13.41 4,342.35 4,342.35 161.73 325.75 167.05 158.69 3.91 105.05 1.950 Pass- 4,425.00 4,353.35 13.55 4,366.49 4,366.49 162.70 331.58 167.98 163.60 3.41 104.56 1.974 Pass- 4,450.00 4,377.50 13.69 4,390.64 4,390.64 163.67 337.44 168.91 168.53 2.93 104.08 1.998 Pass- 4,475.00 4,401.64 13.83 4,414.78 4,414.78 164.63 343.32 169.84 173.48 2.47 103.62 2.021 Pass- 4,500.00 4,425.78 13.96 4,438.92 4,438.92 165.60 349.22 170.77 178.45 2.03 103.17 2.045 Pass- 4,525.00 4,449.93 14.10 4,463.07 4,463.07 166.56 355.14 171.70 183.44 1.60 102.74 2.068 Pass- 4,550.00 4,474.07 14.24 4,487.21 4,487.21 167.53 361.09 172.64 188.45 1.18 102.32 2.092 Pass- 02 March,2015-17:49 Page 7 of 28 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41.18 Pad-KU 41-18-KU 41-18 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 4,575.00 4,49821 14.38 4,511.35 4,511.35 166.49 367.05 173.58 193.47 0.78 101.92 2.115 Pass- 4,600,00 4,522.36 14.52 4,535.50 4,535.50 169.46 373.02 174.52 198.51 0.39 101.53 2.137 Pass- 4,625.00 4,546.50 14.66 4,559.64 4,559.64 170.43 379.02 175.46 203.56 0.01 101.15 2.160 Pass- 4,650.00 4,570,64 14.80 4,583.78 4,583.78 171.39 385.03 176.40 208.63 -0.36 100.78 2.183 Pass- 4,675.00 4,594.79 14.94 4,607.93 4,607.93 172.36 391.06 177.34 213.71 -0.71 100.43 2.205 Pass- 4,700.00 4,618.93 15.08 4,632.07 4,632.07 173.32 397.10 178.29 218.81 -1.06 100.09 2.227 Pass- 4,725.00 4,643.07 15.22 4,656.21 4,65621 174.29 403.15 179.24 223.92 -1.39 99.75 2.249 Pass- 4,750.00 4,667.22 15.36 4,680.36 4,680.36 175.25 409.22 180.18 229.04 -1.72 99.43 2.271 Pass- 4,775.00 4,691.36 15.50 4,704.50 4,704.50 17622 415.30 181.13 234.17 -2.03 99.11 2.293 Pass- 4,800.00 4,715.51 15.64 4,726.65 4,728.65 177.19 421.39 182.08 239.31 -2.34 98.81 2.314 Pass- 4,825.00 4,739.65 15.78 4,752.79 4,752.79 178.15 427.50 183.04 244.46 -2.63 96.51 2.336 Pass- 4,850.00 4,763.79 15.92 4,776.93 4,776.93 179.12 433.61 183.99 249.62 -2.92 96.22 2.357 Pass- 4,875.00 4,787,94 16.05 4,801.08 4,801.08 180.08 439.74 184.94 254.80 -3.20 97.94 2.378 Pass- 4,900.00 4,612.08 16.19 4,825.22 4,82522 181.05 445.88 185.90 259.98 -3.47 97.67 2.398 Pass- 4,925.00 4,836.22 16.33 4,849.36 4,849.36 182.01 452.02 186.85 265.17 -3.74 97.40 2.419 Pass- 4,950.00 4,860.37 16.48 4,873.51 4,873.51 182.98 458.18 187.81 270.37 -4.00 97.15 2.440 Pass- 4,975.00 4,884.51 16.62 4,897.65 4,897.65 183.95 464.34 188.77 275.57 -4.25 96.90 2.460 Pass- 5,000.00 4,908.65 16.76 4,921.79 4,921.79 184.91 470.52 189.73 280.79 -4.49 96.65 2.480 Pass- 5,025.00 4,932.80 16.90 4,945.94 4,945.94 185.88 476.70 190.69 286.01 -4,73 96.41 2.500 Pass- 5,050.00 4,956.94 17.04 4,970.08 4,970.08 186.84 482.89 191.65 291.24 -4.96 96.18 2.520 Pass- 5,075.00 4,981.08 17.18 4,994.22 4,994.22 187.61 489.08 192.61 296.47 -5.19 95.95 2.539 Pass- 5,100.00 5,005.23 17.32 5,018.37 5,018.37 188.77 495.29 193.57 301.72 -5.41 95.73 2.559 Pass- 5,125.00 5,029.37 17.46 5,042.51 5,042.51 189.74 501.50 194.54 306.97 -5.63 95.52 2.576 Pass- 5,150.00 5,053.51 17.60 5,066.65 5,066.65 190.71 507.72 195.50 312.22 -5.83 95.31 2.597 Pass- 5,175.00 5,077.66 17.74 5,090.80 5,090.80 191.67 513.95 196.46 317.48 -6.04 95.10 2.616 Pass- 5,200.00 5,101.80 17.88 5,114.94 5,114.94 192.64 520.18 197A3 322.75 -6.24 94.90 2.635 Pass- 5,225.00 5,125.94 18.02 5,139.08 5,139.08 193.60 526.42 198.40 328.02 -6.43 94.71 2.653 Pass- 5,250.00 5,150.09 18.16 5,163.23 5,163.23 194.57 532.66 199.36 333.30 -6.63 94.52 2.672 Pass- 5,275.00 5,174.23 18.30 5,187.37 5,187.37 195.53 536.91 200.33 336.58 -6.81 94.33 2.690 Pass- 5,300.00 5,198.37 18.44 5,211.51 5,211.51 196.50 545.17 201.30 343.87 -6.99 94.15 2.708 Pass- 5,325.00 5,222.52 18.58 5,235.66 5,235.66 197.47 551.43 202.26 349.16 -7.17 93.97 2.726 Pass- 02 March,2015-17:49 Page 8 0128 COMPASS • • Hilcorp Energy Company HALLIBURT©N Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range: DAO to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) AxisI2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 5,350.00 5,246.66 18.72 5,259.90 5,259.80 198.43 557.69 203.23 354.46 -7.35 93.80 2.744 Pass- 5,375.00 5,270.80 18.87 5,283.94 5,283.94 199.40 563.96 204.20 359.76 -7.52 93.63 2.762 Pass- 5,400.00 5,294.95 19.01 5,308.09 5,306.09 200.36 570.24 205.17 365.07 -7.68 93.46 2.779 Pass- 5,425.00 5,319.09 19.15 5,332.23 5,332.23 201.33 576.52 206.14 370.38 -7.84 93.30 2.797 Pass- 5,450.00 5,343.23 19.29 5,356.37 5,356.37 202.29 582.81 207.11 375.69 -8.00 93.14 2.814 Pass- 5,475.00 5,367.38 19.43 5,380.52 5,380.52 203.26 589.10 206.08 381.01 -8.16 92.98 2.631 Pass- 5,500.00 5,391.52 19.57 5,404.66 5,404.66 204.23 595.39 209.05 386.34 -8.31 92.83 2.848 Pass- 5,525.00 5,415.67 19.71 5,428.81 5,428.81 205.19 601.69 210.03 391.66 -8.46 92.68 2.865 Pass- 5,550.00 5,439.81 19.85 5,452.95 5,452.95 206.16 607.99 211.00 396.99 -8.61 92.54 2.881 Pass- 5,575.00 5,463.95 19.99 5,477.09 5,477.09 207.12 614.30 211.97 402.32 -6.75 92.39 2.698 Pass- 5,600.00 5,488.10 20.14 5,501.24 5,501.24 208.09 620.61 212.95 407.66 -8.89 92.25 2.914 Pass- 5,625.00 5,512.24 20.28 5,525.38 5,525.38 209.06 626.92 213.92 413.00 -9.03 92.12 2.931 Pass- 5,650.00 5,536.38 20.42 5,549.52 5,549.52 210.02 633.24 214.89 418.34 -9.16 91.98 2.947 Pass- 5,675.00 5,560.53 20.56 5,573.67 5,573.67 210.99 639.56 215.87 423.69 -9.29 91.85 2.963 Pass- 5,700.00 5,584.67 20.70 5,597.81 5,597.81 211.95 645.88 216.84 429.04 -9.42 91.72 2.979 Pass- 5,725.00 5,608.81 20.84 5,621.95 5,621.95 212.92 652.21 217.82 434.39 -9.55 91.59 2.994 Pass- 5,750.00 5,632.96 20.98 5,646.10 5,646.10 213.88 658.54 218.79 439.74 -9.67 91.47 3.010 Pass- 5,775.00 5,657.10 21.13 5,670.24 5,670.24 214.85 664.87 219.77 445.10 -9.80 91.35 3.025 Pass- 5,800.00 5,681.24 21.27 5,694.38 5,694.38 215.82 671.21 220.74 450.46 -9.92 91.23 3.041 Pass- 5,825.00 5,705.39 21.41 5,718.53 5,718.53 216.78 677.54 221.72 455.82 -10.03 91.11 3.056 Pass- 5,850.00 5,729.53 21.55 5,742.67 5,742.67 217.75 683.89 222.70 461.19 -10.15 90.99 3.071 Pass- 5,875.00 5,753.67 21.69 5,766.61 5,766.81 218.71 690.23 223.67 466.56 -10.26 90.88 3.086 Pass- 5,900.00 5,777.82 21.83 5,790.96 5,790.96 219.68 696.58 224.65 471.93 -10.37 90.77 3.101 Pass- 5,925.00 5,601.96 21.98 5,815.10 5,815.10 220.64 702.93 225.63 477.30 -10.48 90.66 3.115 Pass- 5,950.00 5,626.10 22.12 5,839.24 5,839.24 221.61 709.28 226.61 482.67 -10.59 90.55 3.130 Pass- 5,975.00 5,850.25 22.26 5,863.39 5,863.39 222.58 715.63 227.58 488.05 -10.70 90.45 3.144 Pass- 6,000.00 5,874.39 22.40 5,887.53 5,887.53 223.54 721.99 228.56 493,43 -10.80 90.34 3.159 Pass- 6,025.00 5,898.53 22.54 5,911.67 5,911.67 224.51 728.35 229.54 498.81 -10.90 90.24 3.173 Pass- 6,050.00 5,922.68 22.68 5,935.82 5,935.82 225.47 734.71 230.52 504.19 -11.00 90.14 3.187 Pass- ' 6,075.00 5,946.82 22.83 5,959.96 5,959.96 226.44 741.07 231.50 509.58 -11.10 90.04 3.201 Pass- 6,100.00 5,970.96 22.97 5,984.10 5,984.10 227.40 747.44 232.48 514.96 -11.19 89.95 3.215 Pass- 02 March,2015-17:49 Page 9 of 28 COMPASS • lilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis12 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 6,125.00 5,995.11 23.11 6,008.25 6,008.25 228.37 753.81 233.46 520.35 -11.29 89.85 3.229 Pass- 6,150.00 6,019.25 23.25 6,032.39 6,032.39 229.34 760.18 234.44 525.74 -11.38 89.76 3.243 Pass- 6,175.00 6,043.39 23.39 6,056.53 6,056.53 230.30 766.55 235.42 531.13 -11.47 89.67 3.256 Pass- 6,200.00 6,067.54 23.54 6,080.68 6,080.68 23127 772.92 236.40 536.53 -11.56 89.58 3.270 Pass- 6,225.00 6,091.68 23.68 6,104.82 6,104.82 232.23 779.30 237.38 541.92 -11.65 89.49 3.283 Pass- 6,250.00 6,115.83 23.82 6,128.97 6,128.97 233.20 785.68 238.36 547.32 -11.74 89.40 3.296 Pass- 6,275.00 6,139.97 23.96 6,153.11 6,153.11 234.16 792.06 239.34 552.72 -11.83 89.32 3.309 Pass- 6,300.00 6,164.11 24.10 6,177.25 6,177.25 235.13 798.44 240.32 558.12 -11.91 89.23 3.322 Pass- 6,325.00 6,188.26 24.25 6,201.40 6,201.40 236.10 804.82 241.30 563.52 -11.99 89.15 3.335 Pass- 6,350.00 6,212.40 24.39 6,225.54 6,225.54 237.06 811.20 242.28 568.92 -12,08 89.07 3.348 Pass- 6,375.00 6,236.54 24.53 6,249.68 6,249.68 238.03 817.59 243.26 574.33 -12.16 88.99 3.361 Pass- 6,400.00 6,260.69 24.67 6,273.83 6,273.83 238.99 823.98 244.24 579.73 -12.24 88.91 3.374 Pass- 6,425.00 6,284.83 24.79 6,297.97 6,297.97 239.96 830.37 245.19 585.17 -12.31 88.83 3.387 Pass- 6,450.00 6,308.97 24.90 6,322.11 6,322.11 240.92 836.76 246.15 590.61 -12.39 88.75 3.399 Pass- 6,475.00 6,333.12 25.01 6,34626 6,346.26 241.89 643.15 247.10 596.05 -12.47 88.68 3.412 Pass- 6,500.00 6,35726 25.13 6,370.40 6,370.40 242.86 649.54 248.06 601.49 -12.54 88.60 3.425 Pass- 6,525.00 6,381.40 25.21 6,394.54 6,394.54 243.82 855.94 248.72 607.22 -12.62 88.53 3.441 Pass- 6,550.00 6,405.55 25.30 6,418.69 6,418.69 244.79 862.34 249.64 612.69 -12.69 88.46 3.454 Pass- 6,575.00 6,429.69 25.39 6,442.83 6,442.83 245.75 868.73 250.57 618.16 -12.76 88.38 3.467 Pass- 6,600.00 6,453.63 25.47 6,466.97 6,466.97 246.72 875.13 251.50 623.63 -12.83 88.31 3.480 Pass- 6,625.00 6,477.98 25.56 6,491.12 6,491.12 247.68 881.53 252.43 629.11 -12.90 8824 3.492 Pass- 6,650.00 6,502.12 25.65 6,515.26 6,515.26 248.65 887.93 253.35 634.58 -12.97 88.18 3.505 Pass- 6,675.00 6,526.26 25.74 6,539.40 6,539.40 249.62 894.34 254.28 640.06 -13.03 88.11 3.517 Pass- 6,700.00 6,550.41 25.83 6,563.55 6,563.55 250.58 900.74 255.21 645.53 -13.10 88.04 3.529 Pass- 6,725.00 6,574.55 25.92 6,587.69 6,587.69 251.55 907.15 256.14 651.01 -13.17 87.98 3.542 Pass- 6,750.00 6,598.69 26.01 6,611.83 6,611.83 252.51 913.55 257.07 656.48 -1323 87.91 3.554 Pass- 6,775.00 6,622.84 26.10 6,635.96 6,635.98 253.48 919.96 256.00 661.96 -1329 87.85 3.566 Pass- 6,800.00 6,646.98 26.19 6,660.12 6,660.12 254.44 926.37 258.93 667.44 -13.36 87.79 3.578 Pass- 6,625.00 6,671.12 26.28 6,684.26 6,684.26 255.41 932.78 259.86 672.92 -13.42 87.72 3.590 Pass- 6,850.00 6,69527 26.38 6,708.41 6,708.41 256.38 939.19 260.79 678.40 -13.48 87.66 3.601 Pass- 6,875.00 6,719.41 26.47 6,732.55 6,732.55 257.34 945.60 261.72 683.88 -13.54 87.60 3.613 Pass- 02 March,2015-17:49 Page 100f28 COMPASS • 0 Hilcorp Energy Company H ALLI B U RTO N Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 6,900.00 6,743.55 26.56 6,756.69 6,756.69 258.31 952.02 262.66 689.36 -13.60 87.54 3.625 Pass- 6,925.00 6,767.70 26.65 6,780.84 6,780.84 259.27 958.43 263.59 694.84 -13.66 87.49 3.636 Pass- 6,950.00 6,791.84 26.75 6,804.98 6,804.98 260.24 964.85 264.52 700.32 -13.72 67.43 3.648 Pass- 6,975.00 6,815.98 26.84 6,829.12 6,829.12 261.20 971.26 265.45 705.81 -13.77 87.37 3.659 Pass- 7,000,00 6,840.13 26.94 6,853.27 6,853.27 262.17 977.68 266.39 711.29 -13.83 87.31 3.670 Pass- 7,025.00 6,864.27 27.03 6,877.41 6,877.41 263.14 984.10 267.32 716.77 -13.88 87.26 3.681 Pass- 7,050.00 6,868.42 27.13 6,901.56 6,901.56 264.10 990.51 268.26 722.26 -13.94 67.20 3.692 Pass- 7,075.00 6,912.56 27.23 6,925.70 6,925.70 265.07 996.93 269.19 727.74 -13.99 87.15 3.703 Pass- 7,100.00 6,936.70 27.32 6,949.84 6,949.84 266.03 1,003.36 270.13 733.23 -14.05 87.10 3.714 Pass- 7,125.00 6,960.85 27.42 6,973.99 6,973.99 267.00 1,009.78 271.06 738.72 -14.10 87.04 3.725 Pass- 7,150.00 6,984.99 27.52 6,998.13 6,998.13 267.97 1,016.20 271.99 744.21 -14.01 86.99 3.736 Pass- 7,175.00 7,009.13 27.61 7,022.27 7,022.27 268.93 1,022.65 272.74 749.90 -10.20 86.95 3.749 Pass- 7,200.00 7,033.27 27.71 7,046.41 7,046.41 269.90 1,029.14 273.51 755.64 -6.38 86.94 3.763 Pass- 7,225.00 7,057A0 27.80 7,070.54 7,070.54 270.86 1,035.69 274.28 761.40 -2.58 86.95 3.776 Pass- 7,250.00 7,081.51 27,89 7,094.65 7,094.65 271.83 1,042.27 275.07 767.20 1.15 86.98 3.789 Pass- 7,275.00 7,105.59 27.98 7,118.73 7,118.73 272.79 1,048.90 275.87 773.04 4.81 87.04 3.802 Pass- 7,300.00 7,129.64 28.08 7,142.78 7,142.78 273.75 1,055.57 276.67 778.90 8.37 87.12 3.615 Pass- 7,325.00 7,153.65 28.17 7,166.79 7,166.79 274.71 1,062.28 277.48 784.81 11.80 87.22 3.826 Pass- 7,350.00 7,177.61 28.26 7,190.75 7,190.75 275.67 1,069.03 278.29 790.75 15.11 87.35 3.841 Pass- 7,375.00 7,201.51 28.36 7,214.65 7,214.65 276.63 1,075.83 279.10 796.72 18.28 67.49 3.855 Pass- 7,400.00 7,225.35 28.45 7,238.49 7,238.49 277.58 1,082.67 279.92 802.75 21.31 87.66 3.668 Pass- 7,425.00 7,249.12 28.55 7,262.26 7,262.26 278.53 1,089.55 280.73 808.81 24.20 87.85 3.881 Pass- 7,450.00 7,272.81 28.64 7,285.95 7,285.95 279.48 1,096.48 281.55 814.93 26.96 88.05 3.894 Pass- 7,475.00 7,296.46 28.73 7,309.60. 7,309.60 280.42 1,103.37 282.75 820.62 28.53 88.28 3.902 Pass- 7,500.00 7,320.11 28.83 7,333.25 7,333.25 261.37 1,110.25 283.63 826.62 28.76 88.50 3.914 Pass- 7,525.00 7,343.76 28.92 7,356.90 7,356.90 282,32 1,117.15 284.50 832.64 28.97 68.72 3.927 Pass- 7,550.00 7,367.42 29.02 7,380.56 7,380.56 283.26 1,124.06 285.38 838.68 29.19 88.93 3.939 Pass- 7,575.00 7,391.07 29.12 7,404.21 7,404.21 284.21 1,130.99 286.26 844.73 29.40 89.15 3.951 Pass- 7,600.00 7,414.72 29.22 7,427.86 7,427.86 285.15 1,137.93 287.13 850.80 29.61 89.36 3.963 Pass- 7,625.00 7,438.37 29.32 7,451.51 7,451.51 286.10 1,144.89 288.02 856.88 29.82 89.57 3.975 Pass- 7,650.00 7,462.02 29.42 7,475.16 7,475.16 287.05 1,151.86 288.90 862.97 30.03 89.77 3.987 Pass- 02 March,2015-17:49 Page 11 of 28 COMPASS • III Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 7,675.00 7,485.67 29.52 7,498.81 7,498.81 287.99 1,158.85 289.78 869.08 30.23 89.97 3.999 Pass- 7,700.00 7,509.32 29.62 7522.46 7522.46 288.94 1,165.86 290.66 875.20 30.43 90.17 4.011 Pass- 7,725.00 7,532.97 29.72 7,546.11 7,546.11 289.68 1,172.87 291.54 881.33 30.63 90.37 4.023 Pass- 7,750.00 7,556.62 29.83 7,569.76 7,569.76 290.63 1,179.90 292.42 887.48 30.83 90.57 4.035 Pass- 7,775.00 7,580.27 29.93 7,593.1 7,593.41 291.78 1,186.95 293.31 893.64 31.02 90.76 4.047 Pass- 7,800.00 7,603.93 30.03 7,617.07 7,617.07 292.72 1,194.01 294.19 899.82 31.21 90.95 4.059 Pass- 02 March,2015-17:49 Page 12 of 28 COMPASS Hilcorp Energy Company HALLIBURTCIN Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13-8 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 18.00 18.00 0.00 10.40 10.40 0.00 266.96 0.87 266.09 -111.67 -111.67 306.781 Pass- 25.00 25.00 0.01 10.40 10.40 0.00 266.02 0.88 265.14 -111.67 -111.67 302.968 Pass- 50.00 50.00 0.04 10.40 10.40 0.00 264.15 0.91 263.25 -111.67 -111.67 291.538 Pass- 61.74 61.74 0.05 14.88 14.88 0.09 264.05 1.01 263.05 -111.67 -111.67 261.722 Pass- 75.00 75.00 0.06 28.14 28.14 0.35 264.05 1.29 262.77 -111.67 -111.67 204.873 Pass- 100.00 100.00 0.09 53.14 53.14 0.85 264.05 1.82 262.24 -111.67 -111.67 145.337 Pass- 125.00 125.00 0.15 78.14 78.14 1.35 264.05 2.37 261.68 -111.67 -111.67 111.275 Pass- 150.00 150.00 0.20 103.14 103.14 1.92 264.05 2.99 261.06 -111.67 -111.67 88.256 Pass- 175.00 175.00 0.26 128.14 128.14 2.92 264.05 4.05 260.01 -111.67 -111.67 65.229 Pass- 200.00 200.00 0.32 153.14 153.14 3.92 264.05 5.10 258.95 -111.67 -111.67 51.732 Pass- 225.00 225.00 0.37 178.14 178.14 4.92 264.05 6.16 257.89 -111.67 -111.67 42.863 Pass- 250.00 250.00 0.43 203.14 203.14 5.92 264.05 7.22 256.84 -111.67 -111.67 36.589 Pass- 275.00 275.00 0.49 228.14 228.14 6.92 264.05 8.27 255.78 -111.67 -111.67 31.918 Pass- 300.00 300.00 0.54 253.14 253.14 7.92 264.05 9.33 254.73 -111.67 -111.67 26.304 Pass- 325.00 325.00 0.60 278.14 278.14 8.92 264.05 10.39 253.67 -111.67 -111.67 25.426 Pass- 350.00 350.00 0.65 303.14 303.14 9.92 264.05 11.44 252.61 -111.67 -111.67 23.079 Pass- 375.00 375.00 0.71 328.14 328.14 10.92 264.05 12.50 251.56 -111.67 -111.67 21.128 Pass- 400.00 400.00 0.77 353.14 353.14 11.92 264.05 13.55 250.50 -111.67 -111.67 19.482 Pass- 425.00 425.00 0.82 378.14 378.14 12.92 264.05 14.61 249.44 -111.67 -111.67 18.074 Pass- 450.00 450.00 0.88 403.14 403.14 13.92 264.05 15.67 248.39 -111.67 -111.67 16.855 Pass- 475.00 475.00 0.94 428.14 428.14 14.92 264.05 16.72 247.33 -111.67 -111.67 15.790 Pass- 500.00 500.00 0.99 453.14 453.14 15.92 264.05 17.78 246.28 -111.67 -111.67 14.852 Pass- 525.00 525.00 1.05 478.14 478.14 16.92 264.05 18.83 24522 -111.67 -111.67 14.020 Pass- 550.00 550.00 1.10 503.14 503.14 17,92 264.05 19.89 244.16 -111.67 -111.67 13275 Pass- 575.00 575.00 1.16 528.14 528.14 18.92 264.05 20.95 243.11 -111.67 -111.67 12.606 Pass- 600.00 600.00 1.22 553.14 553.14 19.92 264.05 22.00 242.05 -111.67 -111.67 12.001 Pass- 625.00 625.00 1.27 578.14 578.14 20.92 264.05 23.06 241.00 -111.67 -111.67 11.451 Pass- 650.00 650.00 1.33 603.14 603.14 21.92 264.05 24.12 239.94 -111.67 -111.67 10.949 Pass- 675.00 675.00 1.38 628.14 628.14 22.92 264.05 25.17 238.88 -111.67 -111.67 10.490 Pass- 700.00 700.00 1.44 653.14 653.14 23.92 264.05 26.23 237.83 -111.67 -111.67 10.068 Pass- 725.00 725.00 1.50 678.14 678.14 24.92 264.05 2728 236.77 -111.67 -111.67 9.678 Pass- 02 March,2015-17:49 Page 13 of 28 COMPASS 1 0 • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13-8 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axls/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 750.00 750.00 1.55 703.14 703.14 25.92 264.05 28.34 235.71 -111.67 -111.67 9.317 Pass- 775.00 775.00 1.61 728.14 728.14 26.92 264.05 29.40 234.66 -111.67 -111.67 8.982 Pass- 800.00 80000 1.67 753.14 753.14 27.92 264.05 30.45 233.60 -111.67 -111.67 8.671 Pass- 825.00 825.00 1.72 778.14 778.14 28.92 264.05 31.51 232.55 -111.67 -111.67 8.380 Pass- 850.00 850.00 1.78 803.14 803.14 29.92 264.05 32.57 231.49 -111.67 -111.67 8.108 Pass- 875.00 875.00 1.83 828.14 828.14 30.92 264.05 33.62 230.43 -111.67 -111.67 7.854 Pass- 900.00 900.00 1.89 853.14 853.14 31.92 264.05 34.68 229.38 -111.67 -111.67 7.615 Pass- 925.00 925.00 1.95 878.14 878.14 32.92 264.05 35.73 228.32 -111.67 -111.67 7.389 Pass- 950.00 950.00 2.00 903.14 903.14 33.92 264.05 36.79 227.26 -111.67 -111.67 7.177 Pass- 975.00 975.00 2.06 928.14 928.14 34.92 264.05 37.85 226.21 -111.67 -111.67 6.977 Pass- 1,000.00 1,000.00 2.12 953.14 953.14 35.92 264.05 38.90 225.15 -111.67 -111.67 6.788 Pass- 1,025.00 1,025.00 2.17 978.14 978.14 36.92 264.05 39.96 224.10 -111.67 -111.67 6.608 Pass- 1,050.00 1,050.00 2.23 1,003.14 1,003.14 37.92 264.05 41.01 223.04 -111.67 -111.67 6.438 Pass- 1,075.00 1,075.00 2.28 1,028.14 1,028.14 38.92 264.05 42.07 221.98 -111.67 -111.67 6.276 Pass- 1,100.00 1,100.00 2.34 1,053.14 1,053.14 39.92 264.05 43.13 220.93 -111.67 -111.67 6.123 Pass- 1,125.00 1,125.00 2.40 1,078.14 1,078.14 40.92 264.05 44.18 219.87 -111.67 -111.67 5.976 Pass- 1,150.00 1,150.00 2.45 1,103.14 1,103.14 41.92 264.05 45.24 218.82 -111.67 -111.67 5.837 Pass- 1,175.00 1,175.00 2.51 1,128.14 1,128.14 42.92 264.05 46.30 217.76 -111.67 -111.67 5.704 Pass- 1,200.00 1,200.00 2.56 1,153.14 1,153.14 43.92 264.05 47.35 216.70 -111.67 -111.67 5.576 Pass- 1,225.00 1,225.00 2.62 1,178.14 1,178.14 44.92 264.05 48.28 215.78 -111.67 -111.67 5.469 Pass- 1,250.00 1,250.00 2.68 1,203.14 1,203.14 45.92 264.05 49.33 214.72 -111.67 -111.67 5.352 Pass- 1,275.00 1,275.00 2.73 1,228.14 1,228.14 46.92 264.05 50.39 213.66 -111.67 -111.67 5.240 Pass- 1,300.00 1,300.00 2.79 1,253.14 1,253.14 47.92 264.05 51.45 212.61 -111.67 -111.67 5.133 Pass- 1,325.00 1,325.00 2.85 1,278.14 1,278.14 48.92 264.05 52.50 211.55 -111.67 -111.67 5.029 Pass- 1,350.00 1,350.00 2.90 1,303.14 1,303.14 49.92 264.05 53.56 210.50 -111.67 -111.67 4.930 Pass- 1,375.00 1,375.00 2.96 1,328.14 1,328.14 50.92 264.05 54.62 209.44 -111.67 -111.67 4.835 Pass- 1,400.00 1,400.00 3.01 1,353.14 1,353.14 51.92 264.05 55.67 208.38 -111.67 -111.67 4.743 Pass- 1,425.00 1,425.00 3.07 1,378.14 1,378.14 52.92 264.05 56.73 207.33 -111.67 -111.67 4.655 Pass- 1,450.00 1,450.00 3.13 1,403.14 1,403.14 53.92 264.05 57.78 20627 -111.67 -111.67 4.570 Pass- 1,475.00 1,475.00 3.18 1,428.14 1,428.14 54.92 264.05 58.84 205.22 -111.67 -111.67 4.488 Pass- 1,500.00 1,500.00 3.24 1,453.14 1,453.14 55.92 264.05 59.90 204.16 -111.67 -111.67 4.409 Pass- 02 March,2015-17:49 Page 14 of 28 COMPASS • 0 Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13-8 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 1,525.00 1,525.00 3.27 1,478.14 1,478.14 56.92 264.05 60.83 203.23 -111.67 -111.67 4.341 Pass- 1,550.00 1,550.00 3.30 1503.14 1,503.14 57.92 264.05 61.85 202.20 -111.67 -111.67 4.269 Pass- 1,575.00 1,575.00 3.32 1,528.14 1,528.14 58.92 264.05 62.88 201.17 -111.67 -111.67 4.199 Pass- 1,600.00 1,600.00 3.35 1,553.14 1,553.14 59.92 264.05 63.91 200.14 -111.67 -111.67 4.132 Pass- 1,625.00 1,625.00 3.36 1,578.14 1,578.14 60.92 264.05 64.92 199.14 -111.67 -111.67 4.068 Pass- 1,650.00 1,650.00 3.36 1,603.14 1,603.14 61.92 264.05 65.92 198.14 -111.67 -111.67 4.006 Pass- 1,675.00 1,675.00 3.36 1,628.14 1,628.14 62.92 264.05 66.92 197.13 -111.67 -111.67 3.946 Pass- 1,700.00 1,700.00 3.37 1,653.14 1,653.14 63.92 264.05 67.93 196.13 -111.67 -111.67 3.887 Pass- 1,725.00 1,725.00 3.38 1,678.14 1,678.14 64.92 264.05 68.93 195.12 -111.67 -111.67 3.831 Pass- 1,750.00 1,750.00 3.38 1,703.14 1,703.14 65.92 264.05 69.94 194.11 -111.67 -111.67 3.775 Pass- 1,775.00 1,775.00 3.39 1,728.14 1,728.14 66.92 264.05 70.95 193.11 -111.67 -111.67 3.722 Pass- 1,800.00 1,800.00 3.40 1,753.14 1,753.14 67.92 264.05 71.96 192.10 -111.67 -111.67 3.670 Pass- 1,825.00 1,825.00 3.41 1,778.14 1,776.14 68.92 264.05 72.97 191.09 -111.67 -111.67 3.619 Pass- 1,850.00 1,850.00 3.42 1,803.14 1,803.14 69.92 264.05 73.98 190.08 -111.67 -111.67 3.569 Pass- 1,875.00 1,875.00 3.43 1,828.14 1,828.14 70.92 264.05 74.99 189.07 -111.67 -111.67 3.521 Pass- 1,900.00 1,900.00 3.44 1,853.14 1,853.14 71.92 264.05 76.00 188.05 -111.67 -111.67 3.474 Pass- 1,925.00 1,925.00 3.46 1,878.14 1,878.14 72.92 264.05 77.02 187.04 -111.67 -111.67 3.429 Pass- 1,950.00 1,950.00 3.47 1,903.14 1,903.14 73.92 264.05 78.03 186.03 -111.67 -111.67 3.384 Pass- 1,975.00 1,975.00 3.49 1,928.14 - 1,928.14 74.92 264.05 79.04 185.01 -111.67 -111.67 3.341 Pass- 2,000.00 2,000.00 3.50 1,953.14 1,953.14 75.92 264.05 80.06 184.00 -111.67 -111.67 3.298 Pass- 2,025.00 2,025.00 3.52 1,978.14 1,978.14 76.92 263.89 81.07 182.83 147.18 -111.68 3.255 Pass- 2,050.00 2,049.99 3.53 2,003.13 2,003.13 77.92 263.41 82.07 181.35 147.16 -111.70 3.210 Pass- 2,075.00 2,074.98 3.55 2,028.12 2,026.12 78.92 262.61 83.05 179.56 147.13 -111.73 3.162 Pass- 2,100.00 2,099.95 3.57 2,053.09 2,053.09 79.92 261.48 84.02 177.47 147.08 -111.77 3.112 Pass- 2,125.00 2,124.91 3.59 2,078.05 2,078.05 80.91 260.04 84.97 175.07 147.02 -111.83 3.060 Pass- 2,150.00 2,149.85 3.61 2,102.99 2,102.99 81.91 258.27 85.91 172.36 146.95 -111.91 3.006 Pass- 2,175.00 2,174.76 3.63 2,127.90 2,127.90 82.91 256.18 86.83 169.35 146.86 -112.00 2.950 Pass- 2,200.00 2,199.63 3.65 2,152.77 2,152.77 83.90 253.78 87.73 166.04 146.76 -112.10 2.893 Pass- 2,225.00 2,224,48 3.68 2,177.62 2,177.62 84.90 251.05 88.62 162.43 146.64 -11222 2.833 Pass- 2,250.00 2,249.29 3.70 2,202.43 2,202.43 85.89 248.01 89.49 158.51 146.50 -112.36 2.771 Pass- 2,275.00 2,274.05 3.73 2,227.19 2,227.19 86.88 244.65 90.35 154.30 146.34 -112.52 2.708 Pass- 02 March,2015-17:49 Page 15 of 28 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13-B Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 2,300.00 2,298.77 3.76 2,251.91 2,251.91 87.87 240.98 91.18 149.80 146.17 -112.69 2.643 Pass- 2,325.00 2,323.43 3.80 2,276.57 2,276.57 88.85 236.99 92.00 144.99 145.97 -112.89 2.576 Pass- 2,350.00 2,348.04 3.84 2,301.18 2,301.18 89.84 232.69 92.79 139.89 145.75 -113.11 2.508 Pass- 2,375.00 2,372.60 3.88 2,325.74 2,325.74 90.82 226.07 93.57 134.50 145.50 -113.35 2.437 Pass- . 2,400.00 2,397.08 3.92 2,350.22 2,350.22 91.80 223.15 94.33 128.83 145.23 -113.63 2.366 Pass- 2,425.00 2,421.50 3.98 2,374.64 2,374.64 92.78 217.92 95.07 122.86 144.92 -113.93 2.292 Pass- 2,450.00 2,445.85 4.03 2,398.99 2,398.99 93.75 212.39 95.79 116.61 144.59 -114.27 2.217 Pass- 2,475.00 2,470.12 4.09 2,423.26 2,42326 94.72 206.56 96.49 110.07 144.21 -114.65 2.141 Pass- 2,500.00 2,494.31 4.15 2,447.45 2,447.45 95.69 200.43 97.17 103.26 143.79 -115.07 2.063 Pass- 2,525.00 2,518.45 4.22 2,471.59 2,471.59 96.66 194.14 98.13 96.01 143.33 -115.53 1.978 Pass- 2,550.00 2,542.59 4.30 2,495.73 2,495.73 97.62 187.86 99.12 88.74 142.83 -116.02 1.895 Pass- 2,575.00 2,566.74 4.38 2,519.88 2,518.88 98.59 181.60 100.10 81.49 142.31 -116.55 1.814 Pass- 2,600.00 2,590.88 4.45 2,544.02 2,544.02 99.55 175.35 101.09 74.26 141.74 -117.11 1.735 Pass- 2,625.00 2,615.03 4.54 2,568.17 2,568.17 100.52 169.12 102.09 67.03 141.14 -117.72 1.657 Pass- 2,650.00 2,639.17 4.63 2,592.31 2,592.31 101.48 162.91 103.09 59.83 140.49 -118.37 1.580 Pass- 2,675.00 2,663.31 4.72 2,616.45 2,616.45 102.45 156.73 104.09 52.64 139.79 -119.07 1.506 Pass- 2,700.00 2,687.46 4.81 2,640.60 2,640.60 103.42 150.57 105.10 45.47 139.03 -119.83 1.433 Pass- 2,725.00 2,711.60 4.90 2,664.74 2,664.74 104.38 144.44 106.12 38.32 138.20 -120.65 1.361 Pass- 2,750.00 2,735.74 5.00 2,688.88 2,688.88 105.35 138.34 107.15 31,19 137.30 -121.55 1.291 Pass- 2,775.00 2,759.89 5.10 2,713.03 2,713.03 106.31 132.28 108.18 24.09 136.32 -122.53 1.223 Pass- 2,800.00 2,784.03 5.20 2,737.17 2,737.17 107.28 126.26 109.23 17.03 135.25 -123.61 1.156 Pass- 2,825.00 2,808.17 5.31 2,761.31 2,761.31 108.24 120.29 110.29 10.00 134.07 -124.79 1.091 Pass- 2,850.00 2,832.32 5.41 2,785.46 2,785.46 109.21 114.37 111.37 3.01 132.77 -126.09 1.027 Pass- 2,875.00 mcrEE ! IMEM2 IMEIZS ! =11313 !II MIME ® MEE 0.96 FAIL- 2,900.00 2,880.60 IIMEE ME= I=EME mar =ME ® 1111111=3 MI= =Mir MOM FAIL- ®' " MI= M.I =BCiln MEM ® =OMIT 0.846 FAIL- 2,950.00 IMMMI IIIIME NM= 2,882.03 !MEI FAIL- 2,975.00MOM 1111.= �7 FAIL- 3,000.90 C6+2 ®.' 1 !CO IIMEM 0.68 FAIL- 3,025.00 ®" IME ME= MN= MI3120 11M11111 � 1 ' ®' FAIL- 3,050.00 ''ME I� MIME =7�7aa.�'+MINIM=DIE FAIL- 02 March,2015-17:49 Page 16 of 28 COMPASS • • Hilcorp Energy Company H ALLI B U RTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13-8 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft)!T� (usft) r. Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning li 3,075.00 I11=3E IA"3M IIIM .C1 MIZE MEM FAIL- 3,100.00 ®' 1=n ME= IIIMEgn =DM MI= =DM 111=121 1=l1M ® 0.500 FAIL- MUM MEM MEM11M13131ii i111EIZE 58.08 ! srxrn ® 0.463 FAIL- 3,150.00 MEM MINE ®' IIIMIECIE ! -162.96 115l FAIL- MEM =En NMNI= MIME MOM MI= Mr= ! IIMEDM "" FAIL- 3,200.00 EIME MOE 1111131M Mr= 122.73 II! FAIL- IMMO MIMI !I 1=0E1 1111111=1 48.66 ME �!f..11FAIL- NM= IIIIMEE MEM MEM MB= 124.65 EWE =Er IIIIIIIIIIIIIII FAIL- 3,250.00 NW= Ewa ® ® 124.66 FAIL- ®" MEM ISM 3,195.89 ..j'J � 48.69 ®�' man®' ' FAIL- 3,300.00 11111 "' =MEIMOMEM MEM liZE =12101=112IE FAIL- MEM ®, 127.56 ! 0.386 FAIL- 3,350.00 IIIIIIII=21 I® !I 140.48 0.40, FAIL- FAIL- 3,400.00 MIMEO 111111107 1 11E1=31 MEM ®' ''' FAIL- WM ME= 1111111111 NEM ":1:1111 !II!MI MEZEI ®I IS1 FAIL- 3,450.00 =ME I! MI= I=IMI EERIE 75.94 ®MUM FAIL- 3,475.00 =MS IIIA 3,389.0' MUM ® MI= FAIL- 3,500.00 ®'i" 111!TI !El 134.32 FAIL- MEM 3,484.19111=133�.�,�I ® ® 112.88 FAIL- 3,550.00 ®'' IIIIIIIIIIIIIrdy =mom moms =En 91.68 =MI!' IIIIIIIIIIIIIII! FAIL- MEMO MIIII=11111111/ 3,485.62 NEM ® �' 'C II! 0.68• FAIL- 3,600.00 111111nn ®'' MEM = IEEE102.94 106.80 IMMMO FAIL- UMW 3,580.76 UWE MOM MOM 139.15 =MI 111111531 l ®" IIIIIIIIIIIIIIITIE FAIL- 3,660.00 =Ma MEM ®i'' 111MEM 140.11 0.799 FAIL- 3,675.00 =MEM' MEE =ME =ME MI= IIMM =EMS ® =IEEE MIME FAIL- 3,700.00 3,606.33 MOM FAIL- IIIIIIIEM 3,630.48 Mr= ECM MIES =IMO MN=®'' ®" 0.907 FAIL- 3,750.00 ®' IN! II! MEM MEM MIELEIll MI= FAIL- Mgannin MIN= 10.00 3,678.76 Ma= MME IMBE MIMEM NEM®' MnnE 0.978 FAIL- 3,800.00 3,749.77 10.13 3,702.91 3,702.91 145.91 150.77 148.74 2.03 -3.62 97.52 1.014 Pass- 02 March,2015-17:49 Page 17 of 28 COMPASS '.. • • Hilcorp Energy Company HALL!BURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13-8 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. , Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 3,825.00 3,773.91 10.27 3,727.05 3,727.05 146.87 156.93 149.65 7.27 -4.38 96.76 1.049 Pass- 3,850.00 3,798.05 10.40 3,751.19 3,751,19 147.84 163.11 150.57 12.54 -5.08 96.06 1.083 Pass- 3,875.00 3,822.20 10.54 3,775.34 3,775.34 148.61 169.32 151.50 17.82 -5.73 95.41 1.118 Pass- 3,900.00 3,846.34 10.67 3,799.48 3,799.48 149.77 175.55 152.43 23.12 -6.34 94.81 1.152 Pass- 3,925.00 3,870.48 10.81 3,823.62 3,823.62 150.74 181.80 153.37 28A3 -6.90 94.25 1.185 Pass- 3,950.00 3,894.63 10.94 3,847.77 3,847.77 151.70 186.06 154.31 33.76 -7.42 93.72 1.219 Pass- 3,975.00 3,918.77 11.08 3,871.91 3,871.91 152.67 194.34 155.25 39.09 -7.91 93.23 1.252 Pass- 4,000.00 3,942.91 11.21 3,696.05 3,896.05 153.63 200.63 156.20 44.44 -8.37 92.77 1.284 Pass- 4,025.00 3,967.06 11.35 3,920.20 3,920.20 154.60 206.94 157.15 49.79 -8.80 92.34 1.317 Pass- 4,050.00 3,991.20 11.49 3,944.34 3,944.34 155.57 213.25 158.10 55.15 -9.21 91.93 1.349 Pass- 4,075,00 4,015.35 11.62 3,968.49 3,968.49 156.53 219.57 159.05 60.52 -9.59 91.55 1.381 Pass- 4,100.00 4,039.49 11.76 3,992.63 3,992.63 157.50 225.91 160.01 65.90 -9.96 91.19 1.412 Pass- 4,125.00 4,063.63 11.90 4,016.77 4,016.77 158.46 232.25 160.97 71.28 -10.30 90.85 1.443 Pass- 4,150.00 4,087.78 12.03 4,040.92 4,040.92 159.43 238.60 161.93 76.67 -10.62 90.52 1.473 Pass- 4,175.00 4,111.92 12.17 4,065.06 4,065.06 160.39 244.96 162.89 82.07 -10.93 90.22 1.504 Pass- 4,200.00 4,136.06 12.31 4,089.20 4,089.20 161.36 251.32 163.86 87.47 -11.22 89.92 1.534 Pass- 4,225.00 4,160.21 12.45 4,113.35 4,113.35 162.33 257.69 164.82 92.87 -11.50 89.65 1.563 Pass- 4,250.00 4,184.35 12.58 4,137.49 4,137.49 163.29 264.07 165.79 9828 -11.76 89.38 1.593 Pass- 4,275.00 4,208.49 12.72 4,161.63 4,161.63 164.26 270.45 166.76 103.69 -12.01 89.13 1.622 Pass- 4,300.00 4,232.64 12.86 4,185.78 4,185.78 165.22 276.84 167.73 109.11 -12.25 88.89 1.651 Pass- 4,325.00 4,256.78 13.00 4,209.92 4,209.92 166.19 283.23 168.70 114.53 -12.48 88.66 1.679 Pass- 4,350.00 4,280.92 13.13 4,234.06 4,234.06 167.15 289.62 169.67 119.96 -12.70 88.45 1.707 Pass- 4,375.00 4,305.07 13.27 4,258.21 4,258.21 168.12 296.02 170.64 125.38 -12.91 88.24 1.735 Pass- 4,400.00 4,329.21 13.41 4,282.35 4,282.35 169.09 302.43 171.61 130.81 -13.11 88.04 1.762 Pass- 4,425.00 4,353.35 13.55 4,306.49 4,306.49 170.05 308.83 172.59 136.25 -13.30 87.84 1.789 Pass- 4,450.00 4,377.50 13.69 4,330.64 4,330.64 171.02 315.24 173.56 141.68 -13.48 87.66 1.816 Pass- 4,475.00 4,401.64 13.83 4,354.78 4,354.78 171.98 321.66 174.53 147.12 -13.66 87.48 1.843 Pass- 4,500.00 4,425.78 13.96 4,378.92 4,378.92 172.95 328.07 175.51 152.56 -13.83 87.31 1.869 Pass- 4,525.00 4,449.93 14.10 4,403.07 4,403.07 173.91 334.49 176.49 158.00 -13.99 87.15 1.895 Pass- 4,550.00 4,474.07 14.24 4,427.21 4,427.21 174.88 340.91 177.46 163.45 -14.15 86.99 1.921 Pass- 4,575.00 4,498.21 14.38 4,451.35 4,451.35 175.85 347.34 178.44 168.90 -14.30 86.84 1.947 Pass- 02 March,2015-17:49 Page 18of28 COMPASS f • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pact-KU 13-8-KU 13-8 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 4,600.00 4,522.36 14.52 4,475.50 4,475.50 176.81 353.76 179.42 174.34 -14.45 66.69 1.972 Pass- 4,625.00 4,546.50 14.66 4,499.64 4,499.64 177.78 360.19 180.40 179.79 -14.59 86.55 1.997 Pass- 4,650.00 4,570.64 , 14.80 4,523.78 4,523.78 176.74 366.62 181.37 185.25 -14.72 86.42 2.021 Pass- 4,675.00 4,594.79 14.94 4,547.93 4,547.93 179.71 373.05 182.35 190.70 -14.86 86.29 2.046 Pass- 4,700.00 4,618.93 15.08 4,572.07 4,572.07 180.67 379.49 183.33 196.16 -14.98 86.16 2.070 Pass- 4,725.00 4,643.07 15.22 4,596.21 4,596.21 181.64 385.92 184.31 201.61 -15.10 86.04 2.094 Pass- 4,750.00 4,667.22 15.36 4,620.36 4,620.36 182.61 392.36 185.29 207.07 -15.22 85.92 2.118 Pass- 4,775.00 4,691.36 15.50 4,644.50 4,644.50 183.57 398.80 186.27 212.53 -15.34 85.81 2.141 Pass- 4,800.00 4,715.51 15.64 4,668.65 4,668.65 184.54 405.24 187.25 217.99 -15.45 85.69 2.164 Pass- 4,825.00 4,739.65 15.76 4,692.79 4,692.79 185.50 411.69 188.24 223.45 -15.56 85.59 2.187 Pass- 4,850.00 4,763.79 15.92 4,716.93 4,716.93 186.47 418.13 169.22 228.91 -15.66 85.48 2.210 Pass- 4,875.00 4,787.94 16.05 4,741.08 4,741.08 187.44 424.57 190.20 234.38 -15.76 85.38 2.232 Pass- 4,900.00 4,812,08 16.19 4,765.22 4,76522 188.40 431.02 191.18 239.64 -15.86 8528 2.255 Pass- 4,925.00 4,836.22 16.33 4,789.36 4,789.36 189.37 437.47 192.16 245.31 -15.95 85.19 2.277 Pass- 4,950.00 4,660.37 16.48 4,813.51 4,813.51 190.33 443.92 193.15 250.77 -16.05 85.10 2.298 Pass- 4,975.00 4,884.51 16.62 4,837.65 4,837.65 191.30 450.37 194.13 256.24 -16.14 85.01 2.320 Pass- 5,000.00 4,908.65 16.76 4,861.79 4,861.79 192.26 456.82 195.11 261.71 -16.22 84.92 2.341 Pass- 5,025.00 4,932,80 16.90 4,885.94 4,685.94 193.23 463.27 196.09 267.18 -16.31 84.83 2.362 Pass- 5,050.00 4,956.94 17.04 4,910.08 4,910.08 194.20 469.72 197.08 272.65 -16.39 84.75 2.383 Pass- 5,075.00 4,981.08 17.18 4,934.22 4,934.22 195.16 476.18 198.06 278.12 -16.47 84.67 2.404 Pass- 5,100.00 5,005.23 17.32 4,958.37 4,958.37 196.13 482.63 199.04 283.59 -16.55 84.59 2.425 Pass- 5,125.00 5,029.37 17.46 4,982.51 4,982.51 197.09 489.09 200.03 289.06 -16.63 64.52 2.445 Pass- 5,150.00 5,053.51 17.60 5,006.65 5,006.65 198.06 495.55 201.01 294.53 -16.70 84.44 2.465 Pass- 5,175.00 5,077.66 17.74 5,030.80 5,030.80 199.02 502.00 202.00 300.01 -16.77 84.37 2.485 Pass- 5,200.00 5,101.80 17.88 5,054.94 5,054.94 199.99 508.46 202.98 305.48 -16.84 84.30 2.505 Pass- 5,225.00 5,125.94 18.02 5,079.06 5,079.08 200.96 514.92 203.97 310.96 -16.91 84.23 2.525 Pass- 5,250.00 5,150.09 18.16 5,103.23 5,103.23 201.92 521,38 204.95 316.43 -16.98 84.17 2.544 Pass- 5,275.00 5,174.23 18.30 5,127.37 5,127.37 202.89 527.84 205.94 321.91 -17.04 84.10 2.563 Pass- 5,300.00 5,198.37 18.44 5,151.51 5,151.51 203.85 534.30 206.92 327.38 -17.11 84.04 2.582 Pass- 5,325.00 5,222.52 18.58 5,175.66 5,175.66 204.82 540.76 207.91 332.86 -17.17 83.98 2.601 Pass- 5,350.00 5,246.66 18.72 5,199.80 5,199.80 205.78 547.23 208.89 338.34 -17.23 83.91 2.620 Pass- 02 March,2015-17:49 Page 19 of 28 COMPASS it • • Hilcorp Energy Company H ALLI B U RTO N Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(NorthReference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13-8 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axisl2 (usft) (usft) (usft) Bearing Bearing Factor Warning 5,375.00 5270.80 18.87 5,223.94 5,223.94 206.75 553.69 209.88 343.61 -17.29 83.86 2.638 Pass- 5,400.00 5,294.95 19.01 5,248.09 5,248.09 207.72 560.15 210.86 349.29 -17.35 83.80 2.656 Pass- 5,425.00 5,319.09 19.15 5272.23 5,272.23 208.68 566.62 211.85 354.77 -17.40 83.74 2.675 Pass- 5,450.00 5,343.23 19.29 5296.37 5,296.37 209.65 573.08 212.83 360.25 -17.46 83.69 2.693 Pass- 5,475.00 5,367.38 19.43 5,320.52 5,320.52 210.61 579.55 213.82 365.73 -17.51 83.63 2.710 Pass- 5,500.00 5,391.52 19.57 5,344.66 5,344.66 211.58 566.01 214.61 371.21 -17.56 83.58 2.728 Pass- 5,525.00 5,415.67 19.71 5,368.81 5,368.81 212.54 592.48 215.79 376.69 -17.62 63.53 2.746 Pass- 5,550.00 5,439.81 19.85 5,392.95 5,392.95 213.51 598.95 216.78 382.17 -17.67 83.48 2.763 Pass- 5,575.00 5,463.95 19.99 5,417.09 5,417.09 214.48 605.41 217.77 387.65 -17.72 83.43 2.780 Pass- 5,600.00 5,488.10 20.14 5,441.24 5,441.24 215.44 611.88 218.75 393.13 -17.76 63.38 2.797 Pass- 5,625.00 5,512.24 20.28 5,465.38 5,465.38 216.41 618.35 219.74 398.61 -17.81 83.33 2.814 Pass- 5,650.00 5,536.38 20.42 5489.52 5,489.52 217.37 624.82 220.73 404.09 -17.86 83.29 2.831 Pass- 5,675.00 5,560.53 20.56 5,506.00 5,506.00 217.91 631.33 221.30 410.03 -17.90 83.24 2.853 Pass- 5,700.00 5,584.67 20.70 5,506.00 5,506.00 217.91 638.55 221.36 417.19 -17.95 63.20 2.885 Pass- 5,725.00 5,608.81 20.84 5,506.00 5,506.00 217.91 646.65 221.42 425.23 -17.99 83.15 2.921 Pass- 5,750.00 5,632.96 20.98 5,506.00 5,506.00 217.91 655.61 221.47 434.13 -18.03 83.11 2.960 Pass- 5,775.00 5,657.10 21.13 5,506.00 5,506.00 217.91 665.38 221.53 443.85 -18.08 83.07 3.004 Pass- 5,800.00 5,681.24 21.27 5,506.00 5,506.00 217.91 675.94 221.59 454.35 -18.12 83.03 3.050 Pass- 5,825.00 5,705.39 21.41 5,506.00 5,506.00 217.91 687.25 221.65 465.60 -18.16 82.99 3.101 Pass- 5,850.00 5,729.53 21.55 5,506.00 5,506.00 217.91 699.26 221.70 477.56 -18.20 82.95 3.154 Pass- 5,875.00 5,753.67 21.69 5,506.00 5,506.00 217.91 711.96 221.76 490.20 -18.24 82.91 3.210 Pass- 5,900.00 5,777.82 21.83 5,506.00 5,506.00 217.91 725.29 221.82 503.47 -18.27 82.87 3.270 Pass- 5,925.00 5,801.96 21.98 5,506.00 5,506.00 217.91 739.23 221.88 517.35 -18.31 82.83 .3.332 Pass- 5,950.00 5,826.10 22.12 5,506.00 5,506.00 217.91 753.74 221.94 531.80 -18.35 82.80 .3.396 Pass- 5,975.00 5,850.25 22.26 5,506.00 5,506.00 217.91 768.79 221.99 546.79 -18.38 82.76 3.463 Pass- 6,000.00 5,874.39 22.40 5,506.00 5,506.00 217.91 784.35 222.05 562.29 -18.42 82.72 3.532 Pass- . 6,025.00 5,898.53 22.54 5,506.00 5,506.00 217.91 800.38 222.11 578.27 -18.45 82.69 3.604 Pass- 6,050.00 5,922.68 22.68 5,506.00 5,506.00 217.91 816.87 222.17 594.70 -18.49 82.65 3.677 Pass- 6,075.00 5,946.82 22.83 5,506.00 5,506.00 217.91 833.78 222.23 611.55 -18.52 82.62 3.752 Pass- 6,100.00 5,970.96 22.97 5,506.00 5,506.00 217.91 851.09 222.28 628.80 -18.55 82.59 3.829 Pass- 6,125.00 5,995.11 23.11 5,506.00 5,506.00 217.91 868.77 222.34 646.43 -18.59 82.56 3.907 Pass- 02 March,2015-17:49 Page 20 of 28 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13.8 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.a Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 6,150.00 6,019.25 23.25 5,506.00 5,506.00 217.91 866.81 222.40 664.41 -18.62 82.52 3.987 Pass- 6,175.00 6,043.39 23.39 5,506.00 5,506.00 217.91 905.17 222.46 682.71 -18.65 82.49 4.069 Pass- 6,200.00 6,067.54 23.54 5,506.00 5,506.00 217.91 923.85 222.52 701.33 -18,68 82.46 4.152 Pass- 6,225.00 6,091.68 23.68 5,506.00 5,506.00 217.91 942.82 222.56 720.25 -18.71 82.43 4.236 Pass- 6,250.00 6,115.83 23.82 5,506.00 5,506.00 217.91 962.07 222.63 739.43 -18.74 82.40 4.321 Pass- 6,275.00 6,139.97 23.96 5,506.00 5,506.00 217.91 981.57 222.69 758.88 -18.77 82.37 4.408 Pass- 6,300.00 6,164.11 24.10 5,506.00 5,506.00 217.91 1,001.32 222.75 778.57 -18.80 82.34 4.495 Pass- 6,325.00 6,168.26 24.25 5,506.00 5,506.00 217.91 1,021.30 222.81 798.50 -18.83 82.32 4.584 Pass- 6,350.00 6,212.40 24.39 5,506.00 5,506.00 217.91 1,041.50 222.87 818.63 -18.85 8229 4.673 Pass- 6,375.00 6,236.54 24.53 5,506.00 5,506.00 217.91 1,061.90 222.93 838.98 -18.88 82.26 4.763 Pass- 6,400.00 6,260.69 24.67 5,506.00 5,506.00 217.91 1,082.50 222.98 859.51 -18.91 82.23 4.855 Pass- 6,425.00 6,264.63 24.79 5,506.00 5,506.00 217.91 1,103.27 223.01 860.26 -18.94 82.21 4.947 Pass- 6,450.00 6,308.97 24.90 5,506.00 5,506.00 217.91 1,124.22 223.04 901.18 -18.96 62.18 5.040 Pass- 6,475.00 6,333.12 25.01 5,506.00 5,506.00 217.91 1,145.33 223.07 922.26 -18.99 82.16 5.134 Pass- 6,500.00 6,357.26 25.13 5,506.00 5,506.00 217.91 1,166.60 223.10 943.50 -19.01 82.13 5.229 Pass- 6,525.00 6,381.40 25.21 5,506.00 5,506.00 217.91 1,188.01 222.95 965.06 -19.04 82.11 5.329 Pass- 02 March,2015-17:49 Page 21 of 28 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 11-17-KU 11-17 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Weil Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 16.00 18.00 0.00 18.14 18.14 0.00 225.59 1.07 224.51 -105.15 -105.15 210.261 Pass- 25.00 25.00 0.01 25.15 25.15 0.04 225.59 1.11 224.47 -105.15 -105.15 202.694 Pass- 50.00 50.00 0.04 50.17 50,17 0.15 225.59 126 224.33 -105.14 -105.14 179.608 Pass- 75.00 75.00 0.06 75.19 75.19 0.27 225.58 1.40 224.16 -105.11 -105.11 161.242 Pass- 100.00 100.00 0.09 100.21 100.21 0.38 225.57 1.54 224.03 -105.06 -105.06 146.297 Pass- 125.00 125.00 0.15 125.45 125.45 0.48 225.55 1.69 223.66 -105.00 -105.00 133.192 Pass- 150.00 150.00 0.20 150.70 150.70 0.57 225.51 1.85 223.66 -104.95 -104.95 . 122.225 Pass- 175.00 175.00 0.26 175.95 175.94 0.67 225.43 2.00 223.43 -104.90 -104.90 112.909 Pass- 200.00 200.00 0.32 201.18 201.17 0.76 225.33 2.15 223.18 -104.85 -104.85 104.948 Pass- 225,00 225.00 0.37 226.09 226.08 0.84 225.22 2.28 222.94 -104.80 -104.80 98.959 Pass- 250.00 250.00 0.43 250.99 250.99 0.91 225.12 2A0 222.71 -104.73 -104.73 93.616 Pass- 275.00 275.00 0.49 275.90 275.89 0.98 225.03 2.53 222.50 -104.64 -104.64 88.821 Pass- 300.00 300.00 0.54 300.84 300.82 1.05 224.95 2.66 222.29 -104.54 -104.54 84.517 Pass- 325.00 325.00 0.60 326,68 326.66 1.10 224.83 2.77 222.06 -104.44 -104.44 81.227 Pass- 350.00 350.00 0.65 352.52 352.50 1.15 224.61 2.87 221.74 -104.37 -104.37 78.147 Pass- 375.00 375.00 0.71 378.37 378.35 1.20 224.30 2.98 221.32 -104.34 -104.34 75.255 Pass- 400.00 400.00 0.77 404.07 404.05 1.26 223.90 3.09 220.81 -104.33 -104.33 72.345 Pass- 425.00 425.00 0.82 429.07 429.04 1.36 223.46 3.25 220.21 -104.33 -104.33 68.751 Pass- 450.00 450.00 0.88 454.06 454.03 1.46 223.03 3.41 219.62 -104.34 -104.34 65.485 Pass- 475.00 475.00 0.94 479.06 479,02 1.56 222.59 3.56 219.03 -104.34 -104.34 62.505 Pass- 500.00 500.00 0.99 504.71 504.67 1.66 222.15 3.71 218.44 -104.34 -104.34 59.825 Pass- 525.00 525.00 1.05 533.76 533.71 1.74 221.41 3.85 217.56 -104.32 -104.32 57.534 Pass- 550.00 550.00 1.10 562.76 562.67 1.82 220.22 3.98 21623 -10424 -104.24 55.285 Pass- 575.00 575.00 1.16 591.70 591.54 1.89 218.57 4.12 214.45 -104.12 -104.12 53.075 Pass- 600.00 600.00 1.22 619.80 619.55 2.01 216.50 4.28 212.21 -103.97 -103.97 50.545 Pass- 625.00 625.00 1.27 647.54 647.14 2.13 214.09 4A6 209.63 -103.60 -103.80 47.997 Pass- 650.00 650.00 1.33 675.20 674.63 225 211.36 4.64 206.72 -103.61 -103.61 45.576 Pass- 675.00 675.00 1.38 702.94 702.15 2.38 208.30 4.82 203.48 -103.41 -103.41 43.245 Pass- 700.00 700.00 1.44 732.09 731.00 2.53 204.79 5.02 199.77 -103.16 -103.16 40.807 Pass- 725.00 725.00 1.50 761.04 759.55 2.68 200.77 5.22 195.55 -102.87 -102.87 38.465 Pass- 750.00 750.00 1.55 789.77 787.79 2.84 196.22 5.42 190.80 -102.54 -102.54 36.212 Pass- 02 March,2015-17:49 Page 22 of 28 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 11-17-KU 11-17 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axisl2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 775.00 775.00 1.61 817.54 814.97 3.01 191.20 5.64 185.57 -102.16 -102.16 33.923 Pass- 800.00 800.00 1.67 844.71 841.46 3.19 185.82 5.86 179.96 -101.74 -101.74 31.693 Pass- 825.00 825.00 1.72 871.69 867.68 3.38 180.09 6.09 174.00 -101.25 -101.25 29.583 Pass- 850.00 850.00 1.78 898.46 893.59 3.57 174.01 6.31 167.70 -100.68 -100.68 27.582 Pass- 875.00 875.00 1.83 924.00 918.24 3.78 167.67 6.56 161.12 -100.06 -100.06 25.576 Pass- 900.00 900.00 1.89 949.36 942.65 4.00 161.16 6.80 154.36 -99.34 -99.34 23.698 Pass- 925.00 925.00 1.95 974.59 966.87 4.22 154.49 7.04 147.45 -98.52 -98.52 21.944 Pass- 950.00 950.00 2.00 999.68 990.90 4.44 147.66 7.27 140.39 -97.58 -97.58 20.300 Pass- 975.00 975.00 2.06 1,024.17 1,014.30 4.69 140.73 7.53 13320 -96.53 -96.53 18.698 Pass- 1,000.00 1,000.00 2.12 1,048.58 1,037.60 4.94 133.75 7.77 125.98 -95.37 -95.37 17.210 Pass- 1,025.00 1,025.00 2.17 1,072.93 1,060.81 5.19 126.73 8.01 118.72 -94.06 -94.06 15.828 Pass- 1,050.00 1,050.00 2.23 1,097.21 1,083.92 5.44 119.68 8.23 111.45 -92.58 -92.58 14.543 Pass- 1,075.00 1,075.00 2.28 1,122.25 1,107.70 5.73 112.55 8.48 104.07 -90.84 -90.84 13.279 Pass- 1,100.00 1,100.00 2.34 1,147.21 1,131.30 6.03 105.23 8.70 96.52 -88.82 -88.82 12.090 Pass- 1,125.00 1,125.00 2.40 1,171.95 1,154.61 6.33 97.75 8.90 88.85 -86.46 -86.46 10.981 Pass- 1,150.00 1,150.00 2.45 1,196.48 1,177.61 6.62 90.17 9.06 81.11 -83.68 -83.68 9.951 Pass- 1,175.00 1,175.00 2.51 1,220.51 1,200.05 6.96 82.58 9.20 73.38 -80.37 -80.37 8.973 Pass- 1,200.00 1,200.00 2.56 1,244.31 1,222.20 7.30 75.13 9.26 65.85 -76.33 -76.33 8.097 Pass- 1,225.00 1,225.00 2.62 1,267.93 1,244.10 7.64 67.95 926 58.69 -71.35 -71.35 7.336 Pass- 1,250.00 1,250.00 2.68 1,291.38 1,265.75 7.97 6125 9.14 52.11 -65.20 -65.20 6.702 Pass- 1,275.00 1,275.00 2.73 1,314.71 1,287.22 8.34 55.31 8.93 46.38 -57.60 -57.60 6.196 Pass- 1,300.00 1,300.00 2.79 1,337.88 1,308.43 8.73 50.48 8.69 41.80 -48.38 -48.38 5.811 Pass- 1,325.00 1,325.00 2.85 1,360.81 1,329.32 9.11 47.28 8.63 38.65 -37.64 -37.64 5.476 Pass- 1,348.71 1,348.71 2.90 1,382.36 1,348.85 9.48 4621 9.03 37.18 -26.51 -26.51 5.120 Pass- 1,350.00 1,350.00 2.90 1,383.52 1,349.90 9.50 4621 9.06 37.15 -25.89 -25.89 5.100 Pass- 1,375.00 1,375.00 2.96 1,406.06 1,370.23 9.89 47.58 10.02 37.57 -14.02 -14.02 4.751 Pass- 1,400.00 1,400.00 3.01 1,428.56 1,390.43 10.33 51.27 11.25 40.02 -2.91 -2.91 4.556 Pass- 1,425.00 1,425.00 3.07 1,450.86 1,410.35 10.76 56.92 12.49 44.43 6.77 6.77 4.557 Pass- 1,450.00 1,450.00 3.13 1,472.96 1,430.01 11.19 64.12 13.60 50.52 14.88 14.88 4.713 Pass- 1,475.00 1,475.00 3.18 1,494.65 1,449.39 11.61 72.51 14.57 57.94 21.56 21.56 4.976 Pass- 1,500.00 1,500.00 3.24 1,516.75 1,468.72 12.07 81.78 15.43 66.34 27.03 27.03 5299 Pass- 02 March,2015-17:49 Page 23 of 28 COMPASS IP • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 11-17-KU 11-17 Scan Range: 0.00 to 10,000.00.usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 1,525.00 1,525.00 327 1,538.70 1,488.08 12.53 91.65 16.08 75.57 31.45 31.45 5.700 Pass- 1,550.00 1,550.00 3.30 1,560.64 1,507.42 12.99 101.95 16.75 85.20 35.04 3504 6.087 Pass- 1,575.00 1575.00 3.32 1,582.56 1,526.76 13.45 112.57 17.37 95.19 37.97 37.97 6.480 Pass- 1,600.00 1,600.00 3.35 1,604.46 1,546.07 - 13.91 123.42 17.96 105.46 40.41 40.41 6.871 Pass- 1,625.00 1,625.00 3.36 1,626.25 1,565.25 14.39 134.46 18.52 115.95 42.46 42.46 7.261 Pass- 1,650.00 1,650.00 336 1,647.97 1,584.36 14.87 145.68 19.06 126.62 44.23 44.23 7.644 Pass- 1,675.00 1,675.00 3.36 1,669.64 1,603.39 1535 157.04 19.58 137.45 45.77 45.77 8.020 Pass- 1,700.00 1,700.00 337 1,691.24 1,62234 15.83 166.52 20.09 148.42 47.12 47.12 0,386 Pass- 1,725.00 1,725.00 3.38 1,712.89 1,641.31 16.32 180.11 20.62 159.49 46.32 48.32 8.735 Pass- 1,750.00 1,750.00 3.38 1,734.59 1,660.31 16.83 191.79 21.15 170.64 49.37 49.37 9.069 Pass- 1,775.00 1,775.00 339 1756.27 1,679.29 17.33 203.53 21.67 181.86 50.29 5029 9.392 Pass- 1,800.00 1,800.00 3.40 1,777.93 1,698.24 17.83 215.33 22.19 193.14 51.10 51.10 9.704 Pass- 1,825.00 1,825.00 3.41 1,800.00 1,717.55 18.35 227.19 22.72 204.47 51.83 51.83 10.000 Pass- 1,850.00 1,650.00 3.42 1,822.27 1,737.05 18.87 239.04 23.26 215.78 52.49 52.49 10.278 Pass- 1,875.00 1,875.00 3.43 1,845.07 1,757.04 19.41 250.84 23,81 227.03 53.11 53.11 10.536 Pass- 1,900.00 1,900.00 3.44 1,867.95 1,777.14 19.95 262.58 24.36 238.23 53.68 53.68 10.781 Pass- 1,925.00 1,925.00 3.46 1,890.91 1,797.34 20.49 274.26 24.91 249.35 5421 54.21 11.010 Pass- 1,950.00 1,950.00 3.47 1,91333 1,817.11 21.02 285.89 25.45 260.44 54.69 54.69 11.232 Pass- 1,975.00 1,975.00 3.49 1,935.36 1,836.53 21.54 297.53 25.99 271.54 55.12 55.12 11.448 Pass- 2,000.00 2,000.00 3.50 1,957.39 1,855.95 22.07 309.19 26.52 282.66 55.52 55.52 11.657 Pass- 2,025.00 2,025.00 3.52 1,979.35 1,675.31 22.59 320.98 12.03 308.96 -45.25 55.90 26.668 Pass- 2,050.00 2,049.99 3.53 2,000.00 1,893.51 23.09 333.06 11.93 321.12 -44.89 5625 27.906 Pass- 2,075.00 2,074.98 3.55 2,021.82 1,912.73 23.63 345.44 12.01 333.43 -44.51 56.63 28.773 Pass- 2,100.00 2,099.95 3.57 2,042.31 1,930.75 24.14 358.15 12.07 346.08 -44.16 5598 29.671 Pass- 2,125.00 2,124.91 3.59 2,062.57 1,948.55 24.64 371.18 12.14 359.05 -43.81 5733 30.587 Pass- 2,150.00 2,149.85 3.61 2,062.60 1,966.12 25.14 384.55 12.20 372.35 -43.47 57.68 31.529 Pass- 2,175.00 2,174.76 3.63 2,102.58 1,983.61 25.64 398.23 12.25 365.97 -43.13 58.02 32.496 Pass- 2,200.00 2,199.63 3.65 2,123.62 2,002.04 26.18 412.18 12.31 399,87 -42.78 58.37 33.477 Pass- 2,225.00 2,224.48 3.68 2,144.50 2,020.33 26.71 426.38 12.37 414.01 -42.43 58.71 34463 Pass- 2,250.00 2,249.29 3.70 2,165.22 2,03849 27.24 440.61 12.43 426.39 -42.09 59.05 35.470 Pass- 2,275.00 2,274.05 3.73 2,185.77 2,056.51 27.77 455.49 12.48 443.01 -41.76 59.38 36.499 Pass- 02 March,2015-17:49 Page 24 of 28 COMPASS I • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 11-17-KU 11-17 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 2,300.00 2,298.77 3.76 2,205.97 2,074.23 28.29 470.41 12.53 457.88 -41.43 59.71 37.546 Pass- 2,325.00 2,323.43 3.80 2,225.56 2,091.42 28.80 485.57 12.58 472.99 -41.12 60.03 38.586 Pass- 2,350.00 2,348.04 3.84 2,244.95 2,108.43 29.30 501.00 12.64 488.37 -40.81 60.34 39.645 Pass- 2,375.00 2,372.60 3.88 2,264.14 2,125.25 29.81 516.69 12.69 504.00 -40.50 60.64 40.723 Pass- 2,400.00 2,397.08 3.92 2,283.10 2,141.88 30.30 532.62 12.74 519.89 -40.21 60.94 41.820 Pass- 2,425.00 2,421.50 3.98 2,300.00 2,156.70 30.74 548.82 12.79 536.03 -39.93 61.22 42.911 Pass- 2,450.00 2,445.85 4.03 2,318.35 2,172.76 31.24 565.29 12.85 552.43 -39.64 61.50 43.984 Pass- 2,475.00 2,470.12 4.09 2,334.71 2,187.07 31.69 582.06 12.91 569.15 -39.37 61.77 45.080 Pass- 2,500.00 2,494.31 4.15 2,350.77 2,201.08 32.14 599.14 12.97 586.17 -39.10 62.04 46.196 Pass- 2,525.00 2,518.45 4.22 2,366.61 2,214.86 32.57 616.41 13.01 603.40 -38.84 62.30 47.388 Pass- 2,550.00 2,542.59 4.30 2,382.34 2,228.53 33.00 633.76 13.05 620.71 -38.59 62.56 48.579 Pass- 2,575.00 2,566.74 4.38 2,400.00 2,243.84 33.49 651.17 13.09 638.09 -38.34 62.80 49.761 Pass- 2,600.00 2,590.88 4.45 2,415.47 2,257.23 33.93 668.63 13.13 655.50 -38.11 63.03 50.924 Pass- 2,625.00 2,615.03 4.54 2,433.25 2,272.64 34.44 686.09 13.18 672.91 -37.89 63.26 52.048 Pass- 2,650.00 2,639.17 4.63 2,451.03 2,286.04 34.95 703.56 13.23 690.33 -37.67 63.48 53.159 Pass- 2,675.00 2,663.31 4.72 2,468.81 2,303.43 35.46 721.04 13.29 707.75 -37.46 63.68 54.259 Pass- 2,700.00 2,687.46 4.81 2,486.59 2,318.83 35.97 738.52 13.34 725.18 -37.26 63.89 55.348 Pass- 2,725.00 2,711.60 4.90 2,506.17 2,335.79 36.52 756.01 13.40 742.60 -37.06 64.08 56.397 Pass- 2,750.00 2,735.74 5.00 2,531.61 2,357.91 37.24 773.37 13.47 759.89 -36.86 64.28 57.394 Pass- 2,775.00 2,759.89 5.10 2,557.55 2,380.61 37.96 790.56 13.55 777.01 -36.67 64.47 58.349 Pass- 2,800.00 2,784.03 5.20 2,584.02 2,403.89 38.70 807.57 13.63 793.94 -36.50 64.64 59.262 Pass- 2,825.00 2,808.17 5.31 2,607.21 2,424.38 39.34 824.41 13.71 810.70 -36.35 64.80 60.148 Pass- 2,850.00 2,832.32 5.41 2,624.96 2,440.09 39.63 841.23 13.78 827.45 -36.20 64.94 61.060 Pass- 2,875.00 2,856.46 5.52 2,642.69 2,455.77 40.31 858.07 13.85 844.22 -36.07 65.07 61.962 Pass- 2,900.00 2,880.60 5.62 2,660.40 2,471A2 40.79 874.93 13.92 861.01 -35.94 65.21 62.855 Pass- 2,925.00 2,90475 5.74 2,678.08 2,487.04 41.27 891.81 14.00 877.81 -35.81 65.33 63.721 Pass- 2,950.00 2,926.89 5.85 2,695.73 2,502.63 41.76 908.70 14.07 894.63 -35.69 65.45 64.577 Pass- 2,975.00 2,953.03 5.96 2,714.49 2,519.19 42.27 925.60 14.15 911.45 -35.57 65.57 65.405 Pass- 3,000.00 2,977.18 6,07 2,733.63 2,536.10 42.81 942.49 14.23 928.26 -35.46 65.68 66.214 Pass- 3,025.00 3,001.32 6.19 2,752.79 2,553.04 43.34 959.37 14.32 945.05 -35.35 65.79 66.996 Pass- 3,05000 3,025.46 6.31 2,771.99 2,570.02 43.87 976.24 14.41 961.83 -35.25 65.90 67.766 Pass- 02 March,2015-17:49 Page 25 of 28 COMPASS • • Hilcorp Energy Company H ALLI B U RT©N Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 11-17-KU 11-17 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 3,075.00 3,049.61 6.42 2,791.22 2,587.03 44A0 993.09 14.49 978.60 -35.15 66.00 68.525 Pass- 3,100.00 3,073.75 6.54 2,809.33 2,603.05 44.91 1,009.94 14.58 995.36 -35.05 66.10 69.277 Pass- 3,125.00 3,097.89 6.66 2,826.46 2,618.20 45.40 1,026.80 14.67 1,012.14 -34.95 66.19 70.014 Pass- 3,150.00 3,122.04 6.78 2,843.54 2,633.30 45.88 1,043.69 14.75 1,028.94 -34.86 66.28 70.745 Pass- 3,175.00 3,146.18 6.91 2,860.59 2,648.35 46.36 1,060.61 14.84 1,045.77 -34.77 66.38 71.470 Pass- . 3,200.00 3,170.32 7.03 2,877.59 2,663.36 46.85 1,077.55 14.93 1,062.62 -34.68 66.47 72.190 Pass- 3,225.00 3,194.47 7.15 2,894.55 2,676.32 47.33 1,094.52 15.02 1,079.50 -34.59 66.55 72.892 Pass- 3,250.00 3,218.61 7.28 2,913.51 2,695.04 47.87 1,111.50 15.11 1,096.38 -34.50 66.64 73.549 Pass- . 3,275.00 3,242.75 7.40 2,933.49 2,712.67 48.45 1,128.45 15.21 1,11324 -34.41 66.73 74.179 Pass- 3,300.00 3,266.90 7.52 2,953.52 2,730.35 49.02 1,145.38 15.31 1,130.07 -34.33 66.82 74.799 Pass- 3,325.00 3,291.04 7.65 2,973.60 2,748.10 49.60 1,16229 15.42 1,146.87 -34.24 66.90 75.398 Pass- 3,350.00 3,315.19 7.78 2,993.73 2,765.90 50.18 1,179.17 15.52 1,163.65 -34.16 66.99 75.988 Pass- 3,375.00 3,339.33 7.90 3,012.67 2,782.67 50.73 1,196.03 15.62 1,180.41 -34.07 67.07 76.586 Pass- Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 18.00 1,500.00 KBU 31-18 WP4 MWD+SC+sag 1,500.00 6,500.00 KBU 31-18 WP4 MWD+SC+sag 6,500.00 10,000.00 KBU 31-18 WP4 MWD+SC+sag Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 02 March,2015-17:49 Page 26of28 COMPASS • • Hilcorp Energy Company HALL IBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Actual @ 84.86usft. Northing and Easting are relative to Plan:KBU 31-18. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00°,Grid Convergence at Surface is:-1.08°. Ladder Plot _ _if J OD �� t 1 tn 150 0 06, I I I o II I I I i J J J 0 „ I I LEGEND Q 100 L N 11., $KU 11-17,KU 11-17,KU 11-17 VO CJ) 1 49'KU 13-8,KU 13-8,KU13-8V0 2 J J J J J _ -9'KU 41-18,KU 41-18,KU 41-18 V0 KBU 31-1B WP4 'c'' ��III o 43- 0 50 a 2 I c � 1 a) J J J J J U 0 0 1500 3000 4500 6000 7500 Measured Depth(1500 usft/in) 02 March,2015-17:49 Page 27 of 28 COMPASS 0 • Hilcorp Energy Company HALL!BURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP4 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor 11.00 - — --.. _ (1 10.00--- _------- ----..._..- - - '--- ------ ----- I'-_-__- .._..--- -------- 9.00 -_ .. _.— --- ----- I ------ -- _�, _.. it 7.00--. .........-- --- .....- -- -- a 6.007.. I. m =.. LEGEND c 5.00----_--- — 1 r 11 II 1 --._— ---- ------ / - ----- - _,. $KU 11-17,KU 11-17,KU 11-17 VO -- e KU 13-8,KU 13-8,KU 13-8 VO n5 -- -_______/�__ _�. KU41-18,KU 41-18,KU41-18VO CD 4.00 ...----- -__.._._ t..._..-- --- -...--_ ------.. -_ - ...___ _._.__.. '8' _.. �.. V. i i 3.00— .... ------ -._._ --- - -- : i,,.. O vim v 200 Collision Avoidance Req r S -=-No-Go Zone-Stop Drilling \� 1 0 y 1 O O 1.00 i 1 0.00 Ili * 111 111111IiIIrIiII IIIIIIIIIIIIl IIIIIIjiiIII IIIIIIII IIIIII IIIII IIIIIIII 0 600 1200 1800 240013000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 Measued Depth(1500 usftlin) 02 March,2015-17:49 Page 28 of 28 COMPASS • • TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: 2-1- Oael V Development _Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: 4"/e--1,4Z-e, POOL: „od Check Box for Appropriate Letter I Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) 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 Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name)in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(dX2XB) 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 2/2015 • i 00 CV N _O N O c, 2, U, a) y, O Q N a>, 'al U, O. CO m -c 0, c Z. a0' a> a, N N, O _ O O Q O m p 3 n ay, v, . C L 00 co aNpcu a' ZN . EOo .. c a o oma, a> -a Z O' 3, a>, a> , L. , °, m , , , , , w, �, ' o CL c w m N. c 3, o, N, 0' � N 0 , , Y, O N, C, Cl) 0 , @ 3 Z a�� E C, L, , O, m Vm N, O, G, . 0, al 1 (n `. - C , 2, c, a, 5, ao, L, _ . OaN° 0, (3 j "� � (Cl �, N, �, E U -- ` 3 w -o c t cai > co 0 T E Oc, ? O, ' C, �, .N, .8 , , , , , 0 0, , ,p, , a, fay �� , 4 N, �, U. , -c, , j �% M, , (i > - �, o, O, , t p 3' .�' g' oo o m' ar a u rn o ° 3 f0 m3 o, i>,, „, C o N, 3, ~ , ao, E c, a>, aoo, aNaD uomaPooaa) o yr . , (1 C, ,a >) o' La o, , oa i•--. 0 N , nw' N 03 a No, ' c' L, i c I- >,. O , W O O a0 a. C , f'- ° _ U mNa a , y , O, o. N. O, E, C 7, N c. , V, wO, @, m E• _W 9 vma CO n0 , H'� � o 0m ' , o, D y 00, , , a' rn � 00 SI 0 c o X' y _ Qoi cri' 04 co' CL Gr' �Z 03 , U, A -0, N , , t, UYN, H, O, Ua) pM L, U d, VE, Oa N Cr) O N 6_ (Cl caD, 0 . O, - N. .3 -, a w O, =, '(, , V, O ', 'a>. 'C m, oi .. , 2, -a, , ao 3 'a a > N N m , o 4 3 . 4 0 oai ^ CO, ui ac E ° 3TaN, 3. a L (n , Z., , �, _0U' y,m , c, v � N > a , o, .N. C, CCo 7 O, o Q 7 C ' N �Z (7), �, , � , U @ -, •N. : O, c a. NCN >CG • N � � Q � w , Xo7 C7a> n > C3 N n RI NoxUU Nc Q w, op' o o Occo ' ED. 7' ' L0' _ I-' ' Ma, fpas' < . as, N' N. m' 2 8, U • CCe. 0 Y Y U o a' v)' i) 03 ir 0 M N' 2 . Z, _, S' d' a N' z a> O asC s . Wu w a 0 m < O, a>, a>, a>, a> a> a a>, a>. a>, as a> a>, a; a, <, <, -, a>, a>, 0, a>, a>, a> a, a), a, -, a>, a), a>, a> O a, -,, a>, <, <, < "/ o_ Z, Z, >- >- >- >-, >-, >-, >, >-, >- }, }. Z, Z, Z Z, } > > Z, >- >-, Z, >-. Z } }, >- >, Z, z >-, >-, Z, z z T \ o , E o, . U, U. a. a' O. C. . . . Yl 0 (.0 , . ' a>, 3 E' , . . . . , a) . . c, 0 (Cl: . �� a) co' y, V, . a' 0 'C, W �O, f9 �� 7 �•- Ti„ O' .d «), 4=, e C, O, `` Ya 3c, >a) .p., N , MN O NcN (O°, , 3, (4 > aE. N. 4 o n-. , , U, N, , aC O, � , . , 'a , a, ' 4 O -3aD , ,,- 0mo > 70 a 0 a Ea . ' M, p ' y, 0' c ' -J ' _' Lc> ' ' 2Zc , a ' 0 .' , cm i N rn , a ' c , of'Fs v , , D ' o 0 .c ' 0)'''T*)c , as, a) M, . , c, N > , c (-7 0_, „ o' .cEE _, vc E - OcF2ded Ct ' L ' a n> a . OE CCCU pN13, C. u)<, C• 00, U .m ..0a). 0, ":0;, .�, ON' Q , ' YZ a)•N L p88OO 7 7 - 'O (° � � YcO 0ZO E, EN L , >. oW U Ea �, _ a o Oc -, C , a 0 o3p _ cEJ .sd > c, c, , N, O, . _,, _c, L (°, ,co3 N, -0, ,, `, .E ), , N, :t-', , co O , O a , , , .- a J (°, c -0, :° :° N, a aO, -0, , -o. E, a), N ' ' yNa) NN ' �oC ' w o• '8 .� CO � a u , '�' NV , �' m' ai oa v. o. N. • � 0- o -p .ma>>. �a>, oo. .0 �, . p 3. �o, o py N � a Q 00 0 . o L ZoY , o NN �� , oaON0, O' N, E,, c. O, O, o o c N `p, co, 'a, E , 0. ELO) c, v, m w' 0. Cd M -0, , a ' :o �' ' ' a. CV Ca . g > 'd O O Ca' Vm EaY Na> No EU . .... c 0 a a, m m a N, N, a a , 0 _ ap 'c Cy-O aU. 0, E E, p ° N .y, .N, (° . .C, , c al 03 (° ' >T -O Z, •H O, O. • Et. a 2,, N , .C, m m N ' a> O 3 .O � c c O 0 N C C (, . [2 p 0 �, O ya) > ," NU d- (Cl, C, -o, -o, -O U, -Nc, W a, L. -p, _ a), y . '0,, 0 >, .� , L. a L ' (0 a, • U - c (Cl, C' ENa) N � O, , p, L, C c . a3O. C ` N O 0 o (ClN _ a -0 O (° C oO /is c a> c. p'ONEm , - , ma> E -' ' = 0 o0a> ao' as a = aa �' (O' c, 0, (Cl CO (Cl c> c1- 0 rmE3 (>. p m $1 `6 o 0 (> ,, c> 6 v' > TN > >, v, ''7-' -s-.' o. E , .0o, 2, -,n J aO, O O o .ON, Oo, ONpg , 3 O ?, s', •CO Wq7, a -§' 0' , a .E �• U 6J _ ....E,' , .c a, m a, U > a), C, 0m z-, 3, a p' vcN' , ' ' uC, O. N, op.' ._5,' ca 0W, YL,, o, mNL, € (Cl .O, m, Nc, ma) aaa � o; o2 � 2 - (° a 0, 03 o ma, �, D, 5, 55, (n, - ooa, a, U aa, z, 0 (n000, U, a, a, - o, mmo, s, - 2' a0 (ncnU W m E ,- N co V (n co N a0 as O .- Nr- M .V- (n .(-0 N. CO .0-) O N.- N M N N N h N N c.9 M N M M (0 (O N- W 0) Co co Co o') (-,') 0 N U to Loa) Ce V O CV (° (6 N W CV oU) N 0 Q7 rn 0 0 0 a) O N H a. L a"+ •[ M co O J N •N a) m C7 E J E a 0 c a (n o a o (� W a E m (L o> 0. _ o m IL I n. a a U) w a 0 0 a w ti of T� S )//j/. 'sv THE STATE Alaska Oil and Gas o'l iLl s K1 Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 oFALASP Fax: 907.276.7542 www.aogcc.alaska.gov Monty M. Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Beluga/Upper Tyonek Gas Pool, KBU 31-18 Hilcorp Alaska, LLC Permit No: 215-024 Surface Location: 409' FEL, 702' FNL, SEC. 18, T4N, R11 W, SM, AK Bottomhole Location: 398' FNL, 2471' FWL, SEC. 18, T4N, R11 W, SM,AK Dear Mr. Myers: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this -2-Sday of February, 2015. RECEIVED STATE OF ALASKA AIA OIL AND GAS CONSERVATION COMMON FEB 0 4 2015 PERMIT TO DRILL 20 20 AAC 25.005A �' la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone Q. 1c.Specify if well is proposed for: Drill • Q Lateral ❑ Stratigraphic Test ❑ Development-Gas Q • Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑ Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. ,,,,02235244 Kenai Beluga Unit(KBU)31-18 • eS l..2.C3 JAS 2.V'! /lb Z-�`•/s-. 3.Address: 6.Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive,Suite 1400 Anchorage AK 99503 MD: 10,000' • TVD: 9,683' • Kenai Gas Field 4a. Location of Well(Governmental Section): 7. Propertignation(Lease Number):/{ jam Beluga/Upper Tyonek Gas Pool • Surface: 409'FEL,702'FNL,Sec 18,T4N,R11W,SM,AK ' Unit Trac ee Lease A028/12) ZZ.3 O Tyonek Gas Pool 1 Top of Productive Horizon: 8.Land Use Permit: „/" f,p/s-- 13.Approximate Spud Date: 777'FNL, 1439'FEL,Sec 18,T4N,R11W,SM,AK N/A 3/15/2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 398'FNL,2471'FWL,Sec 18,T4N,R11W,SM,AK 2494.04 acres 5,100' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 85 ft • 15.Distance to Nearest Well Open Surface: x-275397 • y- 2356031 • Zone-4 GL Elevation above MSL: 67 ft - to Same Pool: 1,234' 16.Deviated wells: Kickoff depth: 2,000 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 19 degrees Downhole: 4300 psi • Surface: 3332 psi • 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) 13-1/2" 10-3/4" 45.5 L-80 Buttress 1,500' Surf Surf 1,500' • 1,500' • 929 ft3 9-7/8" 7-5/8" 29.7 L-80 BTC 6,100' Surf Surf 6,100' • 5,900' . 858 ft3 6-3/4" 5" 18 L-80 DWC 10,000' Surf Surf 10,000' • 9,683' • 730 ft3 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): Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch Q Drilling Prograrn0 Time v.Depth Plot Q Shallow Hazard Analysis Diverter Sketch ❑✓ Seabed Reports Drilling Fluid Program Q 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Monty M Myers Email mmyers(@hilcorp.com Printed Name /(/) 0 k,x,.I,•1. M Pk kr•c- ,r.) Title Drilling Engineer Signature e\ '1 Phone 907-777-8431 Date 2 - 3 • 1 0 ' S `��\ Commission Use Only ' Permit to Drill �• , API Number. / ��/ r Permit Approval r See cover letter for other Number: ��/�� 50-/•D ��r[�`r!- Date: ,--J� G� requirements. Conditions of approval: If box is checked ell may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Other: it 35to ,pSu /jot oto 4,,,,(— Samples req'd: Yes[1] No�' Mud log req'd:Yes❑ Nov❑' ir / •� 2S..;3 -H2 [✓] S measures: Yes❑ No ' Directional svy req'd:Yes[+/ No❑ U�r � �' 49 L `11kip)ting exception req'd: Yes❑ NoEf Inclination-only svy req'd:Yes❑ Noa C * /44 17 -A re.,.....,zQ 1 St E•G g�3,- C'�m" lam . c)P. r..- 'e :. APPROVED BY Approved by: ...- / COMMISSIONER THE COMMISSIONp ` Date: 2 ) Z s/ ),s' c r 7 - is Submit Form and Form 10-401(Revised 10/2012) QsIrrlitG,jicI)Ijcljiis from the d of appfova (20 C 25.005(g)) Att encs in Duplicate • Monty Myers nC�1 C \/ Hilcorp Alaska, LLC Drilling Engineer C�j/G y 3800 Centerpoint Drive Suite 1400 FEB 0 4 2015 Tel Anchorage, 99503 ell 907 777 843 flilrnrp.11a.k,.LEA; Email mmyers@hilcorp.com AOGCC 2/3/2015 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Permit to Drill KBU (Kenai Beluga Unit) 31-18 Dear Commissioner, • Enclosed for review and approval is the application for the Permit to Drill the KBU 31-18 Development gas well. KBU 31-18 is a 10,000' MD / 9,683' TVD Beluga/Upper Tyonek development well off the 41-18 pad in the Kenai Gas Field. Reservoir analysis and subsurface mapping has identified an undrained —200 acre area of the Tyonek D-3B sand and an 80 acre area LB/UT in the southwestern flank of the KGF structure. The reserves for this particular LB/UT location are booked; however, the primary objective (Tyonek D-3B) is not booked and could have significant reserves/rate potential Drilling operations are expected to commence approximately March 15th, 2015. The Saxon Rig# 169 will be used to drill and complete the wellbore. A separate 10-403 sundry will be submitted prior to completion operations. The 10-401 PTD covers all operations up to running and cementing the 5" long string. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 i • Hilcorp Alaska, LLC Kenai Beluga Unit KBU 31-18 Drilling Program Kenai Field Revision 0 Jan 30th, 2015 • • KBU 31-18 Drilling Procedure Hikorp Alaska,LLC Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program: 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 N/U 16-3/4" Conductor Riser 11 11.0 Drill 13-1/2"Hole Section 12 12.0 Run 10-3/4" Surface Casing 16 13.0 Cement 10-3/4" Surface Casing 18 14.0 BOP N/U and Test 21 15.0 Drill 9-7/8"Hole Section 22 16.0 Run 7-5/8"Production Casing 28 17.0 Cement 7-5/8" Cement Procedure 30 18.0 Drill 6-3/4" Hole Section 33 19.0 Run 5" Production Long String 39 20.0 Cement 5"Production Long String 42 21.0 RDMO 44 22.0 Perf and Frac 44 23.0 BOP Schematic 45 24.0 Wellhead Schematic 46 25.0 Days Vs Depth 47 26.0 Formation Tops 48 27.0 Anticipated Drilling Hazards 49 28.0 Saxon Rig 169 Layout 52 29.0 FIT Procedure 53 30.0 Choke Manifold Schematic 54 31.0 Casing Design Information 55 32.0 9-7/8"Hole Section MASP 56 33.0 6-3/4"Hole Section MASP 57 34.0 Spider Plot(NAD 27)(Governmental Sections) 58 35.0 Surface Plat(As Staked)(NAD 27) 59 36.0 Offset MW vs TVD Chart 60 37.0 Drill Pipe Information 61 • • KBU 31-18 Drilling Procedure Hilcor')Alaska,I.LC 1.0 Well Summary Well Kenai Beluga Unit(KBU)31-18 ' Pad&Old Well Designation KBU 31-18 is a grass roots well on the existing 41-18 pad • Planned Completion Type 5"production tubing Target Reservoir(s) Tyonek/Beluga • Planned Well TD, MD/TVD 10,000' MD/9,683' TVD • PBTD, MD/TVD 9,900' MD/9,589' TVD Surface Location(Governmental) 409' FEL, 702' FNL, Sec 18, T4N, R11 W, SM,AK • Surface Location(NAD 27) X=275397,Y=2356031 • Surface Location(NAD 83) Top of Productive Horizon 777'FNL, 1439'FEL, Sec 18, T4N, R11 W, SM,AK (Governmental) TPH Location(NAD 27) X=274411.52,Y=2355852.84 TPH Location(NAD 83) BHL(Governmental) 398'FNL, 2471'FWL, Sec 18, T4N, R11 W, SM,AK • BHL(NAD 27) X=273353.79, Y=2356251.29 BHL(NAD 83) Maximum Anticipated Pressure in 4300 psig psig(Downhole) Maximum Anticipated Pressure in 3332 psig psig(Surface) AFE Number 1510327 AFE Drilling Days 27 AFE Completion Days AFE Drilling Amount $4.6MM AFE Completion Amount Work String 4-1/2" 16.6# S-135 CDS-40 (Rental Saxon String) KB Elevation above MSL 85.0 ft GL Elevation above MSL 67.0 ft BOP Equipment 11" 5M T3-Energy Annular BOP 11" 5M T3-Energy Double Ram 11" 5M T3-Energy Single Ram Page 2 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure !Wore 2.0 Management of Change Information Hilcorp Alaska, LLC Mew"«• .Lit Changes to Approved Permit to Drill Date: 1-30-2015 Subject: Changes to Approved Permit to Drill for KBU 31-18 File#: KBU 31-18 Drilling Program Any modifications to KBU 31-18 Drillin Program will be documented and approved below. Changes to an approved APD will be corGni;;3d'e the BLM and/AOGCC. `�J i"e,..`c<i L•. i� c1 i Gt,liC.-C l'—)!:1J 7� ( Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Revision 0 Jan, 2015 • ! KBU 31-18 Drilling Procedure Hilrorp 1lnvkn,1,1.1 3.0 Tubular Program: Hole OD (in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension Section (in) OD (in) (#/ft) (psi) (psi) (k-lbs) Cond 16" 15" - - 109 X-56 Weld 13-1/2" 10-3/4" 9.95" 9.875" 11.75" 45.5 L-80 BTC5210 2480 1040 9-7/8" 7-5/8" 6.875" 6.75" _ 8.5" 29.7 L-80 BTC 6890 4790 683 6-3/4" 5" 4.276" 4.151" 5.563" 18 L-80 DWC/C 9910 10500 422 HT 4.0 Drill Pipe Information: Hole OD (in) ID (in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension Section (in) (in) (#/ft) (psi) (psi) (k-lbs) All 4.5" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 Jan, 2015 I • KBU 31-18 Drilling Procedure Hi!carp Alaska,III 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com; mmyersahilcorp.com, lkeller@hilcorp.com, &cdinger@hilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting • Notify EHS field coordinator. 1. Matt Hogge: 0: 777-8418 C: 907-227-9829 2. Spills: Julieanna Orczewska: 0:907-777-8444 • Notify Drlg Manager&Drlg Engineer: 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 2. Luke Keller: 0: 907-777-8395 C: 832-247-3785 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final"As-Run"Casing tally to lkeller@hilcorp.com, mmyers@hilcorp.com& cdinger@hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to lkeller(aihilcorp.com, mmyers@hilcorp.com &cdinger@hilcorp.com Page 5 Revision 0 Jan, 2015 • 0 II KBU 31-18 Drilling Procedure LI Ieorp Aln.I.,LLC 6.0 Planned Wellbore Schematic CASING DETAIL Size Type Wt Grade Conn. Top "etm 16"41Conductor- 1l'"- Mt 16" Driven to Set 109 X-56 Weld 16" Surf 130' it:; Depth I,:,,,„ ,ill 10-3/4" Surf.Csg 45.5 L-80 Buttress 9.95" Surf 1500' 10-314. 7-5JS" Intermediate 29 L-80 BTC 6.875" Surf 6,100' la )1 TUBING TOC=3000' ,. r 5" Production 18 L-80 DWC/C HT 4.276" Surf 10,000' F i1 e• � gry Hole Section Casing Pv11"+ WQC StTW.g 13-1/2" 10-3/4" 8.6—9.3 ppg 4-1/2" 9-7/8" 7-5/8" 9—9.5 ppg 4-1J2" 6-3/4" 5" 10—11 ppg 4-1/2" . ' JEWELRY DETAIL ." ,o Depth ID ODen-. 1 18' 4.276` 11" Tubing Hanger 2 5,600' 4.276" 6.875' 10ftSwell Packer(Water Swell) r 'a3tq EXPECTED FLUID, TVD(PT) ;Esq Pressure 7-58" ` (pi 00 rdhrlg , g2 3.887 3,980 _ 250 • fling 5.2 ' "" '"" ° gaslwet ;. 4,249 4.243 1500 l ' iit Sterling Pool 6 gas 4,539 4,532 200 UpperBeiuga gas 4,800 4.778 900 Middle Beluga gas 5,479 5417 -1000, ii... I Lower Beluga' gas 6.255 6,146 '1000 ' w, Upper yoek a g.,--. 7,468 7.286 ,2500 Tyonek D? i 9 051 8.773 2000 , Tyonek t2 •, 9.244 8,995 1000 Tyorrek D3B g 9,534 9,227 2700 Tyonek Det 9.703 9.386 ,,,,,a,,,,,,1700 PBTD=9,900'MD 9.589'TVD TD=10,000'MD 9.633'TVD , Page 6 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure Hileorp Alnskn,LLC 7.0 Drilling / Completion Summary KBU 31-18 is a 10,000' MD/9,683' TVD Beluga/Upper Tyonek development well off the 41-18 pad in the Kenai Gas Field. Reservoir analysis and subsurface mapping has identified an undrained—200 acre area of the Tyonek D-3B sand and an 80 acre area LB/UT in the southwestern flank of the KGF structure. The reserves for this particular LB/UT location are booked,however,the primary objective (Tyonek D-3B) is not booked and could have significant reserves/rate potential. The base plan is a directional wellbore with a kick off point at 2000' MD. Maximum hole angle will be 19 deg. Vertical section will be 2055 ft. Drilling operations are expected to commence approximately March 15th , 2015. • The Saxon Rig # 169 will be used to drill and complete the wellbore. The well will be perforated after the rig has departed. The closest industrial water well to the drill wells on pad 41-18 in the Kenai Gas Field is the Kenai B-4. The hole depth is 100' with the water level at 96', and the chlorides are around 1200 ppm. Arsenic levels came in at 11.8 parts per billion,which is over the EPA limit for the naturally occurring substance. Total gas levels from offset mud logs begin to register at depths as shallow as 175'. The closest domestic water well is the Kenai B-4 KS01, located on the eastern flank of the field,which draws its water from a depth of 268' and has chlorides around 2000 ppm. Casing for the drill wells will be placed well below the fresh water table at 1500' to isolate any useable ground water. Surface casing will be run to 1500' MD and cemented to surface to ensure protection of these resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 — 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field . G&I facility for disposal /beneficial reuse depending on test results. This facility is on the same pad as the drill well. General sequence of operations: 1. MOB Saxon Rig# 169 to well site. 2. N/U 16" diverter riser (No diverter, diverter waiver requested) 3. Drill 13-1/2"hole to 1500' MD. Run and cmt 10-3/4" surface casing. 4. N/D conductor riser,N/U &test 11"x 5M T3-Energy BOP. 5. Drill 9-7/8"hole section to 6,100' MD. Run and cmt 7-5/8" intermediate casing. 6. Drill (and LWD log) 6-3/4"production hole section to well TD. Run and cmt 5"production casing. 7. N/D BOP,N/U tree, RDMO. Page 7 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure Hilmrp Alaska,1,11, Reservoir Data Acquisition Program: 13-1/2" Surface hole: Mud logging only, no LWD 9-7/8" Intermediate Hole: Mud logging + GR/Res LWD 6-3/4" Production Hole: Mud logging+ GR/Res /Den/Neu LWD 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at(2) week intervals during the drilling and completion of KBU 31-18. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 5/5 min(annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: • Diverter waiver request requested due to the recent drilling of KBU 32-08 and KBU 43-07Y on the k' same pad. No issues were experienced on either well drilling the surface hole. Surface casing will be set at the same depth on KBU 31-18. aAeirilrb Page 8 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure in,or!,Alaska,LLC Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 13-1/2" • No diverter Installed N/A • 11"x 5M T3-Energy(Model 7082)Annular BOP • 11"x 5M T3-Energy Double Ram Initial Test:250/3500 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 9-7/8"&6-3/4" • 11"x 5M T-3 Energy Single Ram • 3-1/8"5M Choke Line Subsequent Tests: • 2-1/16"x 5M Kill line 250/3500 • 3-1/8"x 2-1/16"5M Choke manifold (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon(12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event(BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email:guy.schwartz@alaska.gov Victoria Ferguson/Petroleum Engineer/(0): 907-793-1247/Email: Victoria.ferguson@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov_ Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236(During normal Business Hours) Notification/Emergency Phone: 907-659-2714(Outside normal Business Hours) Page 9 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure Hilrhrp Alaska,LLC 9.0 R/U and Preparatory Work 9.1 Set 16" conductor at a minimum of 111' below ground level. This is required to isolate a problematic gravel bed that occurs from 90— 105'. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 16-3/4" 3M "A" section & 20" adapter bushing. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Saxon Rig# 169, spot service company shacks, spot& R/U company man&toolpusher offices. 9.7 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.8 Mix mud for 13-1/2" hole section. 9.9 Set test plug in wellhead prior to N/U conductor riser to ensure nothing is accidentally dropped into the wellbore. 9.10 R/U mud loggers for surface hole section. • 9.11 Install 5-1/2" liners in mud pumps. • TSM 1000 mud pumps are rated at 3633 psi (85%)/ 333 gpm (100%) with 5-1/2" liners. Page 10 Revision 0 Jan, 2015 • • II KBU 31-18 Drilling Procedure Hitnarp Alnskn,GLC 10.0 N/U 16-3/4" Conductor Riser 10.1 N/U 16-3/4" Conductor Riser • Ensure line does not direct flow from trip tank straight down the flowline. Fill up line and flowline should be oriented 90 degrees to each other at approx. the same height. • Ensure flowline outlet installed so that enough slope exists to carry cuttings to the shakers. • Consider adding additional drainage points at the bottom of the conductor riser if deemed necessary. • R/U fill up line to conductor riser. 10.2 Set 15.375" ID wear bushing in wellhead. 10.3 Rig Orientation on 41-18 Pad: \ n ____ — --1 z• IOW 211.., .s. NORTH 4 :?, z 230471,7°. *i 2)Sfi2M•799 2 , l )-- L L(NTS) Z % \ ,. tom of Ate') UJ 7.1 fr' " 1.w!�. ----t_.--- , a #,w./ l tr 3 dT 4 A = 0. •'''< . 40 `)RFACE LOCATION k.......?2:1.— A.„=„01 , fu,..„1,,,,„„ Z4 x.'909 A 16 209 �` LAT:.' • 5,9981N LON.151'14'37.39M ,r r "' ELEV:66.662'(MSL) MOVIIC rtLV425'FEL . r4Cy T E5 it 557 FNL • I KEN PAD S-18IELD D 4.....%. OF �1.ti:OF A..,QSI ft ..,�Q: - GRIND A tH,JECT DUtiOtet, ./. / € ; f OASIS OF COONSSAiAYE815 U S C b G S NO STATION AWRY N A$.P. / ,i_/ / ZONE 4{NAD 27)AVERAGE CO poem OK POMOAN.OT'Y5I 40 ./ZJE* / _______1Y2 2 AU DRT GEODETIC POSmON PER NOS / / LAT:N2'*ESO%ON LONG 151'twat 445•'4N ♦ . M. SCOTT MCLANE; .► x•264,Ste TS Y.2.5&1.04S 42 ,I .• Ti OASTS a<VERTICAL tu+TUM IS MEAN SSA LEVEL.(LOCAL WW1 oe `' 4928—S • 4d NORTHEAST CORNER SEC ISCOORDRMTES DETERMINED FROU ONTO "B;a p� �� ;at SURVEY TIE TO THE TO FASTING SLR SECTION CORNER RECOVERED ANO IIS T •mess..... � `►` ° • SCALE ' NOT THE;MIX/RAC/ED YEACTEa ISCTXN CORNER VALUES. I1.. ..11` I rrrr I Page 11 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure Ht(rnrp Alaska,(.(.0 11.0 Drill 13-1/2" Hole Section 11.1 P/U below 13-1/2" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Bit TFA should be-0.7 in2. We need to pump at 500 to 510 gpm to clean the hole effectively. • Workstring will be 4.5" 16.6# S-135 CDS40. COMPONENT11111111111111 00 ':, , ` # Desa Sweat Number (ant lirt 016 Ilbpf) Mil HDBS OHGIGRC 13.450 300D 13.500 46D 12 P 5-5,8'REG 1.00 1 O 0 8'SperryDNI Lobe 45-5.3 stg 1111111111M 8.003 5.200 121.08 I:=1Gy:t I 31.83 3283 _ Stabliizsr _®_ EMI 6"Drec0onsl COPar 7.850 3.500 _ 147.40 B 6•5B"REG 8.88 41.71 • 4'Hum st80dimrgps)1218'9au9s 6.000 2 830 _ 14987 86.518RFG 340 4551 ® 8'TM HOC(Pulsery 8.150 4 000 _ 145.20 135-5r REG 940 54.91 Km 8'Non Mag Flex Colter 7.803 _KNEE]B&5B'REG 30.90. 84.91 8'Non Mag Flex Collar 7.670 mom KmiKm 8 5-56'REG 30.93 114.91 Km X.0 6-576'Reg P X4-1/7 IF B 1111111111111111111Kmmom Km Ego 8 4-t12`1F 2.25 117.16 • 6.75'Non Mag Flex Calor 8.730 2 875 _ 99.11 B 44/2'1F 30.00 147.16 t0 6:75'Non Mag Flee Color 6.703 3000 ® 96.06 B 4-1 T If 3003 177.'16 ® X•0 4.172`IF P X CDS-40 B 8.522 2.75D _ 1 B 4.5"CDS 40 2.75 179:91 ® 6Jurlts4-172'HWOPCOS-40 4.503 2.750 _ 41.00 185.00 36451 • X-0 CDS-44 P X 4 12.'IF 11111111111111 6.520 2.750 _ +X1.54 LESSIMINEEMI 367.86 KM 6114'Weatherford DAH Jar 6.250 2 250 _ 91,01 B 4-tt2'IF 3200 39866 ® X-0 4-1.7 IF P X CDS-40 B 6.520 2.750 MIN EMI 6 45'CDS-40®MUM ® 13 Joints 4.112'HWDP COS.40 4.502 2 750 _ 41.00 400.00 402.41 TOR! 802.41 BIT DATA 8$Number • Nwslea :1,14 306 Sit Size (ln1 : 13.520 TPA (ln2) :0.7394 Hanufactuno :HOBS Dull Owed.In Model ;CHCIGRC Dull Grade Out Serial Number MOTOR DATA Motor Number Bend (dog) 1.15 00(In) :8.003 Nettles (32nd) 0.0 Manufacturer :Sporn)Drl6rg Avg Din Press Model :SperryDral Cutout Ck Hrs twist Number 11.2 Hydraulics Summary: Depth- Hole Size Pump Rate Standpipe Est Openhole MW ECD TFA MD (ft) (in) (gpm) Pressure (psi) AV(fpm) (ppg) (ppg) (in2) BHA MM + MWD+25 0- 1500 13-1/2" 500 1848 76 9.0 9.2 0.70 HWDP Page 12 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure Hilearp Alaska,LLC 11.3 Primary bit will be the Security 13-1/2" QHC1GRC Milled Tooth Bit. These are available from Halliburton. 13-1/2" (343mm) QHC 1 GRC pRoDucT SPECIFICATIONS i ADC Co& 117W Total Tooth Count 64 (awe Row Tooth Count 36 • Journal Angle 33 1 Offset(1116") Jet Nor&Types Standard 83244 F.aterided 311306 Center Jet (If Center Jetted)501813 Ti.Connection 6-5ill"(API Reg.i Recommended Make‘Up Torque2860012600 flit Weight tBoxed1 260 Lbs.(118 Kg.1 flit Weaker (Matirlegacya) 110/77i644914 • PROD'.CT FEATURES • Neve patented Diantundm Claw*tooth bit design.. - • Proptietary Diamond TE011201800"full tooth hardfacing on cutting structure and gage. "11110° • Tungsten carbide'surf inserts in gage teeth for added gage • protection, • Premium bearin and seal configuration suitable for both rotary and motor applications. • Innovative mechanical pressure compensattng system provides reliable pressure e.quali2ation and relief for maximum bearing and seal hfe. • Raked tungsten carbide inserts and moprkiary bardfacing provides maximum arm protection in abrasive and directional applkations while minimizing drill string torque. • QuadPackt Plus Series,iticorporaicsit tirecessfill'longevity" features and patented engineered hydraulics system for optimal cleaning efficiimey. • Center jet feature to prevent bit balling problems Material#540030 1.CAleulatinoi bawd on ructnnnientlatiom from API ami tool-ioiml manufarturnrs. 02014 Hal liburton.All rights reserved.Saks of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.halliburtonicom Page 13 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure Hilrorp Alaska,GLC 11.4 4-1/2" Workstring&HWDP will come from Saxon. Jars will come from Weatherford. 11.5 No LWD tools will be run on the 13-1/2"hole section. 11.6 Begin drilling out from 16" conductor at reduced flow rates to avoid broaching the conductor. 11.7 Drill 13-1/2"hole section to 1500' MD/ 1500' TVD. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 510 gpm. This gives us an annular velocity of 77 fpm, which is borderline for effective hole cleaning. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep API fluid loss < 10. • TD the hole section in a good shale btwn 1450' & 1550' MD. • Take MWD surveys every stand drilled(60' intervals) . Page 14 Revision 0 Jan,2015 • • KBU 31-18 Drilling Procedure Hilcorp Alaska,IAA 11.8 13-1/2" hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system(1)ppg above highest anticipated MW. We will start with a simple gel+FW spud mud at 8.8 ppg. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 8.8—9.3 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density iscosity Plastic Viscosity Yield Point API FL LGS 80-1500' -()Density 9.3• 85-250 20-40 25-45 <10 <15% System Formulation: AQUAGEL/freshwater Spud Mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 15 -20 ppb caustic soda 0.1 ppb(8.5—9.0 pH) BARAZAN D+ as needed BAROID 41 as required for 8.8—9.3 ppg PAC-L/DEXTRID LT if required for<10 FL ALDACIDE G 0.1 ppb 11.9 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. 11.10 TOH with the drilling assy, handle BHA as appropriate. Page 15 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure HiIrorp Aln.&a,1.LC 12.0 Run 10-3/4" Surface Casing 12.1 R/U and pull 15.375"wearbushing. 12.2 R/U Weatherford 10-3/4" casing running equipment. • Ensure 10-3/4" BTC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill-up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor& model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on (thread locked). • (1) Joint with coupling thread locked. • (1) Joint with float collar bucked on pin end &thread locked. • Install (2) centralizers on shoe joint over a stop collar. 10' from each end. • Install (1) centralizer, mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 10-3/4" surface casing • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. Estimated torque to reach base of triangle: 10,750 ft-lbs. • After making up several connections, use the torque required to M/U to base of triangle as the M/U torque and continue running string. • Install (1) centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 10-3/4" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 10-3/4" 10,750 ft-lbs Page 16 Revision 0 Jan, 2015 • KBU 31-18 Drilling Procedure Hilwrp Alaska,i,LC __ T maria Casing and Tubing Performance Data Choose pipe size,wall thickness and steel grade to view API connection options and performance data. Size • t",+all w�..,. Grade 12 Connection Unit Pipe Body Data GEOMETRY • Nominal OD 10.750 in Wall Thickness 0.400 in API Drift Diameter 9.794 in Nominal Weight 45.50 ibs'ft Nominal ID 9.950 in Alternate Drift Diameter 9.875 in Plain End Weight 44.26 lbs/ft Nominal Cross Section 13.006 sq in PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Body Yield Strength 1,040,000 lbs Internal Yield Pressure 5,210 psi Collapse Pressure 2,470 psi 4 I© Connection Data GEOMETRY Regular OD 11.750 in Threads Per Inch 5 Make-Up Thread Tums 1 PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Joint Strength 1,063,000 lbs Internal Pressure 5,210 psi Resistance TenarisHydril Premium Connections Print Contact Us Ver 8.6 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. Page 17 Revision 0 Jan, 2015 • KBU 31-18 Drilling Procedure Hilt-nip Alaska,LLC 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. 13.0 Cement 10-3/4" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 13.2 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.3 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.4 Pump remaining 35 bbls 10 ppg spacer. 13.5 Drop bottom plug. Mix and pump cmt per below recipe. 13.6 Cement volume based on annular volume+ 50% open hole excess. Job will consist of lead& tail, TOC brought to surface. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) LEAD: 80' x .106 bpf= 8.5 47.8 16" Conductor x 10-3/4" casing annulus: LEAD: (1000' — 80') x .065 bpf x 1.5 = 89.7 504 13-1/2" OH x 10-3/4" Casing annulus: Total LEAD: 98.2 552 TAIL: (1500'-1000') x .065 bpf x 1.5 = 58.5 328 13-1/2" OH x 10-3/4" Casing annulus: TAIL: 90 x .096 bpf = 8.7 48.8 10-3/4" Shoe track: Total TAIL: 67.2 . 376.8 Page 18 Revision 0 Jan,2015 s ! S KBU 31-18 Drilling Procedure Hilcorp Alaska,LLC Cement Slurry Design: Lead Slurry (1000' MD to surface) Tail Slurry (1500' to 1000' MD) System Blend Conventional Density 12 lb/gal 15.2 lb/gal Yield 2.44ft3/sk ✓ 1.26 ft3/sk / Mixed Water 14.437 gal/sk 5.76 gal/sk Mixed Fluid 14.417 gal/sk 5.76 gal/sk Expected 5 HR 3 HR Thickening Code Description Concentration Code Description Concentration D901 Cement 94 lb/sk D901 Cement 94 lb/sk D046 Antifoam 0.2%BWOC D046 Antifoam 0.2%BWOC D020 Extender 2.6% BWOC D065 Dispersant 0.4% BWOC Additives D079 Extender 2% BWOC D167 Fluid Loss 0.2% BWOC D110 Retarder 0.02 gal/sk cmt S002 Accelerator 0.25% BWOC 13.7 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.8 After pumping cement, drop top plug and displace cement with mud. 13.9 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. Be lined up to displace with rig pumps as well, in the event there is an issue during the displacement with the rig pumps. 13.10 Displacement calculation: • Iti344 1411' x .0962 bpf= 135.7 bbls 13.11 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.12 Do not overdisplace by more than V2 shoe track volume. Total volume in shoe track is 8.7 bbls. Page 19 Revision 0 Jan, 2015 I i KBU 31-18 Drilling Procedure Harare Alaska,LLC 13.13 Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 6— 18 hours after CIP. 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: • Pre flush type,volume(bbls) &weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to lkeller(,hilcorp.corn, mmyers@hilcorp.corn & cdinger@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 20 Revision 0 Jan, 2015 • KBU 31-18 Drilling Procedure Hilrorp Alaska,LLC 14.0 BOP N/U and Test 14.1 N/D the conductor riser. 14.2 N/U Seaboard multibowl wellhead assy. Install packoff 10-3/4" P-seals. Test to 3000 psi. 14.3 N/U 11" x 5M T3-Energy BOP as follows: • BOP configuration from Top down: 11"x 5M T3-Energy annular BOP/11"x 5M T3-Energy Model 6011i double ram/11"x 5M mud cross/11"x 5M T3-Energy Model 6011i single ram • Double ram should be dressed with 2-7/8 x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5" VBRs • N/U bell nipple, install flowline. • Install (1) manual valves & (1) HCR on kill side of mud cross. Manual valve used as inside or"master valve". • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. n 14.4 Run 4-1/2" BOP test assy, land out test plug (if not installed previously). -b • Test BOP to 250/3500 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. � X • Ensure to leave "B' section side outlet valves open during B5testing so pressure does not Gf build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9 ppg 6% KCl/EZ MUD/BDF-499 drilling fluid for 9-7/8" hole section. 14.8 Set 10" ID wearbushing in wellhead. 14.9 Ensure mud loggers are R/U for the intermediate hole section. 14.10 Rack back as much 4-1/2" DP in derrick as possible to be used while drilling the hole section. 14.11 Install 5" liners in mud pumps. • TSM 1000 mud pumps are rated at 4250 psi (85%) /275 gpm (100%) with 5" liners. Page 21 Revision 0 Jan, 2015 0 • 14 KBU 31-18 Drilling Procedure Hil.rp Alaska,LLC Ir k c42-Ql.) 15.0 Drill 9-7/8" Hole Section �� --- 15.1 Prior to P/U 9-7/8" directional BHA-test casing against blind rams to 2600 psi/ 30 min. 15.2 P/U below 9-7/8" directional drilling assembly. 561. 1.? 'L Ye- „�. G• 13./s- . length Crarmuiattt+a 1 HOBS M465 POC Bit 6.000 2.500 9.675 79.63 P 4-112'BEG 0.90 0.90 2 r Sp+srryD61I Law 77B-8.0 stg 7.000 4.952 993.13 8 4-192'IF 27.10 27.90 St691 4er 9.628 3 63,'4"Non Mag FIoa t Sob 6.500 2.875 90.96 8 4-112'IF 2.45 30.35 4 6 304"Integral t aie 9 5t$'gouge 6.770 2.875 9.625 100.55 8 4-1x2"IF 7.00 37.35 , 5 6 314"DM Coder 6.690 3.125 103.40~ 8 4-112"IF 925 4660 8 6 34"€WR•P4 Collet / 6.720 2,000 104.30 B 4-tr2'1F 14.00 80.60 7 6 314`DGR Collar ✓ 6.780 1920 97.80 P 4-112"IF 840 6900 8 Inline Stabilizer AILS} 6.750 3.125 9.750 96.82 B 4-112`IF 3.50 72.50 9 6 314'PWD Collar 7 8.730 19305 9.9.30 8 4.172`IF 5 00 77.50 10 6 3'4`99C114 Coast 6.540 1.920 101.70 8 4-112"IF 7.00 84.50 11 8 314'TM Coiter 6.890 3.250 103,60 8 4.1T IF 9.80 94.30 12 6-3/4"Son Mag Flax Collar 6:750 2 810 10082 B 4-1x2`IF 3100 125 30 13 6-3344 hon Meg Flex Collar 6.750 2.810 103.82B 4-112`IF 31. 0 156.30 14 6-3+4"Son Mag Flax Colter 6.750 2.610 100 82` e 4-1f2'IF 3000 166:30 15 6-3.44"N sn Meg Flex Colter 6.750 21310 10082 8 4-112"IF 30:00 216.30 16 X.04.117 IF P X CDS,40 B 6.520 2.750 93.54 84.5"CDS 40 2.75 219.05 17 6 Janes 4-ire FIVY00COS-40 4.500 2.687 36.86 186.00 404 05 18 X'O CDS-40PX41rT IF 6.520 2.750 g3.54 84.1f2"IF 275 406:80 19 4-04"Wrsatherford Hyd Jra6.260 2250 91.01 8 4-1174 IF 32.31 43911 20 X-4 4-1,7 9F P X CDS-40 B 6.520 2.760 93.54 B 4.5"CDS-40 2,.75 441.86 21 13 Joints 4.112'H'.YDP C135-40 4.500 2.687 36.85 400.00 84116 Totau 641.86 BiT DATA Bit Number Nozzles :6x13 Bit Size fln) ; 9.875 TPA 46►2) :0.7777 114arer1acfiaar : HOBS Dull Grads lin :NEW Model ; 1,16465 Dull Grade Out Serial Number . 15.3 Ensure BHA components have been inspected previously. 15.4 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. Page 22 Revision 0 Jan,2015 I ii II KBU 31-18 Drilling Procedure Hileorp Alaska,LLC 15.5 Bit TFA should be—0.75 —0.80 in2. We need to pump at—450 - 500 gpm to clean the hole effectively. Have the directional driller run hydraulics calculations to confirm optimum TFA. 15.6 Primary bit will be the Security 9-7/8" MM65. 9-7/8" (251mm) MM65 PRODUCT SPECIFICATIONS Cutter Type SeleetCutter ,..... - !ADC Code M323 Body Type MATRIX Total Cutter Count 46 04044? Cutter Distribution Jlouxt lam 4 -A. race (1 26 a Gauge 12 0 Up Drill 6 0 Number of Large Nozzles 6 NUInkt of Medium Nozzles 4 Number of Small Nozzles it Number of Micro Nozzles 0 NillitIVT of Pods(Sift) ft Number of Replaceable Ports(Size) 0 Junk Slot Area isu in) 16.71 , Nctrmaltzeti Face'Volume 0,44% m, API Connection 4-1,2 REG PIN Recorruncialed Make-Up Torque* 12.461-17,766 Ft*lbs. Nominal Dinscnsions** Make-Up Face to Nose 10.41 in-275 nun (iauge Length 25,u.,64 man Sleeve Length 0 in-n mm Shank Diameter 6 in-152 nun lireak Out Plate tfv1aLdrlegacykl) 161954444140 Approximate Shipping Weight 250Lbs.-113Kg. SPECIAL FEATURES Up-Drill Cutters on Ceage Pada,1116"Relieved Gage Material#771827 Ntlit specific reentranended makeup torque is a benction attic bit C.D.and actual bit sub O.D.utilized as specified in API RP7C Sectiun A.S.2. **Design dtmensanns are nominal and way vary%tinkly em manufactured reettlil.liallihurron Drill Ibis and SerVilM4 models are onnunumuly sevasysed and refirea Product specifications may chnnw without notice. 02013 Hallibunon.All rights reserved.Sates of Halliburtan products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.hatlibwloo.com Page 23 Revision 0 Jan, 2015 • 111 KBU 31-18 Drilling Procedure ihlenri/Alaska,LLC 15.7 9-7/8"hole section hydraulic summary: Security DBS BIT HYDRAULIC PROGRAM 0 Prepared For-Hike/9 KaU 32.05 gy:-Mark 9rouldet Pate prepared:-1*11 Operator.;,1111cbrp I Well Nanieeri°-NW 32403 1 Bit Type:- PDC - Contractor aCounty:-Reiter ) Bit Diameter:- 9.875 fe. SutvaytAbshaet-# 1 StatePCountry_•AKIUSA _4 MD Out 6400 ft Mud Wreigall 64 ppg ...COMPONENTS 10(In,)! to(tt). 1 13 PY 22cp }Casing 995; 1500:- 2 4 YP M 1b1l001tr Open Hole 9.575 6400 3 1:i Fluid Model P1,1•w'-Os+ 'W' '+tea it • : 4 13 Row Rate« 1900::917915 11; Max.Pump Press.; _.._400mil 6 1.> Surface equip:.: 7 Motor bypass? 6 TVDak 5455 n 9 0 ofNnzsle(10).4 !t lita ua Cautatie . 10 Min.TFA! 0.3631 in° Drill Strtngl. 1286.30 psi 47.62% Total TFII 0.7777 inz : AmarikeS1 78.10 psi 2.89% Jet Velocity'. 296.37¶i Surface! 77.46 psi 2.88% Press.Drop: 361.62 psi : Speaker 900.00 psi 33.27 1 Ea Hyd.Power 105.49 hp Shi:: 361.02 psi 13.31% H.5,1, •3773 hplln Impact Force 507.37 1Sf ECO TofaIISPP 2700.48 •.i 100.00% I 00 10 Tool Joint Length Cap Pressure Loss DRILL STRING COMPONENTS In, In OD I03 II bbls .y Drill Pipe(S)(CDS 40 Connections ! 4.8 3.926 6,375 3.5 5_50. 78.65 593.35 14WOP(CDS 40 connections.13 3141 4.8 2.65 6.25 2.55. •403 2.89 199.60 Weatherford Hyd Jar ICOS 404 6 2.25 8 2 25 31 0.15 32.50 HINDP(CDS 40 connections,5 Jts) 4.5 2.65 6.25 2.55 196 1.29 92,12 0-0 Sub ICOS 40 Bos S 4-112"II Pin) 6.5 2.75 6.5 2 79 4 9.03 1..76 4 Joints 6.314"NM flex Drill Collars 6.75 2..913 6.75 2.011 120 0.42: 47.85 Intagral BladhStabilizet 19.75`Gauge) I 6.75 2.75 6.75 2.155 9 0.04 230 MWDTM HOC(Pulserl 6.75 "s"s»..".« 875 f11111114'-' 16 450.00 MWD RCM Collar 6.75 1.42 6.75 1.42 5 0,01 38.46 ,MWD-PWD C*114r 6,75 1,42 5,75 1,42 5 0.01 38,46 MIND EWRP4 I Gamma Collar 6.75 1.42 6.75 1.42 22 0.04 169,24 MND Directional Collar 6.75 1.42 6.75 1.42 9 0.02 69.23 Integral BladeStabilizer19.75"Gauge) 3 6.75 2.75 6.75 2.15. 5 0.04 2.20 Float Sub 6.75 2.75 875 275 3'f 0.02 1.32 7-SperryDrtil Lobe 716.5.0 51g. 7 ....'" 7 •., 78! ....• 450.00 i ANNULAR Hole lO Pp 00.. Cum.. Casa. Annular; Critical Type o4 Pressure Less SECTIONS, in.: in. Depth bbls torn n, fumes Flew' p*.! Casing 9.95' 4.50 1500 1500 114.75 155.61' 303.43' L 16.62 Open Hole 9.875 4.5! 4058 5558 304.59 158.61 305.05 L 46.43 Open Hole' 9.8791 4.5; 402 5961 30.25 159.61 305.05. L 4.61 Open Hole 9.815s 6.25,, 31 5992 1.76 200.66 354.731 L 077 Open Mole 9.8751 4.51 166 6176 13.96 158..61; 305.05 L 2.13 Open Hnle. 9.6751 6.53 4 6162 6.21 221.18 364.58 L 0.11 Open 14010 9.8751 5.751 120 6302 8.06 235.69:: 37549 I. 4.00 Open Hole 9,675: 6.731 5 6307 0.25 235:89: 37549 I„ 0.17 Open Hole 9575! 6.75€ 16 6323 0.51 735.59;. 37549 1.. 0.53 Open Hole 9.8751 6.75; 5 6328 0.25 235.891 37549 L 0.17 Open Hole 9.8751 6751 5 6333 0.25 235:59, 375.49 L 0.17 Open Hale 9.8751 5.751 22 6355 1.11 235.69`'. 37549 L 073 Open Hole 9.8751 6.751 9 6364 0.45 235.89' 375.49 L 0.30 Open dale 9.8751 6.751. 5 6369 0.25 235.89, 375.49 L 0.17 Open Hole 9.875: 6.751 S 6372 0.15 235.89 375.49 L 0.10 Opan Hole 9.875: 7' 28 6400 1.32 252.60 387.67 L 1.10 Page 24 Revision 0 Jan,2015 • • KBU 31-18 Drilling Procedure HHrntp Ala.ka,u.0 15.8 9-7/8"hole section mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1)ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0—9.5 ppg 6%KC1/PHPA fresh water based drilling fluid. Properties: MD Mud Plastic Viscosity Yield Point pH HPHT / Weight Viscosity 1,500'- 9.0—9.5 40-53 15-25 15-25 8.5-9.5 < 11.0 6,000' System Formulation: 6% KCL/EZ MUD/BDF-499 Product Concentration Water 0.905 bbl KCl 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) BDF-499 4 ppb EZ MUD DP 0.75 ppb(initially 0.25 ppb) DEXTRID LT 1-2 ppb PAC-L 1 ppb BARACARB 5/25/50 5—10 ppb(3.3 ppb of each) BAROTROL PLUS 2—4 ppb SOLTEX 2—4 ppb BAROID 41 as required for a 9.0—9.5 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) Page 25 Revision 0 Jan,2015 I 14KBU 31-18 Drilling Procedure flileorp Alaska,LI.0 15.9 TIH, Conduct shallow hole test of MWD and confirm Gamma Ray LWD functioning properly. 15.10 Continue in hole and tag TOC. Note depth tagged on AM report. 15.11 Drill out plugs and shoe track. Clean out rat hole and drill an additional 20' of new formation. 15.12 CBU and condition mud for FIT. 15.13 Conduct FI to 12 ppg EMW. 15.14 Drill 9-7/8"hole section to 6,100' MD/ 5,900' TVD. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. If tight hole is encountered, screw in and begin backreaming connections until hole conditions improve. Shales in the Beluga formations are notorious for swelling and causing tight hole. Most of the time, backreaming them on a short trip is the only solution. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 11. • Take MWD surveys every other stand drld. Surveys can be taken more frequently if deemed necessary. • Ensure to pre-treat the active system with 10 ppg Calcium carbonate. Have additional fibrous and other bridging material on location in the event lost returns is encountered. There are many stacked sands that are severely depleted that will be penetrated in the 9-7/8"hole section. Page 26 Revision 0 Jan,2015 • 14KBU 31-18 Drilling Procedure Hilrorp Alaska,LLC 15.15 Casing Point selection • KBU 41-18X is the closest offset to use for correlation to pick casing point. Below is the annotated GR+ gas +resistivity log. • We want to set the 7-5/8" shoe 10 - 20' into the MB3CC. KBU 41-18X 4 K•U 11-is% ,.. 11111 �j -7,151 _. .<.7 K. li 111114 (/' KUK 1 MO 41.111)111111 nr Kw 02 ?.182': -7,242 IL • 4:11111111111111KU 11-06 11"• I rTa"wwwrrr�iniall 11.111111111 1I1 • 1411111111114151 riuu.•uu .r r • :`11114. 159111111111 :lit ,. iii - 9r. 7-5/8"Casing Pont in M id Beluga �i �- 3CC shalefrom 5945'-5984'ND F!L "� � lir r ,. � 21111111111111111 j. .<< ..Glsaa , � fiQ.rtFillil g g ' rtsing . Wlii:EEBki li tLEllin L; rill!!!11 X11 °: 1lI••••Io 1.: Page 27 Revision 0 Jan, 2015 • 14KBU 31-18 Drilling Procedure Hilrorp Alaska,LLC 15.16 At TD; pump sweeps, CBU, and pull a wiper trip back to the 10-3/4" shoe. 15.17 TOH with the drilling assy, handle BHA as appropriate. 16.0 Run 7-5/8" Production Casing 16.1 R/U and pull 10" ID wear bushing. Install and test 7-5/8" casing ram in top ram cavity. Test to 250/35si. 16.2 R/U Weatherford 7-5/8" casing running equipment. • $Ensure 7-5/8" BTC x CDS-40 XO on rig floor and M/U to FOSV. ✓ • R/U fill up line to fill casing while running. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 16.3 P/U 7-5/8" 29.7# L-80 BTC shoe joint, visually verify no debris inside joint. 16.4 Continue M/U &thread locking the shoe track assy consisting of: • (1) Float shoe joint w/float shoe bucked on. Install (2) bow spring centralizers at 10' from each end over a stop collar. • (1) Baker locked joint. Install (1) centralizer mid tube over a stop collar. • (1) Float collar joint w/float collar bucked on pin end. Install (1) centralizer mid tube over a stop collar. • Ensure proper operation of float shoe and float collar. 16.5 Run 7-5/8" 29.7# L-80 BTC casing. • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Install centralizers over couplings on every other joint to 1550' MD. 16.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.7 Slow in and out of slips. 16.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe approx 10—20' above TD. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. Page 28 Revision 0 Jan,2015 I • KBU 31-18 Drilling Procedure Hileorp Alaska,LLC Casing and Tubing Performance Data PIPE BODY DATA GEOMETRY Outside Diameter 7.625 in Wall Thickness 0.375 in API Drift Diameter 6.750 in Nominal Weight 29.70 lbs/ft Nominal ID 6.875 in Alternative Drift Diameter n.a. Plain End Weight 29.06 lbs/ft Nominal cross section 8.541 in PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Tension Yield 683,000 in Internal Pressure Yield 6,890 psi Collapse Pressure 4,790 psi Available Seamless Yea Available Welded No CONNECTION DATA TYPE:BTC GEOMETRY Coupling Reg OD 8.500 in Threads per in 5 Thread turns make up 1 PERFORMANCE Steel Grade L80 Coupling Min Yield 80,000 psi Coupling Min Ultimate 95,000 psi Joint Strength 721,000 lbs Internal Pressure Resistance 6,890 psi 7-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 7-5/8" 7,630 ft-lbs 16.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 16.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat(slightly)to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 16.11 Continue circulating until required properties achieved for cmt operations. 16.12 After circulating, lower string and land hanger in wellhead again. Page 29 Revision 0 Jan, 2015 • • 14KBU 31-18 Drilling Procedure H,lrarp Alaska,LLC 17.0 Cement 7-5/8" Cement Procedure 17.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 17.2 R/U cmt head (if not already done so). Ensure top and bottom plugs are loaded correctly. 17.3 Pump 5 bbls 10 ppg spacer. Close low torque on plug dropping head, test surface cmt lines to 4000 psi. 17.4 Pump remaining 35 bbls 10 ppg spacer and drop bottom plug. 17.5 Mix and pump slurry per below calculations: Section: Calculation: Vol (BBLS) Vol (ft3) LEAD: 9-7/8" OH x 7-5/8" csg: (5,600'- 3,000') x .038 bpf x 1.25 = 124 700 Total Lead: 124 bbls 700 ft3 3t`1 5X TAIL: 500' x .038 bpf x 1.25 = 24 135 9-7/8" OH x 7-5/8" csg: TAIL: 90' x .046 bpf= 4.1 23 7-5/8" Shoe Track: Total Tail: 28.1 bbls 158 ft3 /Z .‹"A Page 30 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure Hilrorp Alaska,LLC Slurry Information Lead Tail System LiteCRETE Conventional Density 11 lb/gal 15.2 lb/gal Yield 1.92 ft3/sk • 1.26 ft3/sk Mixed Water 6.794 gal/sk 5.76 gal/sk Mixed Fluid 6.834 gal/sk 5.76 gal/sk Expected 5:02 HR:MIN 3 HR Thickening Code Description Concentration Code Description Concentration D-046 Antifoam 0.2% BWOB D901 Cement 94 lb/sk D-065 Dispersant 0.35% BWOB D046 Bonding Agent 10% BWOC Additives D167 Fluid Loss 0.25% BWOB D065 Anti-Static 0.005 lbs/sk D177 Retarder 0.04%gal/sk D167 Anti Foam 1 gal/100 sks S002 Retarder 0.4% BWOC 17.7 After pumping cement, drop flexible shut-off plug and displace cement with mud. Use the cement unit to displace with as volumes can be tracked much more accurately. Displacement calcs: • 6,000' x .0459 bpf=276 bbls. • Displace with 10 ppg 6% KC1/Kla-Guard drilling fluid out of mud pits. 17.8 Monitor returns closely while displacing cement. Adjust pump rate if necessary. 17.9 Do not overdisplace by more than 1/2 shoe track volume. Total volume in shoe track is 4.1 bbls 17.10 There should be no cmt returns to surface. TOC is planned to be at 3000' MD. 17.11 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. • If this is the case, monitor the pressure on the casing and do not let it exceed 500 psi over the final pump pressure. Page 31 Revision 0 Jan, 2015 i • KBU 31-18 Drilling Procedure iiikorp:klaska.LLC Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally& casing and cement report to lkeller(a hilcorp.corn, mmyers@hilcorp.corn & cdinger@hilcorp.corn. This will be included with the EOW documentation that goes to the AOGCC. 17.1 R/D cement equipment. Flush out wellhead with FW. 17.2 Back out and L/D landing joint, flush out wellhead with FW. 17.3 M/U pack-off running tool and pack-off to bottom of landing joint. Set casing hanger pack-off. Run in lock downs and inject plastic packing element. Test void to 250/3000 psi for 10 min. 17.4 Lay down landing joint and pack-off running tool. Page 32 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure Hilmrp Aln%kn,LLC 18.0 Drill 6-3/4" Hole Section 18.1 Remove 7-5/8" casing rams from BOP. Install 2-7/8" x 5" VBRs in top cavity. BOP configuration should be (from top down): Annular/VBR/Blind/Mud cross/VBR. 18.2 Test BOPs on 4-1/2" and 5"test joints. 18.3 R/U Mud loggers for the 6-3/4"production hole section. They need to be set up to generate mud log, pixler plots, and collect(3) sets of samples every 20 ft. 18.4Pull test plug, run and set wear bushing. vvi8.5 Run CBL on 7-5/8"casing only if cement job did not go according to plan and TOC is in question. 18.6 Ensure BHA Components have been inspected previously. Rack enough 4-1/2"DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. 18.7 Drift& caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 18.8 Ensure TF offset is measured accurately and entered correctly into the MWD software. 18.9 Confirm that the bit is dressed with a TFA of 0.46 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 270 gpm. Page 33 Revision 0 Jan, 2015 0 • KBU 31-18 Drilling Procedure HiIvory"11maca,LLC 18.10 P/U below 6-3/4" directional drilling assy: COMPONENT DATA immumimiiii_ 41101111111114 item '..., ODl'w eight ...>,. „ ti Length "Cumulative, ri crip tton Snri;il NU ' Connection lint } (Ib ) lftl Length Ott Ell HOBS EM65D POG frit IIIIIIIIIII 4.500 1.563 6.750 47.67 075 0.75 Ea 5"SperryDrill Lobe 6.7-6..0 stg aIIIMNII 5.000 3.120 _ 48.00 Nil S1atx,7er b .: I lEll Final,Suet IMIIIMIIIIIIOEM 2.25) MUM=. 11 3-'.2"If 2,25 ® wowed Matt Stabilizer 4.840 2.003 6 .3in 52 00 B 3-112"IF 5.00 32.00 ® 4 314'DM Collar 4.730 1.253 47.00 a 3-"'3"IF 9.20 41.20 11111 4 3,'4'"Slim Phase 4 Collar 4.750 7.2x3 ® 48.20 2 3-'.2'IF 24.50 65.70 ® Inline Stabilizer I;I LS) 4.140 1.920 6.000 50.27 B 3-1..2"IF 3.50 69.20 1101 4 3,"4"ALIJ Collar / 4 77) 1,250 5,t?5 45 511 0.3.1,++2""1l" 14.O0 63,20 _ Sl;ibdex!er 5 r 25 ® 4 2,.'4"GTN Collar - 4.755 1.250 50 50 B 3-1'2"IF 11.30 94.20 10 4 3"'4"PNC 4.75"3 1.250 "47.90 111=1 9.20 103.40 111111 4 314"TM HOC(Putser) 4.'750 1.253 40.90 B 3-1!2„IF 11.00 114.40 ® 4:€,.4"BAT Collor IIMIIIIIIIIIIIIIIIII 4.750 125 45 7n 13 NC:38 ME=III=al L 75"Flux Collar 4.7 0' 2.253 46 04 B 3-112"IF 31 03 171 02 ® 4.75"Flex Collar ;� 4.750 2.250 40 04 B 3-1..2"IF 31.00 202.82 15 X-0 3-1x2"IF Pin X 4-1..2 CDS-10 Box 3 250 2.2 5:1 I30.2�? B 4.5'CD5-40', 2.73 205.57 E'' 6 Jooants 4-1?H'NJDP 4.500 2.750 +11.00 185.130 390.57 17 X•F)4 14"CDS-40 Pin X 3 1,7 II finx ,- 5 301:3 2.250 _® 0 3.1"7"1F 2 75 393 32 - 4 314"Weatherford Myd Jar s 2"250 11111111 l t3 3-1r2"1F 30.00 423 32 E x-O 3-1,+2"IF Pin X 4-1,2"CDS-40 Box - 5.3C . 2.753 54 94 ',B 4 5'CDS-40', 2.75 426 07 20 13 Joints 4-1!2"HWDP 4.500 2.750 ® 41.00 403.O0 826.07 �"` " ; 826.01 BIT DATA Bit Number . Nozzles :6x10 Bit Size ling : 6.750 TFA (In2) : 0.4602 Manufacturer : HOBS Dull Grade In . Model ; E6165D Dull Grade Out Serial Number . 18.11 Hydraulics Summary: Page 34 Revision 0 Jan, 2015 ` • • II KBU 31-18 Drilling Procedure Hilrorp AIa.La,LLC SecurityBIT HYDRAULIC PROGRAM ,---"", �E Prepared For-Hitcoep KSU 32.09 By-Mark Brouinel 0ele prepared;-1141111 Operator 1llcorp Well Nionlai No-10J 3248 1 Bit Type: PDC Contractor: County-Ket 4 nBit Diameter 6.75 i Sawa,;lAbetrect:- Slatetcountry.-AK11.03A 1 MO Out• .._._.9350 9 Mud WeepM i"O >pp4 COMPONENTS 10(in.l To Ib) 1 10 PV 12:cp 6.8751 8490 2 11. YP ; ;IS11bf10C1ki n Hole 675 9350 3 14 Fluid Model Paeoruw -water lased Ra •J 1 4 10 Row Rohl .�gpew ..... _ 5 in Max,Pump Pres6.�-. 4000 i 6 1t, Surface equip.?2 e 1 7 Motor aypassl 8 TVD? . 7153 ft 9 0 of Nozzle ma),6 6,6661. Caiadaban a 10 Min.TFA1 0.1974 Ing Drill String, 873.90 psi 35.40% Total TFA 0 4802 int Annulus, 369 97 psi 14.99% Jet Velocity 191.82 PL's Sarface, 29.19 psi 1.18 S Press.Drop 345.31 psi Special`; 850-00 psi 34.44 4 Etat Hyd.Power 55.40 hp Hit --'-'..3I psi 13.99% H.S./. ...,17 hp'int Impact Force 286.69 I11 ECD 11.41 ppg Tota1'SPPj 24613.37 psi 100.00% 00 1f} Tool Joint i'. LIniPh Cap, Pressure Los* DRILL STRING COMPONENTS i ht. in. OD 101 11 bb's psi Drill Pipe(S1 I CDS 40 Connections I 4.3 3.826 6.375 3.5`• 8517.5 120.53 319.99 NNWDP(CDS 40 connections.13 Jos) 4.8 2.68 615 2.55 ;`` 483 2.80 68.47 4-3'4'Weatherford Hyd Jar we X-O's 5 2.25 5 2.25"I, 35 0.17 12.43 IOWIPICDS40connections,6-RN 4.5 2.88 6.25 2,55 186 1.29 31.60 X-0 Sub(COS 10 Bos 0 3-1,2"iF Pin) 4,7 2,5 5 2.3 41 0,02 0 92 2 Joints NM Fins Oral Cellars 475 2.5 4.75 2.5 84i 0.38 13.61 MWDIBstSonic 4.75 1.25 4.769.25 2.6 0.04 112.92 PSWDdTM HOC(Pulsar) 4.75 """""""' 4.75 •"""'• 11 """.."-«„ 400.00 NIWDIPWD 4.75 1.25 4.75 1.25 ;: 9 0.01 39.05 MWD FALO-CTNRlukesl 4,75 1,25 4.75 1.25„„�, 351 0.04 105.45 'MineStabiliser PLS 6'Gaugml 4.75 1,25 4.75 1/5 . 3.5± 0.01 15,19 MWD,DireclsonaltSlnn Phase 4 4.78 1.25 4.75 125s 341 0.05 147.54 NM Siring Stabilizer)6.625Gau;pel 4.78 2 4.75 2:.° 5.5' 0.02 3.23 Float.Sub 4.75 2.5 4,75 2.5 2.511 0.02 0.57 5'Sperry0r21 Lobe 6,7.6.0 sigitw'ABli 5 ••..""..." 5 """"" 284 •...",'1-- 450.00 ANNULAR!. Hole ID.j, Nee 00 1.e11901 Cum.. Cap. Annular= Critical Type of Pressure Lose SECTIONS, in., in. It Depth, bbls ?Lenin, 7arnlin Flow pat Casing 6.875 4-5 6400 6400 167.96 249:49; 310.59 L 242,12 Open Hole 6.75 4,.5 2117.5 8517.5 52-07 266.28; 916.12, L 89.68 Open Hole 6.75 4.5 403 8920.51 9.91 260.28_ 31.6.12 L 17.07 Open Hole 0.75 4,7 25 9955.5E 0-80 267.161. 325.86 L 1..77 Open Hole 6.75 4.5 196 9141.5 4-57 266-281 316.12 L 7.84 Open Hole 6.75:, 1.7 4 9145.5 0.09 297.16¢ 325.96 L 0.20 Open Hole 6.75 4.25# 60 9205.5 1.34 29303. 328.50 L 3.19 Open Hole 6.75 4.75 26 9231.51 0.58 293 051 328.50 t 1.34 Open Hole 6 75 4,751 11 9242,5' 0 25 293 051 328.50 1 0.59 Open Hole 6 75 4.751,1 9 9251,5, 0:24 293 054 328.50 I 0.44 Open Hole 6 75 4.751 25 9276.5111, 0.56 293 05, 328.50 L 1.32 Open Hole 6.75 4.751 3.5 92801 008 293-05; 328.50 L 15 19 Open Hole 6.75 4.751 341 93141 0.76 293.051 328.50 L 1,90 Open Hole 8.75 4.251 5.51 9319.51 0.12 293.05: 326.50 L 0.29 Open dole 6.75 4.751 2.5 93221 0.06 293.05 328.50. L 0.13 Open Hale 8.75 51 26 9350 0.56 127.79': 343.121 L 1.91 I Page 35 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure Hiker!)Alaska,1,11; 18.12 Primary bit will be the Security EM65D. 6-3/4 (171mm) EM65D PRODUCT SPECIFICATIONS Cutter Type X3-Extreme Drilling sts, IADC Code M323 Ole Body Type MATRIX Total Cutter Count 33 Cutter Distribution J ZIE11111 4' oct 4 Face 4 II A r Gauge II 0 Up Drill 5 0 .,„ Number of Large Nozzles 0 ' Number of Medium Nozzles 0 Number ofStnall Nozzles 6 Number of Micro Nozzks 0 Number Ports(Site) 0 ' - Number of Replaceable Potts(Size) feC Junk Slot Area 04 in) 8.68 Normalized Face Volume 34.69% API Connection 3-1,2 REG.PIN Recotnrnendetl Make Up Moque* 5,173—7,665 Ftlbs. Nominal Dimensions** Make-Up Face to Nose 9.42 in-239 nun Gauge Length 2 in t nail Sleeve Length 0 in-0 Ilya Shank Diameter 43 -114 itta Break Out Plate(Mat.IVI egary91 181953,44030 Approximate Shipping Weight 90Lbs.-41 Kg. SPECIAL FEATURES Up-Drill Cutters on Gage Pads.116"Stepped Gage-Optimized Dtral Row-"D"Feature Material#761302 *Bit sticcific teratrcatrnded makr-up torque is a flmmion of the bit M.and actual bit sub 0.0.utilicrd 7f4 Nr.0.70,-d in Art Rrro Salim XX/. "Down dimenkinn MI!nominal and may vary slightly cm manufactured product Halliburton Dna airs and Services modelr are cantinumady rem:reed and mfined. Noduct treCiftcaties.rust h5tie."AZ 00.4ige C 2013 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.halliburton.corn Page 36 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure Hilrorp Alnekn,1.11 18.13 TIH to TOC. Shallow test MWD on trip in. Note depth TOC tagged at on AM report. 18.14 Conduct casing test to 3500 psi/30 min. p e.s$ 18.15 Drill out shoe track and additional 20' new formation. CBU and prep for FIT. • 18.16 Drill 6-3/4" hole to 10,000' MD/9,683' TVD • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal • seams once drilled. • Keep swab and surge pressures low when tripping. • See attached mud program for hole cleaning and LCM strategies. Ensure adequate LCM is available on location in the event returns are lost. • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain HTHP fluid loss < 10. • Take MWD surveys every other stand drilled. • • Pull wiper trips every 500— 1000 ft drilled. If tight hole is encountered, screw in and begin backreaming connections until hole conditions improve. Page 37 Revision 0 Jan, 2015 • KBU 31-18 Drilling Procedure Hilrnrp Alaykx,LLC 18.17 6-3/4"hole section mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 10— 11 ppg 6%KC1/EZ MUD/BDF-499 fresh water based drilling fluid. Properties: /-` MD 1/Mud '\ Viscosity Plastic Yield Point pH HPHT Weight _V Viscosity 6,100'- 10-11 ppg J 40-53 15-25 15-25 8.5-9.5 < 10.0 10,000' System Formulation: 6% KCL/EZ MUD/BDF-499 Product Concentration Water 0.905 bbl KCl 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) BDF-499 4 ppb EZ MUD DP 0.75 ppb DEXTRID LT 1-2 ppb PAC-L 1 ppb BARACARB 5/25/50 15-20 ppb(5 ppb of each) BAROID 41 as required for a 10.0—11.0 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) 18.18 Hilcorp Geologists will follow LWD log closely to determine exact TD. 18.19 At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8" shoe. 18.20 TOH with drilling assy and handle BHA as appropriate. + Page 38 Revision 0 Jan, 2015 • S KBU 31-18 Drilling Procedure Hileorp Alaska,I,LC 19.0 Run 5" Production Long String 19.1 R/U Weatherford 5" casing running equipment. • Ensure 5" DWC/C HT x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure to R/U Tesco or Weatherford CRT so that string can be rotated if necessary while running. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 19.2 P/U shoe joint, visually verify no debris inside joint. 19.3 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/ shoe bucked on &threadlocked (coupling also thread locked). • (1) Joint with float collar bucked on pin end&threadlocked (coupling also thread locked). • (1) Joint with landing collar installed INSIDE pin end. • Solid body centralizers will be pre-installed on shoe joint&FC joint. • Install a solid body centralizer on landing collar joint. Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe. 19.4 Continue running 5"prod casing. • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every joint to 6,100' MD. Leave the centralizers free floating. • Ensure to install swell packer joint so that it is 500' from the 7-5/8" shoe when landed out. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 5" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 5" 10,700 ft-lbs 12,100 ft-lbs 16,000 ft-lbs 0 Page 39 Revision 0 Jan,2015 • • KBU 31-18 Drilling Procedure Iliieorp Alit..i .LLC Technical Specifications Connection Type: Size(O.D.): Weight(Wali): Grade: DWCJ'C-HT Casing 5 in 18.00 lb/ft(0.362 in) L-80 Material wig; L-80 Grade 80.000 Minimum Yield Strength(psi) USA 95.000 Minimum Ultimate Strength(psi) V M-USA Pipe Dimensions 4424 W.Sam lis n t�kwy.Sua�150 Mauston,TX 77041 5.000 NominalPipeBody J.D.(in) tom: 713-479-3200 NominalPipeBody I.D.(in) Fax:713-479-3234 0.362 Nominal` ,'allThickness(in) E-matt:vAMu marHvaa.arn 18.00 Nominal Weight(lbs/ft) 17.95 Plain End Weight(Ibs/ft) 5.275 Nominal Pipe BodyArea(sgin) Pipe Body Performance Properties 422.000 Minimum Pipe Body Yield Strength(lbs) 10.490 Minimum Collapse Pressure(psi) 10.140 Minimum Internal Yield Pressure(psi) 9.300 Hy d ro static Test Pressure(psi) Connection Dimensions 5.563 Connection J.D.(in) 4.276 Connectionl.D.(in) 4.151 Connection DriftDiameter(in) 4.06 Make-up Loss(in) 5.275 Critical Area($.41 in) 100.0 Joint Efficiency(') Connection Performance Properties 422.000 Joint Strength(Ibs) 16.750 Reference String Length(ft) 1.4 Design Factor ' 457.000 API Joint Strength(Ibs) 422,000 Compression Rating(Ibs) 10.490 API Collapse Pressure Rating(psi) 9.910 API Internal Pressure Resistance(psi) 73.3 Maximum Un i axial Ben d Rating[degrees/100ft] Apimxitneted Field End Torque Values 10700 Minimum FinalTorque(ft-lbs) • 12.100 Maximum Final Torque(ft-Ibs) 16.000 Con n edionYiel d Torque(ft-lbs) For detailed information on performance properties,refer to DWC Connection Data Notes on following page(s). 0 Connection specificadonswithinthe control oft/AM-USA xere corretas ofthedate printed.Specifciions are subject tocharge without notice.Cedar correction s-peaficationsare dependenton the metharical properties of the pipe.Mecharical properties of mil proprietary pipe grades were obtaired frim mill publications and are sut:Oato change.Properties of mill proprietary grades should be confirmed wth the mill.Users are advised toobtan currentcorrectbn specifications andverify pipe mechanical properties for each application. Page 40 Revision 0 Jan, 2015 • • 14KBU 31-18 Drilling Procedure F[ilrnrp Alaska,LIC 19.5 M/U casing hanger joint to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe approx 10—20' above TD. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 19.6 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 19.7 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat (slightly)to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 19.8 After circulating, lower string and land hanger in wellhead again. Page 41 Revision 0 Jan,2015 • • 11 KBU 31-18 Drilling Procedure Ililoorp Alnskn,1.LC 20.0 Cement 5" Production Long String 20.1 Hold a pre job safety meeting over the upcoming cmt operations. Ensure the below is covered during the meeting: • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 20.2 Attempt to reciprocate the long string during cmt operations. 20.3 Pump 5 bbls 12 ppg MUDPUSH II spacer. 20.4 Test surface cmt lines to 4500 psi. 20.5 Pump remaining 15 bbls 12 ppg MUDPUSH II spacer. 20.6 Mix and pump 15.3 ppg class "G" cmt per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump 100% OH excess. Section: Calculation: (BLS) Vol (ft3) 7-5/8" x 5" long string Overlap: 500' x 0.022 = 11 61.8 6-3/4" OH x 5" Longstring: (10,000—6,100') x 0.020 x 1.5 = 117 657 Shoe Track: 90' x 0.019 = 1.7 9.5 Total Volume: 130 bbls 730 ft3 5e(o Page 42 Revision 0 Jan,2015 • • KBU 31-18 Drilling Procedure Hileorp Alnakn,id.0 Slurry Information: Tait System Blend Density 15.3 lb/gal Yield 1.35 ft3/sk Mixed Water 5.889 gal/sk Mixed Fluid 5.929 gal/sk Expected Blend Thickening Code Description Concentration D046 Antifoam 0.2%BWOC D202 Dispersant 1.5% BWOC Gas Additives D400 0.8% BWOC Migration D154 Extender 8.0% BWOC D174 Expanding 1.0% BWOC agent D177 Retarder 0.04 gps 20.7 Drop top plug and displace with filtered 6%KCl. 10,000 ft x .01776 = 178 bbls. 20.8 Do not overdisplace by more than '/2 shoe track. Shoe track volume is 1.7 bbls. 20.9 Bleed pressure to zero to check float equipment. 20.10 Pressure up again to 3500 psi and hold for 30 min to test production bore. I Page 43 Revision 0 Jan, 2015 I 0 KBU 31-18 Drilling Procedure IIilrorp 1laska,Ile Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume,whether plug bumped &bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to lkeller@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. 21.0 RDMO 22.1 Install back pressure valve in hanger neck. N/D BOP. 9 22.2 N/U tree. 1 22.3 RDMO Saxon Rig #169. /ft‘ 22.4 After rig has departed,pull BPV & run CBL to determine TOC behind 5"production casing. V 22.0 Perf and Frac , 1 A separate Sundry will be submitted to the AOGCC that will cover the perf& frac operations for ✓ V KBU 31-18. 23.2 Ensure to run a CBL across 5" to determine TOC after rig has departed. Expedite this to J AOGCC ASAP. 23.3 Test 5"x 7-5/8" annulus to 2500 psi after swell packer has had sufficient time to inflate. Page 44 Revision 0 Jan, 2015 i KBU 31-18 Drilling Procedure HiIcorp Alaska,TIC 23.0 BOP Schematic iai aii lir ilii ue minummi 1I • Saxon#169 r 3- 11"x5M iar tai iil Illlit T-3 Energy BOP 13-Energy Modal 60114 "I Manual Manual �� Manual Valve Valve IMMO Valve HCR Itt ttlj• •t■th•I ,lam 1811 ,r g ��r I Choke Lane y , _� •~1• � N I() P Line 3 44-74111 lit 1111,111,1i1:- _<1.11- �J 13-Energy Mode.1 fi0tll =Wilt 4054\ 3 � ` Grade'_eve? _ t_t I_ LTJ Sparer t.4= 115MXt15 41 lib.III lit 1!t -ne moi• �•- Seaboard-NIBS sy:s(ern �1 Err ■ � .y. 143 Y.3M X 11 5A '111F 1110 _ Ut : . • 49 Len- -1i I :IIS :FII Page 45 Revision 0 Jan, 2015 • • KBU 31-18 II Drilling Procedure HiIcor!)Alaska,Ill 24.0 Wellhead Schematic KBU 3 1-1 8 0 i 1 3-1i15 .10M *70 IA 041:10, i amo....0... t1.4:10':II 411• .0:4..a : Itad.'Pr 11111"1""1111,,, 4t; 1.1' \ 3-1115'/OM 3-1/1510M 0:4/0''A 1 . Are, --- 11 11P11111:1 :ill 3-1/15v 10M gt 111161.ill'. -„ AdaPte';5M-E-2CLN lir. 1.1 - — il'5M X 3-1/15'tom now*wax,its-or-aa. n.it 3-4/2 m woo sot end U X 3 "NKr .1/2 C111,0 IX*TOP eni film _ . Palliq ,C4t" al I asisor'II g.imsla[ oru'w I .....,_n up( l 1, X 7-5/4 iv, 0 set WL XIStliketAr il% . 0 ID: IMP mix 4r, - II'I 'al l 1 . 1 It.:44009 40-3/4 PS III. to+ 101161.. CAS HM . 9X6-21 MIMES timolust 1-411.Ili 14-3/4.X 10-3/4 , 1111111 I, ... 3/4SN il I 1•A' 911"1"4"4"ItAt L.,. mi:I .I,.III 1 100%. 10 --, ..,, 1 '11 • I IIit COMO---,... I 110414 CIO llIPAt' ' "0412 MP*-............01 P- SEAMIOA RD 3 000 z.: 0,:e -ea4 1 10 000 7.s I.-et"ISSe Is x 10-3,,s st 7-34 xi-III l XESTIKTED 1:00.00014 0.04110DIT,.,. ., ,...., ..*1-.42 17W4212 al, 1 _---...,. .....zi•Lu....1 TM A.../._ 4110.01110 MI P 1 48 7 3 1 1 17. Page 46 Revision 0 Jan, 2015 I S KBU 31-18 Drilling Procedure HiIrarp Alaska,!IC 25.0 Days Vs Depth Days Vs Depth 0 -KBU 31-15 -KBU 42-06Y 2000 4000 Zi tai v 6000 m v 5000 10000 12000 0 5 10 15 20 25 30 35 Days Page 47 Revision 0 Jan, 2015 I KBU 31-18 Drilling Procedure II ko 11,A1A1.51,1,I I I 26.0 Formation Tops ANTICIPATED FORMATION TOPS&GEOHAZARDS 1 I EXPECTED FLUID MD TVD(FT) SUBSEA DEPTH Est. Pressure Sterling Met 3,887...._. ._._...... 3,980 _._.. (3093) . Sterling 5.2 •as/wet 4,249 4,243 1 (4156) 1 Sterling Pool 6 E gas 4539 4532 (4445) 200 Upper Beluga " gas 4,800 4,778 (4691) 900 Middle Beluga gas 5,479 5,417 (5330) 1000 Lower Beluga = gas ..__ _ 6,255 6,146 (6059) 1000 . - „,' Upper Tyonek ' gas ,.. 7,468 ; 7,286 (7199) 2500 t` TyonekDi gas 9,051 8,773 (8686) 2000' Tyonek D2 gas 9.244 8,995 z (8868) ' 1000 T onek D38 s 9,5349,227 (9140) Tyonek D4 mm 9,703 9,3861 (9299) =Reservoir Objectives =Possible Geo Hazards Page 48 Revision 0 Jan,2015 I • KBU 31-18 Drilling Procedure Hilmrp Alaska,LLC 27.0 Anticipated Drilling Hazards 13-1/2" Hole Section: Lost Circulation: / Ensure adequate amounts of LCM are available. BARACARB 5, 25, 50, 150, 400, and 1200. Ensure STEELSEAL, WAL-NUT, and BARAFIBRE are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of BARACARB 5 and 25 to the active system at 1 —2 ppb. Hole Cleaning: Maintain rheology w/ gel and gel extender. Sweep hole with gel or BARAZAN sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 25 —45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of—50 -—60 lbs/100ft2 to combat this issue. Maintain low flow rates for the intial 200' of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 20—30 prior to cement operations. Do not lower the YP beyond 20 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheology can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 49 Revision 0 Jan, 2015 i • KBU 31-18 Drilling Procedure Hilrorp Alaska,GLC 9-7/8" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. BARACARB 5, 25, 50, 150, 400 & 1200. Ensure STEELSEAL, Wal-Nut, and BARAFIBRE are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. Background concentrations of LCM (sized calcium carbonate) should be btwn 5 — 10 ppb while drilling this interval. There is a high probability of lost returns through the many stacked, depleted sands in this hole section. Hole Cleaning: Maintain rheology w/BARAZAN. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain 1ppb total of PAC L and 1 —2 ppb DEXTRID to maintain a thin/strong wall cake and keep HTHP filtrate below 11 ml/30 min. Maintain MW as necessary using additions of Barite. Maintain 4 ppb BDF-499 for shale/clay inhibition. Maintain 2—4 ppb BAROTROL and 2—4 ppb Soltex for Shale/Coal stabilizer. Maintain 6%KC1 in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams (BAROTROL, Soltex). • Increase fluid density as required to control a"running coal". • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb Asphasol Supreme pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss. H2S: H2S is not present in this hole section. V No abnormal temperatures are present in this hole section. Page 50 Revision 0 Jan, 2015 I KBU 31-18 Drilling Procedure Hitewrp Alaska,ILC 6-3/4" Hole Section: Lost Circulation: i Ensure adequate amounts of LCM are available. BARACARB 5, 25, 50, 150, 400 & 1200. Ensure STEELSEAL, Wal-Nut, and BARAFIBRE are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. Background concentrations of LCM • (sized calcium carbonate) should be btwn 5 — 10 ppb while drilling this interval. Hole Cleaning: Maintain rheology w/BARAZAN. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain 1ppb total of PAC L and 1 —2 ppb DEXTRID to maintain a thin/strong wall cake and keep HTHP filtrate below 10 ml/30 min. Maintain MW as necessary using additions of Barite. Maintain 4 ppb BDF-499 for shale/clay inhibition. Maintain 6%KC1 in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The • need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams (BAROTROL, Soltex). • Increase fluid density as required to control a"running coal". • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb BAROTROL pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss. H2S: , H2S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 51 Revision 0 Jan, 2015 • • II KBU 31-18 Drilling Procedure Hilrorp Alaska,LLC 28.0 Saxon Rig 169 Layout 123'-7" 36'-0" 55'-6" 30'-0" b INN f'RE-v'' TANK (m ,,nu 596 AAI 1 II ,� ■. _ ��s — +_II .r life.untapo , ---i [ice .� � X919!111- .41 11 lF-1,12 f I 1 Im` "w'' tib?TAPP ___ :I •Iil i� o-• i 11 11- . 1E. I •' a-_- 11 j !� —.11 � LRA QR mun pimp it gig - Liii — z u_iil � Eo re I11 i ! RI �""' — lwI a ,— �I l� " I I I''. ' I I 1A.<: j� En'., LA I� NNI11INN1I1111NI11NNINIINIIIIIIIIuNIIINIIIIIIIINII.u1I11un�uelLIII�I uuM1INNbNNI11N1 .11IIIIIM1111111111IIlIIlllIl1 11111I111111111111111111111111N111111111111111111111111111111u11 11111111111111111111111M1I11IIPNI-- I a ""1UlINII1ilNN 1111Npom` mr. , `- lr�la „ " '1t I, .,... 0M o idr - s�wl� I a,Rqtw rn,,r II. -''. —�� i�I•1111lYllUlUil -. 1 11111111NN111N111111111111111CININIIt misi�i min. 111 - II111131 l lllhluli a ----,,,,..„:.„.,=;.„,..7:-.7,______-_,_, ,mune ,i IIIIII1I111MIIIII1111IIIIIIIIINI111111111III11'Hnimpolln1'!�II iiiiii1i11II1iI111111 . 111111111111 11111111111111N111111I111111111111111111111111111111111181111>!ill .11i i IIIIINII 1011110111111111111111118111111 1INIIINI111 1 :6-7. "rIL II I itigirfillrf � � ��- �11111lII�IIpI4k jilt NilillU lil;kil`II I. .Twp . V� aiF�r ci murta poCHNSF,MATFR TmocaocuiouM 53'-0" 45'--0" . 85'-0" F' 85'-5" 70'-4' -4 Page 52 Revision 0 Jan, 2015 / • i KBU 31-18 Drilling Procedure Iti!,orp,1lnskn,1d.0 29.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer(ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 53 Revision 0 Jan,2015 • • KBU 31-18 Drilling Procedure HIIrorp Alaska,Ill 30.0 Choke Manifold Schematic 61.24 4162 4162 I -�.C3 1643 14.2v 1492 1641 tirX !''r t C O. 6.19 A�A, OAS 619 ti Fowl ra1MN= 619 ala 111.1,1. ...1.1 . B ma-I I 4"m G 1111111111111 s�i■ ms 1es ata . to © t,a 9.64 '2' - va �� MINIIP 619 P.rol. 39.63 t 4111.41 U.6191 o' ,s,..-1.4'. aha 1492 r.' •� r r. 1462 ..i!; 1. A f 12'1' +�R 11 1D' '�0 4:- 19.62 A►A. 4.19 1� !'`I'{,''` ►...ami �m,, ! �l �6(ial coo ilier a,a moo V 1.e,.r.i619 .- a2 oraa * -at9 —618 .19 — 619 — —are ,.I..1 I1a16� —rya, X1462 —1442 1462 14.62 5.? ..�" 4362 4162 ,.. - 60.24 . aon• CAD :,rLSL'."-te y 1.MY6117 MM R 2191915 1 1'* S- C__-..--.7-1.22,--- A'T'iT^ice., sSw ,,.. 1 e-✓:_. o ':'11!'RT-.rl'!! -„6i-51-,, Page 54 Revision 0 Jan, 2015 KBU 31-18 Drilling Procedure Hibor')Alatika,LLC 31.0 Casing Design Information Calculation &Casing Design Factors Kenai Beluga Unit DATE: 2-2-2015 WELL: KBU 31-18 FIELD: Kenai Gas Field DESIGN BY:Luke Keller Design Criteria: Hole Size 9-7/8" Mud Density: 9.5 ppg Hole Size 6-3/4" Mud Density: 11 ppq Hole Size Mud Density: Drilling Mode MASP(sec 1): 1254 psi(see attached MASP determination&calculation) MASP(sec 2&3): 1977 psi(see attached MASP determination&calculation) Production Mode MASP: 3332 psi(see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1,2,3 Max MW gradient external stress and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 Casing OD 10-3/4" 7-5/8" 5" Top(MD) 0 0 0 Top(TVD) 0 0 0 Bottom(MD) 1,500 6.100 10.000 Bottom(TVD) 1,500 5,900 9,683 Length 1,500 6,100 10.000 Weight(ppf) 45.5 29.7 18 Grade L-80 L-80 L-80 Connection BTC BTC DWC/C HT c..-. Weight w/o Bouyancy Factor(lbs) 68.250 181.170 180,000 Y•I3''. Tension at Top of Section(lbs) 68.250 3`61.170 180.000 Min strength Tension(1000 lbs) 1040 685'714 457 Worst Case Safety Factor(Tension) 15.24 , tee4Q6 2.54 Collapse Pressure at bottom(Psi) 741 2.915 5,035 Collapse Resistance w/o tension(Psi) 2,480 4.790 10.500 , Worst Case Safety Factor(Collapse) 3.35 1.64 • 2.09 MASP(psi) 1,254 3.332 3,332 Minimum Yield(psi) 5,210 6.890 9,910 Worst case safety factor(Burst) 4.15 2.07 2.97 Page 55 Revision 0 Jan, 2015 Z,,3, ,� • KBU 31-18 Drilling Procedure Il ileorp.\In<4a.I,LC 32.0 9-7/8" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 9-7/8" Hole Section KBU 31-18 Ninilchik Unit MD TVD Planned Top: 1500 1500 Planned TD: 6100 5900 Anticipated Formations and Pressures: I Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Sterling 3,980 250 gas/wet 1.2 0.063 Sterling 5.2 4,243 1500 gas/wet 6.8 0.354 Sterling Pool 6 4,532 200 gas 0.8 0.044 Upper Beluga 4,778 900 gas 3.6 0.188 Middle Beluga 5,417 1000 gas 3.6 0.185 Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date KBU 11-17X 9-9.2 1,587 5,464 2009 KBU 14-08 9-9.2 1,510 5,432 2008 KBU 41-18X 9-9.2 1,500 5,391 2008 KBU 24-7X 9-9.7 1,502 5,326 2006 KBU 32-08 9.3-9.8 1,446 5,401 2014 KBU 43-07Y 9.5-9.7 1,540 5,738 2014 • Assumptions: 1. Fracture gradient at 1,500'MD/1,497'TVD is estimated at 0.936 psi/ft based on field test data. 2. Maximum planned mud density for the 9-7/8"hole section is 9.5 ppg. 3. Calculations assume"Unknown"reservoir contains 100%gas(worst case). 4. Calculations assume worst case event is complete evacuation of wellbore to gas. Fracture Pressure at 10-3/4"shoe considering a full column of gas from shoe to surface: 1500(ft)x 0.936(psi/ft)= 1404 psi 1404(psi)-[0.1(psi/ft)*1500(ft))= 1254 psi,' MASP from pore pressure(unknown gas sand at TD,at 9.2 ppg(0.4784 psi/ft) 5,900(ft)x 0.4784(psi/ft)= 2822 psi 2822(psi)-[0.1(psi/ft)*5900(ft))= 2232 psi Page 56 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure 33.0 6-3/4" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 6-3/4"Hole Section KBU 31-18 Cook Inlet,Alaska MD TVD Planned Top: 6100 5900 Planned TD: 10000 9683 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Lower Beluga 6,146 1000 gas 3.1 0.163 Upper Tyonek 7,286 2500 gas 6.6 0.343 Tyonek Dl 8,773 2000 gas 4.4 0,228 Tyonek D2 8,995 1000 gas 2.1 0.111 Tyonek D3B 9,227 2700 gas 5.6 0.293 Tyonek D4 9,386 700 gas 1.4 0.075 Offset Well Mud Densities Well Max Drlg MW Top(ND) Bottom(TVD) Date KBU 11-17X 10.7 5,464 7,919 2009 KBU 14-08 10.3 5,432 7,746 2008 KBU 41-18X 11.6 5,391 8,651 2008 KBU 24-7X 9.7 5,326 7,550 2006 KBU 32-08 10.70 5,401 8,183 2014 KBU 43-07Y 12.10 5,738 9,280 2014 Assumptions: 1. Fracture gradient at shoe is estimated at 0.936 psi/ft based on field test data. 2. Maximum planned mud density for the 9-7/8"hole section is 11 ppg. 3. Calculations assume"D4"Sand contains 100%gas(worst case). 4. Calculations assume worst case event is 2/3 evacuation of weilbore to gas. Fracture Pressure at 7-5/8"shoe considering a full column of gas from shoe to surface: 5900(ft)x 0.936(psi/ft)= 5522 psi 5,522(psi)-[0.1(psi/ft)*5,900(ft))= 4932 psi Drilling Mode MASP MASP from pore pressure(2/3 wellbore evacuated to gas from"D"at.444 psi/ft) 9,683(ft)x 0.444(psi/ft)= 4300 psi 4,300(psi)-[[0.1(psi/ft)*9,683(ft)*2/3]+[0.52(psi/ft)*9,683(ft)*1/3])= 1977 psi Production Mode MASP MASP from pore pressure(entire wellbore evacuated to gas from TD): 9,683{ft)x 0-444{psi/ft)= 4300 psi ✓ �� 4,300(psi)-[0.1{psi/ft)'9,683(ft)]= 3332 psi Summary: 1. MASP while drilling 6-3/4"production hole is governed by SIBHP minus 2/3 wellbore evacuated to gas from TD. 2. MASP during production mode is governed by SIBHP minus entire wellbore evacuated to gas from TO. Page 57 Revision 0 Jan, 2015 ii 11, KBU 31-18 Drilling Procedure Hitemp A Imam Ile 34.0 Spider Plot (NAD 27) (Governmental Sections) Kai 04(KU 13-7:,BHL, j,/ ,' • / / pm/32.07 BHL4 * *f* o * • 0 * 4 4 4 4 4 * 0 * * * * 0 4 * 0 4 * 4 0 f 84 `,. 7 ;‘, 494 * * * 0 49 .4 4. * * 6 . 4, 44 * 4 94, 4 * * * * * * 98 ...1,1r, 4 4 0 * 6664 6 * * 444 • * 4 * * * * * * * a * * * * ** * 4 4 * * * . KBU'3-08.BHL , * * o * * o * ., * 68 .. 48 * * * 44 # 448 - „, * * * OS * * * „.., i... KOW,L4-Pgi BHL & 33B} - 7L 9 4 4 8 4 4 4 4 4 44 . . . . 0 8 9 opoo * * * * * * * ?* 6 .?, 54\066 4 6 4 * ../ 4 * 6 44 66 60/44 66, 0 0 4 66 84 44446 * 444 oe00000c *• •1012341711140* 4 4 4 8 * Ku i3_0713Hc. o o • / o * * * 44 6 4 88 6/6 * 6 6 • * * * * * 1,ZBU 43437X BHL-- ' I - o 7 4 . . . . . 4 0 SA, 4 • 3 4 4- , ' 0 KEIL/43-07Y BHL 44883 - , 4 98488 * 4604444 8 ' 4494 .i. tte 4 90 6 6 * * * .6 4 4 4 ' 4 0 * 44 f 4* 0 4 4 4 4 * 4 * 8. * * 0 9 8 4 484 * * * 4 * * 448844444 * 41* * * .* - 4 4 * 4 4 4 4. * 0 4 * * , 484 * * * * * * 48 * * * 4 4449 * * 0 * . * 0 4 * , /4 * 6666614 * 4 0 * 0 * * 0 * 0 if 0 * * If • . • * 0 If * * * .4u 4-0813Ht* / t o * * o * * * * c / ,./ 466644644 v KM/24-7X BHL, 4 4 4 * 4 # a 4 9 3 6 9 * * • * 4, • 8 kUppi(Ku*-1.1403 . /` ,, 4, 6 9 4 8 • KU 24-D7 BHL .--.---._ o * o 0 o * o 4 * S ., 41 4 - ' // - 40 * * * * * 4 666 0, KU 24-4gRO lil-U 4 * IF 1 * , I/ .,./ * * * 0 0 * 4 0 V 4 * . ,' ,' --. KIM 41-T8X'NHL= ' * -X * 4440 * * ...„ . t ,',- / , , 6 \ \ '.. ti 7 / Ku 11-17 BHL-- , . !lir 7. KBLI 31-18 BHL ----.N. \ ( i 7 / MU 31-18 1.6%//' -,,..._ \-- y , / , * * * * * * * * 000 KENAI UNIT , ---- \ '4', il(BL. 31-18 SHL . 4, * .. . . .06 * * 6 SOO4N011W, 66 ..... 6 64 0 * 6 nahrct- .:.•-xt ..4146'--, * 4 * 4, * 8 * * * 4 * 0 4 * 4 . 4111142'- 4.. 11-17:4 EAU O- oo / o N - 0 * V * 4 8 4 8 * 8 4 4 4 8 4 , , 4,. a 4 4 4 e e 4 .6 * i4 * 46 4 6, 66 • 4064446 ' KIR;31-18 TPH, v., , .:' ' . , * 4 .4084848884 * * * e , * 14 4 4 4 0 4 4 -------- , 4 4 14 4 4 4 * k- \ 4 - '' 0 * 0 0 40 .* * * * * * * * * * • ff 4 0 * * * 9 * * * 9 0 * * * * * * 4 4 4, \ 0 -,, * 4 4 4 4 4 0 4 4 4 4 4 4 4 et 4 4 49 A 466 4 ft Of * * Off 444t . * if 4 0 4 4 84 44 * * * 499088 t 4 - , 4 4 0 0 0 4 4 4 4 4 9 ti 4 0 4 4 8 * * * 0 * 0 A 4 9 8 a * 4 a 4 4 4 9 4 * . ,-\ ', 4 9 .9 4 4 3 9 4 4 4 4 4 8 * * * * * 4 * 4 4 4 0 . , , R 0 * * * * * * * 0 , \ 0 * * * * 0 ° ° ' ''' * 0 0 r, 0 * * 4 0 * 0 * 4 * 4 8 , ,, 4 * * * 4 , 44049 ,, 4 3 4 4 4 4 - emiaD 9 48 . . 4 . . . 4 - \ 4 * 8 8 4 @alga 4 44 84 4 0 4 O V 0 0 0 * * * * * * 4* * * * 4 4 4, .- * * * 4 4 4 4 4 * 4 4 4 4 4 4 4 4 . . * * * 4 6 4 8 0 It I* 4 4 8 4 4 , * 4 3 4 0 0 0 8 0 * * 5 • * * * ft 4 * 4 4- 0 4* 4 4. * * * 9 4 * 4 * * 4 7 '-', , 8 4 4 , , t 5 -44494444* 84. 4 * * 4 0 0 0 4 * 844 ,09444 * KLI12-17&Hex, o a , Legend , • 6 4 4 0 4 0 16 * 4 4 4 * 0. 4 * * * -4 it * 4 - - 4 4 8 4 * * * * * * * * * * * * * * * * • * • * 4 * * 4. 64 , 6- * * . Other Surface Well Locations o * • 4 4 4. 4 4 0 0 * 4 * * * * .4 * * to 8 * 4 * 4 * * * * 4 * O * * * * 044 ' * * * * * * * * * * * * * * * 666666 * ther Bottom Hole Locations 400 .646 0 6 0. 4 * * 0 * * * it 6 6 .6 4 0 6 4 6 a* 6 4 Wen paths * * 0 .4 * 0 , 00 * * * * * * 46664 6666 6 4 406r**461 _ Well Pad * 0 * * * * * * *to * * * 4 44 60 46 . 646 46 446 I j. * 06646 ;3. * * * * * . . * * * * 44 . 4 8 CD Oil and Gas Unit Boundary O * 090 4 19804 4 i KU44-18BHL,, * o * o 0 * 4 4 4 . L ,. 1 Hircorp O&G Minerals * • 0 0 * * 4 4. * * 0 4 4 * 4. 4 * , '., • * * • * 8 * * * * , II Kenai Unit 0 1.CCO Feet KBU 31-18 Alaska Slate Plane Zone 4,NADZT 2'13: ltit1T4111 1164.,1 IV Mao Date:1;302C115 A Page 58 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure 11,4 0,1,,A I.i.4ka,1.I,I' 35.0 Surface Plat (As Staked) (NAD 27) \ SECTION LINE NTS \it 43 ^Y C, TION' nr a �xn w L1 't ' SECTION 18, T4N. 11W " , S.M.. AK " ti i. \ i , SO :Nricot--------ronv. 7%':''I"NI : '� H4fat:2dT1i "ii 0!i$k4 r:GEd 1#G ' n ji NJ ,t Igm t#31''.2) KSU 31-18 AS-STAKED NAD27 cLoe wa' 10r°X10r GRID N:2356031,00 &+40t CNAN Wit; GRID E:275327.00 2441 ct1NrT LBIDE -11\ i • LATITUDE:60'26'35.4496"N LONGITUDE' 151'14'37,1814'W DRII ELEV.;67 0 FT, °lows r-r EIDE teen ee ill 1 0, 9 i% i II % , 14e7i 4441 ..- I axxras !±LCIS 40EJ'FEL AI PI: 1�,.-++ u 11.17 fik % Ur rx.X:a � Mit A4,§M A' ,4 „,. „ 0. UJ T:Y,iS" A31*AJ K It t.i-$ j: ir a� T{T4ltP7 J ii Ura l'+vy, :RY?r z ' PROMOTION ..A E+1.°1X3 0&" ., fgCt.111t3 I- �, E7 i 2 o KENAI GAS FIELD GE/ °xis° Cts PAD 41-18 gr°rDRAtiixA xnLIT r Tr4.i1i HEA1Eti x,..0004111 l I X ,:fr t bb��/�yy((��Tl� .:57 10 4._......N • _*,49m � •••:*' N0R i-. 1 RtiSI°tlE tiURIZiNITM.4.`1CNGINATC3 ARE ALAEKA STATE Pi.ANr NAN? i r. .••w r-OV►_..- ZONE+OET'ERMMaED DT ACMkECT TIE TO USCADS Tait STA AS.CI'1Y HAVING PUBLISHED PO$rTION OF LAT.110"3O5D.5'A'N LONG.151'11337.WSYA 44 t•-SSThY JL NitLPNE ' l.� N2.O2o4E 42 E:MESS 75 { .44537 5 °I "x,46 LAN Ejr 2I BASEL CF VERTA"•AL DATUM IS MEAN SFA LFYEI ,� .� SCALE y7D0UT'V'€STCORNER SEC.6COON NATEOCTERMINEDFROMDIrL r I{ 1 1��` WTI 2•I] WC IS CORNER SECTIONS EXISTINGSURVEY tlE To THE TO 7 RECOVERED At NOT THE PROTRACTED Ie I i SECTION CCMMER VALUES H FEET r KBU 31-18 WELL ON KGF PAD 41-18 CP1E "M WF19UE fl Inc LW NANNY Nom.' AS-BUILT SURFACE LOCATION OIAGRAIuf it NAD2 f 9G41.i. 1-.iR E,,,,,EE.,o,wenke,N.WE1 i46 T£kv S`.?.Pax ai SCIDOT.,V.AOC MEI i c e+7CE owl oee 1.41$ fA4 .xtrebbavx, _ 8ntt. "."- "a4kN °M f[ilriarp 41a..1.41, 1L S18 T4N R11W SEWARD MERIDIAN.ALASKA Page 59 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure Hilrorp Ala/18,1,1,C 36.0 Offset MW vs TVD Chart MW vs TVD Offsets 0 i ! —KBU32-08 1000 IIIIIIIIl �l KBY 43-07Y 2000 Iis —KBU 11-082 KBU 23-05I I li — 3000 E KDU 10 4000 ILI1NI KBU 42-06Y I 34/.;. 5000 r w ) iliiI1II w. 5•/sem E 6000 IIl 11111 i 7000 1k \I 8000 ikLk E I € 9000 11 1� 10000 I 11000 I g / I i i 1 i t 12000 13000 6 7 8 9 10 11 12 13 14 Mud Weight(PPG) Page 60 Revision 0 Jan, 2015 • • KBU 31-18 Drilling Procedure II 1,1:Nlia.LIK 37.0 Drill Pipe Information _ . SIZE 4 1/2" COMMANII WEIGHT: 16.6 Les/FT GRADE: 5-135 E. ,,, RENY SIMMS RANGE: 11(31,5) DRILL PIPE SPECS CONNECTION: CDS4O TUBE NEW PREMIUM IN „,,.. MM IN MM OD 4,500 T14.3' 4.3.6!,.: 1 1 0 9 WALL THICKNESS 0.337 8.6 i 0.270 5.6 ID 3.826 972 3.525 97 2 FT-LBS NM FT-LBS N-M TORSIONAL STRENGTH 55.453 75200 43.451 58.900 80%TORSIONAL STRENGTHI 44,362 60.200 34.761 47.100 LBS DAN LBS DAN TENSILE STRENGTH 595,004 265,300 468,297 208 800 PSI KPA PSI KPA INTERNAL PRESSURE CAPACITY 17,693 121,985 16,'76 111 S.:I0 COLLAPSE CAPACITY 16,769 115,615 10,959 75.061 1N2 MM2 IN2 mm2 CROSS SECTIONAL AREA BODY 4.407 2844 :3.46E 2238 CROSS SECTIONAL AREA OD 15.904 10261 14.955 9655 CROSS SECTIONAL AREA1D ' 1.497 7417 11.497 7417 IN2 MM3 1N2 MM3 SECTION MODULUS! 4.271 69995 3.347 54845 POL A SECTION MODULUS! 8.543 139989 6.694 109590 TOOL JOINT ,, NEW i PREMIUM PSI KPA PSI KPA YIELD STRENGTH, 130,000 896.318 130.000 896,318 1N MM IN MM OD, 5.2500 133.41 5.1198 130,0 IDI 2.6875 68.3 2.6875 68.3 PIN LENGTH' 11,0 279.4 11.0 279 4 BOX LENGTH! 14.0 355,6 14.0 355.6 rr-LES NM FT-LBS N+4 TORSIONAL STRENGThI 35,400 48.000 34.700 47,100 MAX MAKEUP ToROUE 22,500 30.5001 21,400 29,000 RECOMMENDED MAKE-UP TORQUE 21.200 28.800 20.800 28.200 MIN MAKE-UP TORQUE/ 19.600 26.600 19.300 26.200 LBS DAN LBS DAN TENSILE STRENGTH 824,400 367,600 804.900 358,900 TOOL JOINT/DRILL PIPE TORSIONAL RATIO' 0.64 0.80 _ _ ___ ,___ ../ DRILL PIPE ASSEMBLY WITH CONNECTION LBS/FT KG/M ADJUSTED WEIGHT 17.87 26,64 FT M APPROXIMATE LENGTH 31.50 9,60 GAL/FT Ma/M FLUID DISPLACEMENT 0.273 0.003394 FLUID CAPACITY 0.577 0.007169 IN MM DRIFT SIZE 2.5625 65 Page 61 Revision 0 Jan, 2015 0 0 KBU 31-18 II Drilling Procedure Hileorp AlaNka,IAA] COMBINED LOAD CURVE FOR 4 1/2"S-135 16.6 u3s/FT DRILL PIPE WITH CDS4O CONNECTIONS 900,000 800.000 700,000 610.0G0 0X0 OW0 C0.0 mm van 020 en0 x00, t , .0 500.000 q"Z ; E 40,,xx, ,, S. , C. 'IC ';** 300,000 ,„, , *. %6 o Nz. 0 rt. 200,000 „ o 3 , „.. I ' 100.000 * . .. . ii o MOOD — .SHOuLDER SEPERATION 20,000 30,000 Applied Torque(ft-lbs) NEW TUBE COMBINED LOAD F- 40.000 50,000 PRmit'm T -.........0RE COMBINED LOAD MAK EAR TOROUS -PIN YIELD ••••••••••••BOX YIELD 60.000 Page 62 Revision 0 Jan, 2015 • • Hilcorp Energy Company Kenai Gas Field KGF 41-18 Pad I � :1 Plan: KBU 31-18 KBU 31-18 Plan: KBU 31-18 WP3 • Standard Proposal Report 28 January, 2015 HALLIBURTON Sperry Drilling Services m I WELL DETAILS:Plan: -18 NAD 1927(NADCON CONUS) Alaska Zone 04 Kenai Gas Field •ect: Ground Level: 66.64 HALLIBUPTON Site: KGF 41-18 Pad +N/-S +E/-W Northing Fasting Latittude Longitude Slot Drilling Well: Plan: KBU 31-18 0.00 0.00 2356031.00 275397.00 60.4431805 -151.2436615 SperryWellbore: KBU 31-18 Plan: KBU 31-18 WP3 REFERENCE INFORMATION — Co-ordinate(N/E)Reference:Well Plan:KBU 31-18,True North — Vertical(TVD)Reference:Prelim:KBU 31-18©84.64usft -500— Measured Depth Reference: Prelim:KBU 31-18 @ 84.84usf1 — Calculation Method:Minimum Curvature • 0- 500— 500 1000— 1000 1500— 10 3/4"--- '1500 2000— 2000 2500— 25p0 3000— 3000 3500— 3yp0 — t 4000r Sterling 000 C - o ---Sterling 5.2N - 45001 Sterling Pool 6 - g500 ._ —Upper Beluga Q- 5000 p5000— f -.-- Middle Beluga +500 5500— 2 - 6000 I— 6000- --Lower Beluga -• '6500 6500— 7 5/8" — 7000 7000— KBU 31-18 tgtl wp3 -Upper Tyonek- 500 7500— - 6p00 8000— _ 55p0 8500— —Tyonek D1 '000 9000--Tyonek D2 KBU 31-18 tgt2 wp3 -- -Tyonek D38 .50° Tyonek D4 / - 9500— •10000 / „ 5 - ` V 10000— KBU 31.18 WP3 I i i i I I I I I I I I I I I I I I I l I I I I I I l l I I I I I I I I I I I I I I I I I I I 1 f 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 Vertical Section at 275.07° (1250 usft/in) LAI 11ikc•orp HALLIBURTON • Project: Kenai Gas Field • WELL DETAILS:Mani KBU 31-18 Gro114(MTV o.naoo Site: KGF 41-18 Pad +x/-s+E/-W Northing Fasting cat;nudo Longitude Slot 800— Well: Plan:KBU 31-18 0.00 0.00 2356031.00 275397.00 60.4431805 -151.2436615 Wellbore: KBU 31-18 Plan: KBU 31-18 WP3 REFERENCE INFORMATION 700— Co-ordinate(N/E)Reference:Well Plan:KBU 31-19,True North Vertical(TVD)Reference:Prelim:KBU 31-18 Q 84.84usa — Measured Depth Reference:Prelim:KBU 31-18<884.84usa Calculation Method:Mnimum Curvature 600- 500- 400—- Total Depth:10000'MD,9684'TVD • ' 300—- / • ¢ Start Dir 39100':2000'MD,2000TVD - J - m �e 200— r `/� End Dir:2503'MD,2497 TVD l 0 100— 5" _ o i9 7 _ ten`' Start Dir 4°/100':7157 MD,6991TVD I�, n 0— u o - liUU 31-lR 1gC nP3 4' o End Dir:7471'MD,7292'TVD a �'tlll co _ DD Poly 95%coat. �,Vy / S 1sy i 0/ 1 � $ 10 3/4"$C -100— y $ /it % o o 'li $-zoog _ KBU 31-18 toll mp3 I� gP c DD Poly 95%coni -300— 7 5B" -400— -500- -600— • -700— T M Azimuths to True North . Magnetic North:18.41° Magnetic Field -800— Strength:55295.2snT — Dip Angle:73.43° — Date:11/18/2015 _ Model:BGGM2014 — -900 1111111111111 : 1111111111111I1111I1111I1111I11111111111111111111 11111 : T11111111111' 111111111 IllIll1I1111I1111I 11111 1111 l . ill -2200 -2100 -2000 -1900 -1800 -1700 -1600 -1500 -1400 -1300 -1200 -1100 -1000 -900 -800 -700 -600 -500 -400 -300 -200 -100 0 100 West(-)/East(+)(250 usft/in) I,114.418.11 • HALLI8URTON • KBU 13-8 KBU 32-07 WPI.0 KBU 43-07Y Sperry Drilling Services KU 11-17 ,iI p4 Project: Kenai Gas Field KBU 32-08 "p' Site: KGF 41-18 Pad Well: Plan: KBU 31-18 w 100 KU 41-18 Wellbore: KBU 31-18 Plan: KBU 31-18 WP3 5333— 0 0000 KBU 11-17X N + 0 2000 s' KBU 31-18 WP3 t o O Oo 4800— -100 s_ O 1000 0cip -200 :000 4267— -400 -300 -200 -100 0 100 200 West(-)/East(+)(200 usft/in) KBU 32-08 800 o 3733— 914'6 KBU 13-8 KBU 32-07 WP1.0- I i ) � 1 O 3200— No No 7000 6 - 6000 °00 2667— 80p0 KBU 43-07Y - 1 i s°00 9300 s 7 p0 °00 - 1000 2133— 6.6 + KBU 14-8 .4 4000 4000 , / 6000 Ao ch 4000 1600— ..' - 6000 0 o — rn S000 3000 50 30042 p KU 41-18 1067— KBU 41-18X 40 7 8648 00 g0°0 ,2000 U11-17 - KBU 31-18 WP3O 3' 2000 533— ' a� ,,i o - J ' t,, ,, 0 .? M di' KU 13-8 p o ° 0— mop s4;,: 0 ao 0 o % i 81rI I I ,.../.-- 'Oohs_ - o o KBU I 1-17X 0 -533— - T M Azimuths to True North -1067— Magnetic North:16.41° - Magnetic Field Strength:55295.2snT Dip Angle:73.43° - Date: 11/18/2015 Model:BGGM2014 -1600— iiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiIiiiiiiiiiiiiiiiiii -2133 -1600 -1067 -533 0 533 1067 1600 2133 2667 3200 West(-)/East(+)(800 usft/in) • • Halliburton ALL.I B L RTD N Standard Proposal Report .. .win _ m s 1 N nI.,�w , _ _mom.. 'Rk,M,,, II Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 31-18 Company: Hilcorp Energy Company TVD Reference: Prelim:KBU 31-18 @ 84.64usft • l!' Project: Kenai Gas Field MD Reference: Prelim:KBU 31-18 @ 84.64usft Site: KGF 41-18 Pad North Reference: True Well: Plan:KBU 31-18 Survey Calculation Method: Minimum Curvature • li *k Wellbore: KBU 31-18 /tlt1 Design: KBU 31-18 WP3 ' '" pt „ -. �IIBIYBPYpYYCG7k eiremie°u �=a tee...s .-_ � ;.x --- �°ma,.m�coamsswcsx yexarniH aax Project Kenai Gas Field ff ane a Mo r ,r„„ i,„,,,,,,„„� r F � a,aaarwwr Map System: US State Plane 1927(Exact solution) • System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) • Using Well Reference Point Map Zone: Alaska Zone 04 • Using geodetic scale factor Site KGF 41-18 Pad rvmaMwa1ueenu u - s Site Position: Northing: 2,356,042.86usft Latitude: 60.4431928 From: Lat/Long Easting: 275,008.97usft Longitude: -151.2458107 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.08° Well Plan:KBU 31-18 Well Position i-NI-S 0.00 usft Northing: 2,356,031.00 usft • Latitude: 60.4431805 +EI-W 0.00 usft Easting: 275,397.00 usft • Longitude: -151.2436615 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: . 66.64 usft ltltelibore KBU 31-18 ,.---,.,,„,.,-,,,„,,,,,--,,,-,,m,, 'H'1IIIY,111,1,111 X1,1111, ,Efr*d�M A ,. F�32^kww - aR, "01,010h, Model Name Sample Date D k .0 .lp Angle ) �i)Field Strength 41111 ., - (')' ,11i�i til win iiIIIIIMIIIP1i BGGM2014 11/18/2015 16.41 73.43 55,295 a-- 14" '„',' KBU3118WP3 ''.®a _ VI iiNiiZ7iiii4r, i4.anm ... reiiiimubiiimnNi,,, mzaa iisr0oi a:y ,, Audit Notes: Version: Phase: PLAN Tie On Depth: 18.00 a. @n:11r2ttgr�:71aern6r iii. yd ;� _ Depth Fe. ® +N/-S ' +E/.4V Direction �r �' (usft} (usft) (usft) (°) 18.00 0.00 0.00 275.07 Plan Sections 1'r itRo•1 � r, .7, 11, 1l i`i ; ytsii r P(litiie Measured Vertical TVD Dogleg Build TOM Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face a"r') (°) O (usft) usft (usft) (usft) (°/100usft) (°I100usft) (°/1DOusft) (0) 18.00 0.00 0.00 18.00 -66.64 0.00 0.00 0.00 0.00 0.00 0.00 2,000.00 0.00 0.00 2,000.00 1,915.36 0.00 0.00 0.00 0.00 0.00 0.00 2,502.56 15.08 258.67 2,496.79 2,412.15 -12.92 -64.46 3.00 3.00 0.00 258.67 7,156.72 15.08 258.67 6,990.73 6,906.09 -250.74 -1,251.49 0.00 0.00 0.00 0.00 7,462.07 18.98 299.22 7,283.64 7,199.00 -234.24 -1,334.08 4.00 1.28 13.28 91.99 7,470.51 18.98 300.26 7,291.62 7,206.98 -232.88 -1,336.46 4.00 0.01 12.30 90.39 9,514.68 18.98 300.26 9,224.64 9,140.00 102.14 -1,910.75 0.00 0.00 0.00 0.00 10,000.00 18.98 300.26 9,683.58 9,598.94 181.68 -2,047.10 0.00 0.00 0.00 0.00 1/28/2015 2:39:57PM Page 2 COMPASS 5000.1 Build 70 • • Halliburton HALL!B V R ID j trJ Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 31-18 Company: Hilcorp Energy Company TVD Reference: Prelim:KBU 31-18 @ 84.64usft Project: Kenai Gas Field MD Reference: Prelim:KBU 31-18 @ 84.64usft Site: KGF 41-18 Pad North Reference: True Well: Plan:KBU 31-18 Survey Calculation Method: Minimum Curvature Wellbore: KBU 31-18 Design: KBU 31-18 WP3 Planned Survey 11 .; '' Measured VerticalMap, Map Depth Inclination Azimuth Depth TVDss +N/-S '' +E/-W Northing Easting DLS � Vert Section (usft) (0) (°) (usft) usft (usft) (usft) (usft) (usft) -66.64 18.00 0.00 0.00 18.00 -66.64 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 100.00 0.00 0.00 100.00 15.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 200.00 0.00 0.00 200.00 115.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 300.00 0.00 0.00 300.00 215.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 400.00 0.00 0.00 400.00 315.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 500.00 0.00 0.00 500.00 415.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 600.00 0.00 0.00 600.00 515.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 700.00 0.00 0.00 700.00 615.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 800.00 0.00 0.00 800.00 715.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 900.00 0.00 0.00 900.00 815.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 1,000.00 0.00 0.00 1,000.00 915.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 1,100.00 0.00 0.00 1,100.00 1,015.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 1,200.00 0.00 0.00 1,200.00 1,115.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 1,300.00 0.00 0.00 1,300.00 1,215.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 1,400.00 0.00 0.00 1,400.00 1,315.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 1,500.00 0.00 0.00 1,500.00 1,415.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 ,,10.3/44`I 1,600.00 0.00 0.00 1,600.00 1,515.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 1,700.00 0.00 0.00 1,700.00 1,615.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 1,800.00 0.00 0.00 1,800.00 1,715.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 1,900.00 0.00 0.00 1,900.00 1,815.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 2,000.00 0.00 • 0.00 2,000.00 1,915.36 0.00 0.00 2,356,031.00 275,397.00 0.00 0.00 Start Dir 3°/100':2000'MD,2000'TVD 2,100.00 3.00 258.67 2,099.95 2,015.31 -0.51 -2.57 2,356,030.53 275,394.42 3.00 2.51 2,200.00 6.00 258.67 2,199.63 2,114.99 -2.06 -10.26 2,356,029.14 275,386.70 3.00 10.04 2,300.00 9.00 258.67 2,298.77 2,214.13 -4.62 -23.06 2,356,026.82 275,373.86 3.00 22.56 2,400.00 12.00 258.67 2,397.08 2,312.44 -8.20 -40.92 2,356,023.58 275,355.93 3.00 40.04 2,500.00 15.00 258.67 2,494.31 2,409.67 -12.78 -63.81 2,356,019.42 275,332.96 3.00 62.43 2,502.56 15.08 258.67 2,496.78 2,412.14 -12.91 -64.46 2,356,019.31 275,332.31 3.00 63.07 End Dir :2503'MD,2497'TVD 2,600.00 15.08 258.67 2,590.87 2,506.23 -17.89 -89.31 2,356,014.80 275,307.37 0.00 87.38 2,700.00 15.08 258.67 2,687.42 2,602.78 -23.00 -114.82 2,356,010.17 275,281.77 0.00 112.33 2,800.00 15.08 258.67 2,783.98 2,699.34 -28.11 -140.32 2,356,005.54 275,256.18 0.00 137.29 2,900.00 15.08 258.67 2,880.54 2,795.90 -33.22 -165.83 2,356,000.91 275,230.58 0.00 162.24 3,000.00 15.08 258.67 2,977.10 2,892.46 -38.33 -191.33 2,355,996.29 275,204.99 0.00 187.19 3,100.00 15.08 258.67 3,073.65 2,989.01 -43.44 -216.84 2,355,991.66 275,179.39 0.00 212.15 3,200.00 15.08 258.67 3,170.21 3,085.57 -48.55 -242.34 2,355,987.03 275,153.80 0.00 237.10 3,300.00 15.08 258.67 3,266.77 3,182.13 -53.66 -267.85 2,355,982.41 275,128.20 0.00 262.05 3,400.00 15.08 258.67 3,363.33 3,278.69 -58.77 -293.35 2,355,977.78 275,102.61 0.00 287.01 3,500.00 15.08 258.67 3,459.89 3,375.25 -63.88 -318.85 2,355,973.15 275,077.01 0.00 311.96 3,600.00 15.08 258.67 3,556.44 3,471.80 -68.99 -344.36 2,355,968.52 275,051.41 0.00 336.91 3,700.00 15.08 258.67 3,653.00 3,568.36 -74.10 -369.86 2,355,963.90 275,025.82 0.00 361.86 3,800.00 15.08 258.67 3,749.56 3,664.92 -79.21 -395.37 2,355,959.27 275,000.22 0.00 386.82 3,900.00 15.08 258.67 3,846.12 3,761.48 -84.32 -420.87 2,355,954.64 274,974.63 0.00 411.77 4,000.00 15.08 258.67 3,942.67 3,858.03 -89.43 -446.38 2,355,950.01 274,949.03 0.00 436.72 1/28/2015 2:39:57PM Page 3 COMPASS 5000.1 Build 70 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 31-18 Company: Hilcorp Energy Company TVD Reference: Prelim:KBU 31-18 @ 84.64usft Project: Kenai Gas Field MD Reference: Prelim:KBU 31-18 @ 84.64usft Site: KGF 41-18 Pad North Reference: True Well: Plan:KBU 31-18 Survey Calculation Method: Minimum Curvature Wellbore: KBU 31-18 Design: KBU 31-18 WP3 i a x r Planned Sura ( Measured Vertical Map Map' 9w 1 1,1' Depth Inclination Azimuth Depth TVDss +N/-S +E1-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,893.00 4,036.21 15.08 258.67 3,977.64 3,893.00 -91.28 -455.61 2,355,948.34 274,939.76 0.00 445.76 Sterling 4,100.00 15.08 258.67 4,039.23 3,954.59 -94.54 -471.88 2,355,945.39 274,923.44 0.00 461.68 4,200.00 15.08 258.67 4,135.79 4,051.15 -99.65 -497.39 2,355,940.76 274,897.84 0.00 486.63 4,300.00 15.08 258.67 4,232.35 4,147.71 -104.76 -522.89 2,355,936.13 274,872.25 0.00 511.58 4,308.59 15.08 258.67 4,240.64 4,156.00 -105.20 -525.08 2,355,935.73 274,870.05 0.00 513.73 Sterling 5.2 4,400.00 15.08 258.67 4,328.91 4,244.27 -109.87 -548.40 2,355,931.50 274,846.65 0.00 536.54 4,500.00 15.08 258.67 4,425.46 4,340.82 -114.98 -573.90 2,355,926.88 274,821.05 0.00 561.49 4,600.00 15.08 258.67 4,522.02 4,437.38 -120.09 -599.41 2,355,922.25 274,795.46 0.00 586.44 4,607.89 15.08 258.67 4,529.64 4,445.00 -120.50 -601.42 2,355,921.89 274,793.44 0.00 588.41 Sterling Pool 6 4,700.00 15.08 258.67 4,618.58 4,533.94 -125.20 -624.91 2,355,917.62 274,769.86 0.00 611.40 4,800.00 15.08 258.67 4,715.14 4,630.50 -130.31 -650.42 2,355,913.00 274,744.27 0.00 636.35 4,862.66 15.08 258.67 4,775.64 4,691.00 -133.52 -666.40 2,355,910.10 274,728.23 0.00 651.99 Upper Beluga 4,900.00 15.08 258.67 4,811.69 4,727.05 -135.42 -675.92 2,355,908.37 274,718.67 0.00 661.30 5,000.00 15.08 258.67 4,908.25 4,823.61 -140.53 -701.43 2,355,903.74 274,693.08 0.00 686.26 5,100.00 15.08 258.67 5,004.81 4,920.17 -145.64 -726.93 2,355,899.11 274,667.48 0.00 711.21 5,200.00 15.08 258.67 5,101.37 5,016.73 -150.75 -752.44 2,355,894.49 274,641.88 0.00 736.16 5,300.00 15.08 258.67 5,197.93 5,113.29 -155.86 -777.94 2,355,889.86 274,616.29 0.00 761.12 5,400.00 15.08 258.67 5,294.48 5,209.84 -160.97 -803.44 2,355,885.23 274,590.69 0.00 786.07 5,500.00 15.08 258.67 5,391.04 5,306.40 -166.08 -828.95 2,355,880.60 274,565.10 0.00 811.02 5,524.44 15.08 258.67 5,414.64 5,330.00 -167.33 -835.18 2,355,879.47 274,558.84 0.00 817.12 Middle Beluga 5,600.00 15.08 258.67 5,487.60 5,402.96 -171.19 -854.45 2,355,875.98 274,539.50 0.00 835.97 5,700.00 15.08 258.67 5,584.16 5,499.52 -176.30 -879.96 2,355,871.35 274,513.91 0.00 860.93 5,800.00 15.08 258.67 5,680.71 5,596.07 -181.41 -905.46 2,355,866.72 274,488.31 0.00 885.88 5,900.00 15.08 258.67 5,777.27 5,692.63 -186.52 -930.97 2,355,862.10 274,462.72 0.00 910.83 6,000.00 15.08 258.67 5,873.83 5,789.19 -191.63 -956.47 2,355,857.47 274,437.12 0.00 935.79 6,100.00 15.08 258.67 5,970.39 5,885.75 -196.74 -981.98 2,355,852.84 274,411.52 0.00 960.74 6,200.00 15.08 258.67 6,066.94 5,982.30 -201.85 -1,007.48 2,355,848.21 274,385.93 0.00 985.69 6,279.43 15.08 258.67 6,143.64 6,059.00 -205.91 -1,027.74 2,355,844.54 274,365.60 0.00 1,005.51 Lower Beluga 6,300.00 15.08 258.67 6,163.50 6,078.86 -206.96 -1,032.99 2,355,843.59 274,360.33 0.00 1,010.65 6,400.00 15.08 258.67 6,260.06 6,175.42 -212.07 -1,058.49 2,355,838.96 274,334.74 0.00 1,035.60 6,500.00 15.08 258.67 6,356.62 6,271.98 -217.18 -1,084.00 2,355,834.33 274,309.14 0.00 1,060.55 7 5/8" 6,600.00 15.08 258.67 6,453.18 6,368.54 -222.29 -1,109.50 2,355,829.70 274,283.55 0.00 1,085.51 6,700.00 15.08 258.67 6,549.73 6,465.09 -227.40 -1,135.01 2,355,825.08 274,257.95 0.00 1,110.46 6,800.00 15.08 258.67 6,646.29 6,561.65 -232.51 -1,160.51 2,355,820.45 274,232.36 0.00 1,135.41 6,900.00 15.08 258.67 6,742.85 6,658.21 -237.62 -1,186.02 2,355,815.82 274,206.76 0.00 1,160.37 7,000.00 15.08 258.67 6,839.41 6,754.77 -242.73 -1,211.52 2,355,811.19 274,181.16 0.00 1,185.32 7,100.00 15.08 258.67 6,935.96 6,851.32 -247.84 -1,237.03 2,355,806.57 274,155.57 0.00 1,210.27 7,156.72 15.08 258.67 6,990.73 6,906.09 -250.74 -1,251.49 2,355,803.94 274,141.05 0.00 1,224.43 Start Dir 4°1100':7157'MD,6991'TVD 1/28/2015 2:39:57PM Page 4 COMPASS 5000.1 Build 70 / v ■ • • Halliburton HALLIBU °• T.ON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 31-18 Company: Hilcorp Energy Company TVD Reference: Prelim:KBU 31-18 @ 84.64usft Project: Kenai Gas Field MD Reference: Prelim:KBU 31-18 @ 84.64usft Site: KGF 41-18 Pad North Reference: True Well: Plan:KBU 31-18Survey Calculation Method Minimum Curvature Wellbore: KBU 31-18 Design: KBU 31-18 WP3 ii r7ulluiminiinrr _ - Planned Survey.: ,� -... rvugxrµ fi�I7 P� � a"°;; s-s,� �11,,i�0 i IIS Measured Vertical Map Map �Ir : t��' Depthr Inclination Azimuth Depth TVDss +NI-S +BMW Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,947.88 7,200.00 15.11 265.32 7,032.52 6,947.88 -252.31 -1,262.63 2,355,802.59 274,129.88 4.00 1,235.39 7,300.00 15.92 280.01 7,128.91 7,044.27 -250.99 -1,289.14 2,355,804.41 274,103.40 4.00 1,261.91 7,400.00 17.60 292.64 7,224.70 7,140.06 -242.78 -1,316.61 2,355,813.13 274,076.10 4.00 1,289.99 7,462.07 18.98 299.22 7,283.64 7,199.00 -234.24 -1,334.08 2,355,822.00 274,058.79 4.00 1,308.15 Upper Tyonek 7,470.51 18.98 300.26 7,291.62 7,206.98 -232.88 -1,336.46 2,355,823.41 274,056.43 4.00 1,310.64 End Dir :7471'MD,7292'TVD 7,500.00 18.98 300.26 7,319.50 7,234.86 -228.05 -1,344.75 2,355,828.39 274,048.24 0.00 1,319.32 7,600.00 18.98 300.26 7,414.07 7,329.43 -211.66 -1,372.84 2,355,845.31 274,020.46 0.00 1,348.76 7,700.00 18.98 300.26 7,508.63 7,423.99 -195.27 -1,400.94 2,355,862.23 273,992.69 0.00 1,378.19 7,800.00 18.98 300.26 7,603.19 7,518.55 -178.88 -1,429.03 2,355,879.14 273,964.91 0.00 1,407.62 7,900.00 18.98 300.26 7,697.76 7,613.12 -162.49 -1,457.12 2,355,896.06 273,937.13 0.00 1,437.06 8,000.00 18.98 300.26 7,792.32 7,707.68 -146.10 -1,485.22 2,355,912.97 273,909.35 0.00 1,466.49 8,100.00 18.98 300.26 7,886.88 7,802.24 -129.71 -1,513.31 2,355,929.89 273,881.57 0.00 1,495.92 8,200.00 18.98 300.26 7,981.44 7,896.80 -113.32 -1,541.41 2,355,946.80 273,853.79 0.00 1,525.35 8,300.00 18.98 300.26 8,076.01 7,991.37 -96.94 -1,569.50 2,355,963.72 273,826.02 0.00 1,554.79 8,400.00 18.98 300.26 8,170.57 8,085.93 -80.55 -1,597.59 2,355,980.63 273,798.24 0.00 1,584.22 8,500.00 18.98 300.26 8,265.13 8,180.49 -64.16 -1,625.69 2,355,997.55 273,770.46 0.00 1,613.65 8,600.00 18.98 300.26 8,359.70 8,275.06 -47.77 -1,653.78 2,356,014.47 273,742.68 0.00 1,643.08 8,700.00 18.98 300.26 8,454.26 8,369.62 -31.38 -1,681.88 2,356,031.38 273,714.90 0.00 1,672.52 8,800.00 18.98 300.26 8,548.82 8,464.18 -14.99 -1,709.97 2,356,048.30 273,687.12 0.00 1,701.95 8,900.00 18.98 300.26 8,643.38 8,558.74 1.40 -1,738.06 2,356,065.21 273,659.35 0.00 1,731.38 9,000.00 18.98 300.26 8,737.95 8,653.31 17.79 -1,766.16 2,356,082.13 273,631.57 0.00 1,760.82 9,034.57 18.98 300.26 8,770.64 8,686.00 23.45 -1,775.87 2,356,087.98 273,621.96 0.00 1,770.99 Tyonek D1 9,100.00 18.98 300.26 8,832.51 8,747.87 34.18 -1,794.25 2,356,099.04 273,603.79 0.00 1,790.25 9,200.00 18.98 300.26 8,927.07 8,842.43 50.56 -1,822.35 2,356,115.96 273,576.01 0.00 1,819.68 9,227.04 18.98 300.26 8,952.64 8,868.00 55.00 -1,829.94 2,356,120.53 273,568.50 0.00 1,827.64 Tyonek D2 9,300.00 18.98 300.26 9,021.64 8,937.00 66.95 -1,850.44 2,356,132.88 273,548.23 0.00 1,849.11 9,400.00 18.98 300.26 9,116.20 9,031.56 83.34 -1,878.53 2,356,149.79 273,520.46 0.00 1,878.55 9,500.00 18.98 300.26 9,210.76 9,126.12 99.73 -1,906.63 2,356,166.71 273,492.68 0.00 1,907.98 9,514.68 18.98 300.26 9,224.64 9,140.00 102.14 -1,910.75 2,356,169.19 273,488.60 0.00 1,912.30 Tyonek D3B 9,600.00 18.98 300.26 9,305.32 9,220.68 116.12 -1,934.72 2,356,183.62 273,464.90 0.00 1,937.41 9,682.82 18.98 300.26 9,383.64 9,299.00 129.69 -1,957.99 2,356,197.63 273,441.89 0.00 1,961.79 Tyonek D4 9,700.00 18.98 300.26 9,399.89 9,315.25 132.51 -1,962.81 2,356,200.54 273,437.12 0.00 1,966.84 9,800.00 18.98 300.26 9,494.45 9,409.81 148.90 -1,990.91 2,356,217.45 273,409.34 0.00 1,996.28 9,900.00 18.98 300.26 9,589.01 9,504.37 165.29 -2,019.00 2,356,234.37 273,381.56 0.00 2,025.71 • 10,000.00 18.98 300.26 9,683.58 • 9,598.94 181.68 -2,047.10 2,356,251.29 273,353.79 0.00 2,055.14 1/28/2015 2:39:57PM Page 5 COMPASS 5000.1 Build 70 • • Halliburton HALLIBURTDN Standard Proposal Report ,- - w� Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 31-18 Company: Hilcorp Energy Company TVD Reference: Prelim:KBU 31-18 @ 84.64usft Project: Kenai Gas Field MD Reference: Prelim:KBU 31-18 @ 84.64usft Site: KGF 41-18 Pad North Reference: ,, True Well: Plan:KBU 31-18 Survey Calculation Method:i, Minimum Curvature Wellbore: KBU 31-18 Design: KBU 31-18 WP3 wr= . Ri 7p . "x )Y a �.11i i ��l •-i .,,- Targets i9 Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E1-WNorthing�� Easting 1 -Shape (°) (°) (usft) (usft) ( (usft) (usft) (usft) KBU 31-18 BHL 0.00 0.00 9,662.64 224.24 -2,013.38 2,356,293.20 273,388.30 -plan misses target center by 53.75usft at 9977.71usft MD(9662.49 TVD,178.02 N,-2040.83 E) -Circle(radius 100.00) KBU 31-18 tgtl 0.00 0.00 7,275.64 -234.18 -1,330.87 2,355,822.00 274,062.00 -plan misses target center by 1.60usft at 7453.58usft MD(7275.60 TVD,-235.56 N,-1331.67 E) -Circle(radius 100.00) KBU 31-18 tgt2 wp3 0.00 0.00 9,224.64 102.14 -1,910.75 2,356,169.19 273,488.60 -plan hits target center -Circle(radius 100.00) KBU 31-18 tgtl wp3 0.00 0.00 7,283.64 -234.24 -1,334.08 2,355,822.00 274,058.79 -plan hits target center -Circle(radius 100.00) KBU 31-18 tgt2 0.00 0.00 9,224.64 101.95 -1,910.35 2,356,169.00 273,489.00 -plan misses target center by 0.42usft at 9514.53usft MD(9224.50 TVD,102.11 N,-1910.71 E) -Circle(radius 100.00) Casing Polo ..r-r Measured Vertical - ,T1 g Depth Depth a ,-. +� 01: ' (usft) (usft) ' i ,11 �Vn 1,500.00 1,500.00 .10 3/4" 10-3/4 12-1/4 6,500.00 6,356.62 7 5/8" 7-5/8 9-7/8 10,000.00 9,683.58 5" 5 6-3/4 Formations .-i-77-Ur-1-r.liiiiiii 7i(i Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft)_ Name Lithology (°) 5,524.44 5,414.64 Middle Beluga , 9,682.82 9,383.64 Tyonek D4 9,227.04 8,952.64 Tyonek D2 4,607.89 4,529.64 Sterling Pool 6 9,034.57 8,770.64 Tyonek D1 6,279.43 6,143.64 Lower Beluga 4,036.21 3,977.64 Sterling 4,308.59 4,240.64 Sterling 5.2 9,514.68 9,224.64 Tyonek D3B 7,462.07 7,283.64 Upper Tyonek 4,862.66 4,775.64 Upper Beluga 1/28/2015 2:39:57PM Page 6 COMPASS 5000.1 Build 70 • • Halliburton HALLIBURTO11i1 Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 31-18 Company: Hilcorp Energy Company TVD Reference: Prelim:KBU 31-18 @ 84.64usft Project: Kenai Gas Field MD Reference: Prelim:KBU 31-18 @ 84.64usft Site: KGF 41-18 Pad North Reference: True Well: Plan:KBU 31-18 Survey Calculation Method: Minimum Curvature Wellbore: KBU 31-18 �> Design: � KBU 31-18 WP3 gillGl1,1niii11,11i 9MTITIITIIIMEM.,-7,---= ' ---='.-- _ o � Plan Annotations Measured Vertical` Local Coordinates ',I,'� _ Depth Depth +N/-5 ,,„ +E/-W Cg �— (usft) (usft) - As`:(usft) (usft) Comment, I? — 2,000.00 2,000.00 0.00 0.00 Start Dir 3°/100':2000'MD,2000'TVD 2,502.56 2,496.78 -12.91 -64.46 End Dir :2503'MD,2497'TVD 7,156.72 6,990.73 -250.74 -1,251.49 Start Dir 4°/100':7157'MD,6991'TVD 7,470.51 7,291.62 -232.88 -1,336.46 End Dir :7471'MD,7292'TVD 10,000.00 9,683.58 181.68 -2,047.10 Total Depth:10000'MD,9684'ND 1/28/2015 2:39:57PM Page 7 COMPASS 5000.1 Build 70 OR 0 i Hilcorp Energy Company Kenai Gas Field KGF 41-18 Pad 01 1 / Plan: KBU 31-18 KBU 31-18 "r- Ill KBU 31-18 WP3 Sperry Drilling Services Clearance Summary Anticollision Report 28 January,2015 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: KGF 41.18 Pad-Plan:KBU 31-18-KBU 31-18-KBU 31-18 WP3 Well Coordinates:2,356,031.00 N,275,397.00 E(60°26'35.45"N,151°14'37.18"W) Datum Height: Prelim:KBU 31-18 @ 84.64usft Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff Is Unlimited.Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied ii Version: 5000.1 Build: 70 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 HALLIBURTON S; Sperry Drilling Services • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18-KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: KGF 41-18 Pad-Plan:KBU 31-18-KBU 31.18-KBU 31-18 WP3 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft KGF 41-18 Pad KBU 11-17X-KBU 11-17X-KBU 11-17X 2,119.06 241.18 2,119.06 231.38 2,128.33 24.613 Centre Distance Pass- KBU t1-17X-KBU 11-17X-KBU 11-17X 2,150.00 241.28 2,150.00 231.35 2,159.25 24.291 Ellipse Separation Pass- KBU 11-17X-KBU 11-17X-KBU 11-17X 2,475.00 255.18 2,475.00 243.72 2,486.65 22.252 Clearance Factor Pass- KBU 13-8-KBU 13-8-KBU 13-8 1,494.62 169.67 1,494.62 160.55 1,549.49 18.600 Centre Distance Pass- KBU 13-8-KBU 13-8-KBU 13-8 1,500.00 169.69 1,500.00 160.46 1,554.28 18.395 Ellipse Separation Pass- KBU 13-8-KBU 13-8-KBU 13-8 1,775.00 229.49 1,775.00 211.21 1,777.00 12.557 Clearance Factor Pass- KBU 14-8-KBU 14-8-KBU 14-8 164.39 260.20 164.39 258.73 167.75 177.063 Centre Distance Pass- KBU 14-8-KBU 14-8-KBU 14-8 225.00 260.33 225.00 258.59 227.23 150.207 Ellipse Separation Pass- KBU 14-8-KBU 14-8-KBU 14-8 2,000.00 300.94 2,000.00 291.56 1,963.64 32.075 Clearance Factor Pass- KBU 32-08-KBU 32-08-KBU 32-08 411.18 152.60 411.18 150.14 411.80 62.143 Centre Distance Pass- KBU 32-08-KBU 32-08-KBU 32-08 450.00 152.69 450.00 150.07 449.92 58.278 Ellipse Separation Pass- KBU 32-08-KBU 32-08-KBU 32-08 950.00 189.89 950.00 184.99 914.79 38.769 Clearance Factor Pass- KBU 41-18X-KBU 41-18X-KBU 41-18X 2,463.00 263.09 2,463.00 251.82 2,456.63 23.341 Centre Distance Pass- KBU 41-18X-KBU 41-18X-KBU 41-18X 2,475.00 263.12 2,475.00 251.79 2,467.63 23.223 Ellipse Separation Pass- KBU 41-18X-KBU 41-18X-KBU 41-18X 2,750.00 281.72 2,750.00 268.89 2,714.93 21.953 Clearance Factor Pass- KBU 43-07Y-KBU 43-07Y-KBU 43-07Y 18.00 56.76 18.00 55.80 18.60 59.206 Centre Distance Pass- KBU 43-07Y-KBU 43-07Y-KBU 43-07Y 50.00 56.79 50.00 55,76 50.51 55.114 Ellipse Separation Pass- KBU 43-07Y-KBU 43-07Y-KBU 43-07Y 625.00 76.92 625.00 73.47 618.02 22.288 Clearance Factor Pass- KU 11-17-KU 11-17-KU 11-17 1,361.23 43.56 1,361.23 34.44 1,396.47 4.774 Centre Distance Pass- KU 11-17-KU 11-17-KU 11-17 1,375.00 43.97 1,375.00 34.32 1,408.93 4.559 Ellipse Separation Pass- KU 11-17-KU 11-17-KU 11-17 1,425.00 51.69 1,425.00 39.42 1,453.77 4.213 Clearance Factor Pass- KU 13-8-KU 13-8-KU 13-8 MIN _ - _ - KU 13-8-KU 13-8-KU 13-8 - - - IIIIIIII KU 13-8-KU 13-8-KU 13-8 KU 41-18-KU 41-18-KU 41-18 3,293.60 147.05 3,293.60 18.36 3,273.95 1.143 Centre Distance Pass- KU 41-18-KU 41-18-KU 41-18 3,375.00 148.57 3,375.00 16.44 3,352.55 1.124 Ellipse Separation Pass- KU 41-18-KU 41-18-KU 41-18 3,400.00 149.63 3,400.00 16.50 3,376.69 1.124 Clearance Factor Pass- All KGF 41-7 Pad 28 January,2015- 19:41 Page 2 of 5 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18-KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: KGF 41-18 Pad-Plan:KBU 31-18-KBU 31-18-KBU 31-18 WP3 Scan Range:0.80 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Plan:KBU 32-07-KBU 32-07-KBU 32-07 WP1.0 1,490.80 165.26 1,490.80 157.86 1,493.16 22.341 Ellipse Separation Pass- Plan:KBU 32-07-KBU 32-07-KBU 32-07 WP1.0 1,850.00 175.76 1,850.00 167.59 1,842.10 21.505 Clearance Factor Pass- Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 18.00 10,000.00 KBU 31-18 WP3 MWD+SC+sag Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 28 January,2015-19:41 Page 3 of 5 COMPASS • 0 Hilcorp Energy Company H A LLI B U RTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18-KBU 31-18 WP3 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Prelim:KBU 31-18 @ 84.84usft. Northing and Easting are relative to KGF 41-18 Pad. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00°,Grid Convergence at Surface is:-1.08°. Ladder Plot A C I 'I I • 1 •,' l ik �, 1050 P / a, 1 o q Ii / LEGEND ('7 -- ------ --- -- ---�P- .i -- I. /A cv P� ♦ KBU 11-17X,KBU 11-17X,KBU 11-17X VO O ,� �� /. p -�- KBU 138,KBU 138,KBU 138VO 2 700 ^ ,, 1 �� t -9-KBU 14-8,KBU 14-8,KBU 14-8 VO O- NF KBU 32-08,KBU 32-08,KBU 32-08 VO a) 1 , IP 4 r p 1fi, I , KBU41-18X,KBU41-18X,KBU41-18XVO N ♦-KBU 43-07Y,KBU 43-07Y,KBU 43-07YV0 Pj �i c P KU11-17,KU11-17,KU11-17V0 N „ ' / �, -KU138,KU138,KU13�VO v 350 ,,' ., / y 0 'J �� ,`, ,- U32 U32-07WP1AV0 � fG �.. �r� -�Plan: -07,K6 ,_ ...." ,.r � $KBU 31-18VuP3 a) -.1;-=A--Itt--V--'4, •tin iU 0 iI 0 1500 et: 4500 6000 7500 Measured Depth(1500 usft/in) 28 January,2015- 19:41 Page 4 of 5 COMPASS ill III Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18-KBU 31-18 WP3 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor 10.00- 8.75— 7.50- . .... .__ .. .... --- LEGEND C ` '----- • -- $KBU11-17X,KBU11-17X,KBU11-17XVO Ir 6.25- -',.. - - -- --- - _�__—. J ;_. _ KBU 13-8,KBU 13-8,KBU 13-8 V0 o , - _ - • $KBU 14-8,KBU 14-S,KBU 14-B VO -- -- -K-KBU32-08,KBU32-08,KBU32-08V0 0 5.00 •-- ---- i- - - _________-_ -♦KBU41-18X,KBU41-18X,KBU41-18XVO .. -0-KBU 43-07Y,KBU 43-07Y,KBU 43-07YV0 a • a., I -N-KU11-17,KU11 17,KU11-17V0 4E-KU 13-8,KU 13-8,KU 13-8 VO -4'-KU41-18,KU41-18,KU41-18V0 2.50-- .... `� . . .. . - . .. • ._._. -6-Plan:KBU 32-07,KBU 32-07,KBU 32-07WP1.0V0 —Collision Zone-St pDnllingnce Re4 _ u _ -- $KBU31-18WP3 1.25— 0.00 II 1111 1 l I I 1 1 1 1111 1 1 1 1 1 I 1111 I i 1 1 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 Mued Depth(1500 usWin) 28 January,2015- 19:41 Page 5 of 5 COMPASS • • Hilcorp Energy Company Kenai Gas Field KGF 41-18 Pad Plan: KBU 31-18 KBU 31-18 KBU 31-18 WP3 a I 41 Sperry Drilling Services Anticollision Report 28 January,2015 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: KGF 41-18 Pad•Plan:KBU 31-18-KBU 31-18-KBU 31-18 WP3 Well Coordinates: 2,356,031.00 N,275,397.00 E(60°26'35.45"N,151.14'37.18"W) Datum Height: Prelim:KBU 31-18 @ 84.64usft Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build:70 Scan Type: NO GLOBAL FILTER:Using user defined selection&filtering criteria Interpolation Interval: 25.00 ppN = HALLIBURTON • 0 Hilcorp Energy Company HALLI BU RTO N Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 18.00 18.00 0.00 98.00 84.64 0.00 315.88 0.96 314.92 -129.77 -129.77 329.475 Pass- 25.00 25.00 0.01 98.00 84.64 0.00 314.48 0.97 313.51 -129.77 -129.77 325.349 Pass- 50.00 50.00 0.04 98.00 84.64 0.00 310.71 0.99 309.71 -129.77 -129.77 312.388 Pass- 75.00 75.00 0.06 98.00 84.64 0.00 308.92 1.02 307.90 -129.77 -129.77 302.077 Pass- 88.56 88.56 0.08 101.92 88.56 0.08 308.77 1.12 307.65 -129.77 -129.77 276.590 Pass- 100.00 100.00 0.09 113.36 100.00 0.31 308.77 1.36 307.41 -129.77 -129.77 227.391 Pass- 125.00 125.00 0.15 138.36 125.00 0.81 308.77 1.91 306.85 -129.77 -129.77 161.316 Pass- 150.00 150.00 0.20 163.36 150.00 1.31 308.77 2.47 306.30 -129.77 -129.77 124.996 Pass- 175.00 175.00 0.26 188.36 175.00 1.81 308.77 3.03 305.74 -129.77 -129.77 102.025 Pass- 200.00 200.00 0.32 213.36 200.00 2.31 308.77 3.58 305.19 -129.77 -129.77 86.186 Pass- 225.00 225.00 0.37 238.36 225.00 2.81 308.77 4.14 304.63 -129.77 -129.77 74.604 Pass- 250.00 250.00 0.43 263.36 250.00 3.31 308.77 4.69 304.07 -129.77 -129.77 65.766 Pass- 275.00 275.00 0.49 288.36 275.00 3.81 308.77 5.25 303.52 -129.77 -129.77 58.800 Pass- 300.00 300.00 0.54 313.36 300.00 4.31 308.77 5.81 302.96 -129.77 -129.77 53.169 Pass- 325.00 325.00 0.60 338.36 325.00 4.81 308.77 6.36 302.41 -129.77 -129.77 48.522 Pass- 350.00 350.00 0.65 363.36 350.00 5.31 308.77 6.92 301.85 -129.77 -129.77 44.622 Pass- 375.00 375.00 0.71 388.36 375.00 5.81 308.77 7.48 301.29 -129.77 -129.77 41.302 Pass- 400.00 400.00 0.77 413.36 400.00 6.31 308.77 8.03 300.74 -129.77 -129.77 38.442 Pass- 425.00 425.00 0.82 438.36 425.00 6.81 308.77 8.59 300.18 -129.77 -129.77 35.953 Pass- 450.00 450.00 0.88 463.36 450.00 7.31 308.77 9.14 299.62 -129.77 -129.77 33.766 Pass- 475.00 475.00 0.94 488.36 475.00 7.81 308.77 9.70 299.07 -129.77 -129.77 31.830 Pass- 500.00 500.00 0.99 513.36 500.00 8.57 308.77 10.52 298.24 -129.77 -129.77 29.340 Pass- 525.00 525.00 1.05 538.36 525.00 9.57 308.77 11.58 297.19 -129.77 -129.77 26.664 Pass- 550.00 550.00 1.10 563.36 550.00 10.57 308.77 12.64 296.13 -129.77 -129.77 24.435 Pass- 575.00 575.00 1.16 588.36 575.00 11.57 308.77 13.69 295.08 -129.77 -129.77 22.550 Pass- 600.00 600.00 1.22 613.36 600.00 12.57 308.77 14.75 294.02 -129.77 -129.77 20.935 Pass- 625.00 625.00 1.27 638.36 625.00 13.57 308.77 15.80 292.96 -129.77 -129.77 19.536 Pass- 650.00 650.00 1.33 663.36 650.00 14.57 308.77 16.86 291.91 -129.77 -129.77 18.312 Pass- 675.00 675.00 1.38 688.36 675.00 15.57 308.77 17.92 290.85 -129.77 -129.77 17.233 Pass- 700.00 700.00 1.44 713.36 700.00 16.57 308.77 18.97 289.80 -129.77 -129.77 16.274 Pass- 725.00 725.00 1.50 738.36 725.00 17.57 308.77 20.03 288.74 -129.77 -129.77 15.416 Pass- 28 January,2015-20:14 Page 2 of 22 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 750.00 750.00 1.55 763.36 750.00 18.57 306.77 21.09 287.68 -129.77 -129.77 14.643 Pass- 775.00 775.00 1.61 788.36 775.00 19.57 306.77 22.14 286.63 -129.77 -129.77 13.945 Pass- 800.00 800.00 1.67 813.36 800.00 20.57 306.77 23.20 285.57 -129.77 -129.77 13.310 Pass- 825.00 825.00 1.72 838.36 825.00 21.57 308.77 24.25 284.51 -129.77 -129.77 12.730 Pass- 850.00 850.00 1.78 863.36 850.00 22.57 308.77 25.31 283.46 -129.77 -129.77 12.199 Pass- 875.00 875.00 1.83 888.36 675.00 23.57 308.77 26.37 282.40 -129.77 -129.77 11.710 Pass- 900.00 900.00 1.89 913.36 900.00 24.57 308.77 27.42 281.35 -129.77 -129.77 11.259 Pass- 925.00 925.00 1.95 938.36 925.00 25.57 308.77 28.48 280.29 -129.77 -129.77 10.842 Pass- 950.00 950.00 2.00 963.36 950.00 26.57 308.77 29.54 279.23 -129.77 -129.77 10.454 Pass- 975.00 975.00 2.06 988.36 975.00 27.57 306.77 30.59 278.18 -129.77 -129.77 10.093 Pass- 1,000.00 1,000.00 2.12 1,013.36 1,000.00 28.57 308.77 31.65 277.12 -129.77 -129.77 9.756 Pass- 1,025.00 1,025.00 2.17 1,038.36 1,025.00 29.57 308.77 32.70 276.06 -129.77 -129.77 9.441 Pass- 1,050.00 1,050.00 2.23 1,063.36 1,050.00 30.57 308.77 33.76 275.01 -129.77 -129.77 9.146 Pass- 1,075.00 1,075.00 2.28 1,088.36 1,075.00 31.57 308.77 34.82 273.95 -129.77 -129.77 8.868 Pass- 1,100.00 1,100.00 2.34 1,113.36 1,100.00 32.57 308.77 35.87 272.90 -129.77 -129.77 8.607 Pass- 1,125.00 1,125.00 2.40 1,138.36 1,125.00 33.57 308.77 36.93 271.84 -129.77 -129.77 8.361 Pass- 1,150.00 1,150.00 2.45 1,163.36 1,150.00 34.57 308.77 37.98 270.78 -129.77 -129.77 8.129 Pass- 1,175.00 1,175.00 2.51 1,188.36 1,175.00 35.57 308.77 39.04 269.73 -129.77 -129.77 7.909 Pass- 1,200.00 1,200.00 2.56 1,213.36 1,200.00 36.57 308.77 40.10 268.67 -129.77 -129.77 7.700 Pass- 1,225.00 1,225.00 2.62 1,238.36 1,225.00 37.57 308.77 41.15 267.62 -129.77 -129.77 7.503 Pass- 1,250.00 1,250.00 2.68 1,263.36 1,250.00 38.57 308.77 42.21 266.56 -129.77 -129.77 7.315 Pass- 1,275.00 1,275.00 2.73 1,288.36 1,275.00 39.57 308.77 43.27 265.50 -129.77 -129.77 7.137 Pass- 1,300.00 1,300.00 2.79 1,313.36 1,300.00 40.57 308.77 44.32 264.45 -129.77 -129.77 6.966 Pass- 1,325.00 1,325.00 2.85 1,338.36 1,325.00 41.57 308.77 45.38 263.39 -129.77 -129.77 6.804 Pass- 1,350.00 1,350.00 2.90 1,363.36 1,350.00 42.57 308.77 46.43 262.33 -129.77 -129.77 6.650 Pass- 1,375.00 1,375.00 2.96 1,388.36 1,375.00 43.57 308.77 47.49 261.28 -129.77 -129.77 6.502 Pass- 1,400.00 1,400.00 3.01 1,413.36 1,400.00 44.57 308.77 48.55 260.22 -129.77 -129.77 6.360 Pass- 1,425.00 1,425.00 3.07 1,438.36 1,425.00 45.57 308.77 49.60 259.17 -129.77 -129.77 6.225 Pass- 1,450.00 1,450.00 3.13 1,463.36 1,450.00 46.57 308.77 50.66 258.11 -129.77 -129.77 6.095 Pass- 1,475.00 1,475.00 3.18 1,488.36 1,475.00 47.57 308.77 51.72 257.05 -129.77 -129.77 5.971 Pass- 1,500.00 1,500.00 3.24 1,513.36 1,500.00 48.57 308.77 52.77 256.00 -129.77 -129.77 5.851 Pass- 1,525.00 1,525.00 3.27 1,538.36 1,525.00 49.57 308.77 53.57 255.20 -129.77 -129.77 5.764 Pass- 28 January,2015-20:14 Page 3 of 22 COMPASS III • Hilcorp Energy Company HALLI B U RTO N Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,199.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 1,550.00 1,550.00 3.30 1,563.36 1,550.00 50.57 308.77 54.60 254.17 -129.77 -129.77 5.655 Pass- 1,575.00 1,575.00 3.32 1,588.36 1,575.00 51.57 308.77 55.63 253.14 -129.77 -129.77 5.551 Pass- 1,600.00 1,600.00 3.35 1,613.36 1,600.00 52.57 308.77 56.66 252.11 -129.77 -129.77 5.450 Pass- 1,625.00 1,625.00 3.36 1,638.36 1,625.00 53.57 308.77 57.66 251.11 -129.77 -129.77 5.355 Pass- 1,650.00 1,650.00 3.36 1,663.36 1,650.00 54.57 308.77 58.66 250.10 -129.77 -129.77 5.263 Pass- 1,675.00 1,675.00 3.36 1,688.36 1,675.00 55.57 308.77 59.67 249.10 -129.77 -129.77 5.175 Pass- 1,700.00 1,700.00 3.37 1,713.36 1,700.00 56.57 308.77 60.67 248.10 -129.77 -129.77 5.089 Pass- 1,725.00 1,725.00 3.38 1,738.36 1,725.00 57.57 308.77 61.68 247.09 -129.77 -129.77 5.006 Pass- 1,750.00 1,750.00 3.38 1,763.36 1,750.00 58.57 308.77 62.69 246.08 -129.77 -129.77 4.926 Pass- 1,775.00 1,775.00 3.39 1,788.36 1,775.00 59.57 308.77 63.69 245.07 -129.77 -129.77 4.848 Pass- 1,800.00 1,800.00 3.40 1,813.36 1,800.00 60.57 308.77 64.70 244.07 -129.77 -129.77 4.772 Pass- 1,825.00 1,825.00 3.41 1,838.36 1,825.00 61.57 308.77 65.71 243.06 -129.77 -129.77 4.699 Pass- 1,850.00 1,850.00 3.42 1,863.36 1,850.00 62.57 308.77 66.72 242.04 -129.77 -129.77 4.628 Pass- 1,875.00 1,675.00 3.43 1,888.36 1,875.00 63.57 308.77 67.73 241.03 -129.77 -129.77 4.558 Pass- 1,900.00 1,900.00 3.44 1,913.36 1,900.00 64.57 308.77 68.75 240.02 -129.77 -129.77 4.491 Pass- 1,925.00 1,925.00 3.46 1,938.36 1,925.00 65.57 308.77 69.76 239.01 -129.77 -129.77 4.426 Pass- 1,950.00 1,950.00 3.47 1,963.36 1,950.00 66.57 306.77 70.78 237.99 -129.77 -129.77 4.363 Pass- 1,975.00 1,975.00 3.49 1,988.36 1,975.00 67.57 308.77 71.79 236.98 -129.77 -129.77 4.301 Pass- 2,000.00 2,000.00 3.50 2,013.36 2,000.00 68.57 308.77 72.80 235.96 -129.77 -129.77 4.241 Pass- 2,025.00 2,025.00 3.52 2,038.36 2,025.00 69.57 308.62 73.82 234.81 128.88 -129.79 4.181 Pass- 2,050.00 2,049.99 3.53 2,063.35 2,049.99 70.57 308.19 74.82 233.37 128.84 -129.83 4.119 Pass- 2,075.00 2,074.98 3.55 2,088.34 2,074.98 71.57 307.47 75.81 231.66 128.77 -129.90 4.056 Pass- 2,100.00 2,099.95 3.57 2,113.31 2,099.95 72.57 306.47 76.79 229.68 128.66 -130.01 3.991 Pass- 2,125.00 2,124.91 3.59 2,138.27 2,124.91 73.57 305.18 77.76 227.42 128.53 -130.14 3.924 Pass- 2,150.00 2,149.85 3.61 2,163.21 2,149.85 74.57 303.60 78.72 224.88 128.37 -130.30 3.857 Pass- 2,175.00 2,174.76 3.63 2,188.12 2,174.76 75.56 301.75 79.67 222.08 128.17 -130.50 3.787 Pass- 2,200.00 2,199.63 3.65 2,212.99 2,199.63 76.56 299,61 80.61 219.00 127.94 -130.73 3.717 Pass- 2,225.00 2,224.48 3.68 2,237.84 2,224.48 77.55 297.20 81.54 215.66 127.68 -130.99 3.645 Pass- 2,250.00 2,249.29 3.70 2,262.65 2,249.29 78.55 294.50 82.45 212.05 127.38 -131.29 3.572 Pass- 2,275.00 2,274.05 3.73 2,287.41 2,274.05 79.54 291.54 83.36 208.18 127.05 -131.62 3.497 Pass- 2,300.00 2,298.77 3.76 2,312.13 2,298.77 80.53 288.31 64.25 204.06 126.67 -132.00 3.422 Pass- 2,325.00 2,323.43 3.80 2,336.79 2,323.43 81.51 284.82 85.13 199.68 126.25 -132.42 3.345 Pass- 28 January,2015-20:14 Page 4 of 22 COMPASS 410 ill Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41.18 Pad-KU 41-18-KU 41-18 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.n Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 2,350.00 2,348.04 3.84 2,361.40 2,348.04 82.50 281.06 86.01 195.05 125.79 -132.88 3.268 Pass- 2,375.00 2,372.60 3.88 2,385.96 2,372.60 83.48 277.05 86.87 190.18 125.28 -133.39 3.189 Pass- 2,400.00 2,397.08 3.92 2,410.44 2,397.08 84.46 272.80 87.73 185.07 124.72 -133.95 3.110 Pass- 2,425.00 2,421.50 3.98 2,434.86 2,421.50 85.43 266.30 68.58 179.72 124.10 -134.57 3.029 Pass- 2,450.00 2,445.85 4.03 2,459.21 2,445.85 86.41 263.57 89.43 174.14 123.42 -135.24 2.947 Pass- 2,475.00 2,470.12 4.09 2,483.48 2,470.12 87.38 258.62 90.27 168.34 122.68 -135.99 2.865 Pass- 2,500.00 2,494.31 4.15 2,507.67 2,494.31 88.35 25345 91.11 162.34 121.87 -136.80 2.782 Pass- 2,525.00 2,518.45 4.22 2,531.81 2,518.45 89.31 248.18 92.13 156.05 121.00 -137.67 2.694 Pass- 2,550.00 2,542.59 4.30 2,555.95 2,542.59 90.28 242.97 93.18 149.79 120.09 -138.58 2.608 Pass- 2,575.00 2,566.73 4.38 2,580.09 2,566.73 91.24 237.83 94.23 143.60 119.14 -139.52 2.524 Pass- 2,600.00 2,590.87 4.45 2,604.23 2,590.87 92.21 232.75 95.29 137.47 118.15 -140.51 2.443 Pass- 2,625.00 2,615.01 4.54 2,628.37 2,615.01 93.17 227.75 96.36 131.39 117.12 -141.55 2.364 Pass- 2,650.00 2,639.15 4.63 2,652.51 2,639.15 94.14 222.82 97.43 125.39 116.04 -142.63 2.287 Pass- 2,675.00 2,663.28 4.72 2,676.64 2,663.28 95.11 217.98 98.52 119.47 114.91 -143.76 2.213 Pass- 2,700.00 2,687.42 4.81 2,700.78 2,687.42 96.07 213.23 99.60 113.62 113.73 -144.93 2.141 Pass- 2,725.00 2,711.56 4.91 2,724.92 2,711.56 97.04 208.56 100.71 107.86 112.50 -146.17 2.071 Pass- 2,750.00 2,735.70 5.00 2,749.06 2,735.70 98.00 204.00 101.82 102.18 111.21 -147.45 2.004 Pass- 2,775.00 2,759.84 5.10 2,773.20 2,759.84 98.97 199.55 102.94 96.61 109.87 -148.80 1.939 Pass- 2,800.00 2,783.98 5.20 2,797.34 2,783.98 99.93 195.22 104.07 91.15 108.46 -150.21 1.876 Pass- 2,825.00 2,808.12 5.31 2,821.48 2,808.12 100.90 191.00 105.21 85.79 106.99 -151.68 1.815 Pass- 2,850.00 2,832.26 5.41 2,845.62 2,832.26 101.86 186.92 106.36 80.56 105.46 -153.21 1.757 Pass- 2,875.00 2,856.40 5.52 2,869.76 2,856.40 102.83 182.98 107.52 75.45 103.85 -154.81 1.702 Pass- 2,900.00 2,680.54 5.63 2,893.90 2,880.54 103.80 179.18 108.69 70.49 102.18 -156.49 1.649 Pass- 2,925.00 2,904.68 5.74 2,916.04 2,904.68 104.76 175.55 109.87 65.68 100.44 -158.23 1.598 Pass- 2,950.00 2,928.82 5.85 2,942.18 2,928.82 105.73 172.08 111.05 61.03 98.63 -160.04 1.550 Pass- 2,975.00 2,952.96 5.96 2,966.32 2,952.96 106.69 168.80 112.24 56.55 96.74 -161.93 1.504 Pass- 3,000.00 2,977.10 6.08 2,990.46 2,977.10 107.66 165.70 113.44 52.26 94.78 -163.89 1.461 Pass- 3,025.00 3,001.24 6.19 3,014.60 3,001.24 108.62 162.81 114.64 48.16 92.75 -165.92 1.420 Pass- 3,050.00 3,025.38 6.31 3,038.74 3,025.38 109.59 160.12 115.85 44.28 90.65 -168.02 1.382 Pass- 3,075.00 3,049.52 6.43 3,062.88 3,049.52 110.56 157.66 117.05 40.61 88.48 -170.19 1.347 Pass- 3,100.00 3,073.65 6.55 3,087.01 3,073.65 111.52 155,44 116.25 37.18 86.24 -172.43 1.314 Pass- 3,125.00 3,097.79 6.67 3,111.15 3,097.79 112.49 153.45 119.45 34.00 83.94 -174.73 1.285 Pass- 28 January,2015-20:14 Page 5 of 22 COMPASS 0 II Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 3,150.00 3,121.93 6.79 3,135.29 3,121.93 113.45 151.72 120.64 31.08 81.59 -177.08 1.258 Pass- 3,175.00 3,146.07 6.91 3,159.43 3,146.07 114.42 150.25 121.82 28.43 79.18 -179.48 1.233 Pass- 3,200.00 3,170.21 7.03 3,183.57 3,170.21 115.38 149.05 122.99 26.06 76.74 178.07 1.212 Pass- 3,225.00 3,194.35 7.16 3,207.71 3,194.35 116.35 148.13 124.15 23.98 74.26 175.59 1.193 Pass- 3,250.00 3,218.49 7.28 3,231.85 3,218.49 117.31 147.49 125.29 22.20 71.75 173.08 1.177 Pass- 3,275.00 3,242.63 7.41 3,255.99 3,242.63 118.28 147.13 126.41 20.73 69.22 170.55 1.164 Pass- 3,293.60 3,260.59 7.50 3,273.95 3,260.59 119.00 147.05 127.23 19.83 67.34 168.67 1.156 Pass- 3,300.00 3,266.77 7.53 3,280.13 3,266.77 119.25 147.06 127.51 19.56 66.69 168.02 1.153 Pass- 3,325.00 3,290.91 7.66 3,304.27 3,290.91 120.21 147.28 128.58 18.70 64.16 165.49 1.145 Pass- 3,350.00 3,315.05 7.79 3,328.41 3,315.05 121.18 147.78 129.64 18.14 61.64 162.97 1.140 Pass- 3,375.00 3,339.19 7.91 3,352.55 3,339.19 122.14 148.57 130.67 17.90 59.14 160.47 1.137 Pass- 3,400.00 3,363.33 8.04 3,376.69 3,363.33 123.11 149.63 131.68 17.95 56.68 158.01 1.136 Pass- 3,425.00 3,387.47 8.17 3,400.83 3,387.47 124.07 150.97 132.67 18.30 54.25 155.58 1.138 Pass- 3,450.00 3,411.61 8.30 3,424.97 3,411.61 125.04 152.58 133.64 18.93 51.67 153.20 1.142 Pass- 3,475.00 3,435.75 8.43 3,449.11 3,435.75 126.00 154.44 134.59 19.85 49.55 150.88 1.147 Pass- 3,500.00 3,459.89 8.56 3,473.25 3,459.89 126.97 156.55 135.52 21.02 47.28 148.61 1.155 Pass- 3,525.00 3,484.03 8.69 3,497.39 3,484.03 127.94 158.89 136.44 22.46 45.08 146.41 1.165 Pass- 3,550.00 3,508.16 8.82 3,521.52 3,508.16 128.90 161.47 137.34 24.13 42.94 144.27 1.176 Pass- 3,575.00 3,532.30 8.95 3,545.66 3,532.30 129.87 164.26 138.23 26.03 40.87 142.21 1.188 Pass- 3,600.00 3,556.44 9.08 3,569.80 3,556.44 130.83 167.26 139.11 28.15 38.88 140.21 1.202 Pass- 3,625.00 3,580.58 9.21 3,593.94 3,580.58 131.80 170.46 139.98 30.48 36.96 138.29 1.218 Pass- 3,650.00 3,604.72 9.35 3,618.08 3,604.72 132.76 173.84 140.84 32.99 35.11 136.44 1.234 Pass- 3,675.00 3,628.86 9.48 3,642.22 3,626.86 133.73 177.39 141.70 35.69 33.33 134.66 1.252 Pass- 3,700.00 3,653.00 9.61 3,666.36 3,653.00 134.69 181.11 142.56 38.55 31.63 132.96 1.270 Pass- 3,725.00 3,677.14 9.75 3,690.50 3,677.14 135.66 184.98 143.41 41.57 29.99 131.32 1.290 Pass- 3,750.00 3,701.28 9.88 3,714.64 3,701.28 136.63 188.99 144.26 44.74 28.42 129.75 1.310 Pass- 3,775.00 3,725.42 10.01 3,738.78 3,725.42 137.59 193.14 145.11 48.04 26.92 128.25 1.331 Pass- 3,800.00 3,749.56 10.15 3,762.92 3,749.56 138.56 197.42 145.96 51.46 25.48 126.82 1.353 Pass- 3,825.00 3,773.70 10.28 3,787.06 3,773.70 139.52 201.82 146.81 55.01 24.11 125.44 1.375 Pass- 3,850.00 3,797.84 10.42 3,811.20 3,797.84 140.49 206.33 147.66 58.67 22.79 124.12 1.397 Pass- 3,875.00 3,821.98 10.55 3,835.34 3,821.96 141.45 210.94 148.52 62.42 21.53 122.87 1.420 Pass- 3,900.00 3,846.12 10.69 3,859.48 3,846.12 142.42 215.65 149.37 66.28 20.33 121.66 1.444 Pass- 28 January,2015-20:14 Page 6 of 22 COMPASS • 9 Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Nighside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 3,925.00 3,870.26 10.82 3,883.62 3,870.26 143.38 220.45 150.24 70.22 19.18 120.51 1.467 Pass- 3,950.00 3,894.40 10.96 3,907.76 3,894.40 144.35 225.34 151.10 74.24 18.07 119.41 1.491 Pass- 3,975.00 3,918.53 11.09 3,931.89 3,918.53 145.32 230.30 151.97 78.34 17.02 118.35 1.516 Pass- 4,000.00 3,942.67 11.23 3,956.03 3,942.67 146.28 235.35 152.84 82.51 16.01 117.34 1.540 Pass- 4,025.00 3,966.81 11.37 3,980.17 3,966.81 147.25 240.46 153.71 86.75 15.04 116.37 1.564 Pass- 4,050.00 3,990.95 11.50 4,004.31 3,990.95 148.21 245.63 154.59 91.05 14.11 115.44 1.589 Pass- 4,075.00 4,015.09 11.64 4,028.45 4,015.09 149.18 250,87 155.47 95.41 13.22 114.55 1.614 Pass- 4,100.00 4,039.23 11.78 4,052.59 4,039.23 150.14 256.17 156.35 99.82 12.37 113.70 1.638 Pass- 4,125.00 4,063.37 11.91 4,076.73 4,063.37 151.11 261.52 157.24 104.28 11.55 112.88 1.663 Pass- 4,150.00 4,087.51 12.05 4,100.87 4,087.51 152.07 266.92 158.13 108.80 10.77 112.10 1.688 Pass- 4,175.00 4,111.65 12.19 4,125.01 4,111.65 153.04 272.37 159.02 113.35 10.01 111.34 1.713 Pass- 4,200.00 4,135.79 12.33 4,149.15 4,135.79 154.01 277.87 159.92 117.95 9.29 110.62 1.738 Pass- 4,225.00 4,159.93 12.46 4,173.29 4,159.93 154.97 283.41 160.82 122.59 8.59 109.93 1.762 Pass- 4,250.00 4,184.07 12.60 4,197.43 4,184.07 155.94 288.99 161.72 127.26 7.92 109.26 1.787 Pass- 4,275.00 4,208.21 12.74 4,221.57 4,208.21 156.90 294.60 162.63 131.98 7.28 108.61 1.812 Pass- 4,300.00 4,232.35 12.88 4,245.71 4,232.35 157.87 300.26 163.54 136.72 6.66 107.99 1.836 Pass- 4,325.00 4,256.49 13.02 4,269.85 4,256.49 158.83 305.94 164.45 141.49 6.07 107.40 1.860 Pass- 4,350.00 4,280.63 13.15 4,293.99 4,280.63 159.80 311.66 165.36 146.30 5.49 106.82 1.885 Pass- 4,375.00 4,304.77 13.29 4,318.13 4,304.77 160.77 317.41 166.28 151.13 4.94 106.27 1.909 Pass- 4,400.00 4,328.91 13.43 4,342.27 4,328.91 161.73 323.19 167.20 155.99 4.40 105.73 1.933 Pass- 4,425.00 4,353.04 13.57 4,366.40 4,353.04 162.70 328.99 166.12 160.87 3.89 105.22 1.957 Pass- 4,450.00 4,377.18 13.71 4,390.54 4,377.18 163.66 334.82 169.05 165.77 3.39 104.72 1.981 Pass- 4,475.00 4,401.32 13.85 4,414.68 4,401.32 164.63 340.67 169.97 170.70 2.91 104.24 2.004 Pass- 4,500.00 4,425.46 13.99 4,438.82 4,425.46 165.59 346.55 170.90 175.65 2.45 103.78 2.028 Pass- 4,525.00 4,449.60 14.13 4,462.96 4,449.60 166.56 352.45 171.83 180.62 2.00 103.33 2.051 Pass- 4,550.00 4,473.74 14.26 4,487.10 4,473.74 167.52 358.37 172.77 185.61 1.56 102.89 2.074 Pass- 4,575.00 4,497.88 14.40 4,511.24 4,497.88 168.49 364.31 173.70 190.61 1.14 102.47 2.097 Pass- 4,600.00 4,522.02 14.54 4,535.38 4,522.02 169.46 370.27 174.64 195.63 0.74 102.07 2.120 Pass- 4,625.00 4,546.16 14.68 4,559.52 4,546.16 170.42 376.25 175.57 200.67 0.34 101.68 2.143 Pass- 4,650.00 4,570.30 14.82 4,583.66 4,570.30 171.39 382.24 176.51 205.73 -0.04 101.29 2.166 Pass- 4,675.00 4,594.44 14.96 4,607.80 4,594.44 172.35 388.25 177.45 210.80 -0.41 100.93 2.188 Pass- 4,700.00 4,618.58 15.10 4,631.94 4,618.58 173.32 394.28 178.40 215.88 -0.76 100.57 2.210 Pass- 28 January,2015-20:14 Page 7of22 COMPASS 111 0 Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff Is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 4,725.00 4,642.72 15.24 4,656.08 4,642.72 174.28 400.32 179.34 220.98 -1.11 100.22 2.232 Pass- 4,750.00 4,666.86 15.38 4,680.22 4,666.86 175.25 406.37 180.29 226.09 -1.45 99.88 2.254 Pass- 4,775.00 4,691.00 15.52 4,704.36 4,691.00 176.21 412.44 181.23 231.21 -1.77 99.56 2.276 Pass- 4,800.00 4,715.14 15.66 4,728.50 4,715.14 177.18 418.52 182.18 236.34 -2.09 99.24 2.297 Pass- 4,825.00 4,739.28 15.80 4,752.64 4,739.28 178.15 424.62 183.13 241.49 -2.40 98.93 2.319 Pass- 4,850.00 4,763.42 15.94 4,776.78 4,763.42 179.11 430.73 184.08 246.65 -2.70 98.63 2.340 Pass- 4,875.00 4,787.55 16.08 4,800.91 4,787.55 180.08 436.84 185.03 251.81 -2.99 98.34 2.361 Pass- 4,900.00 4,811.69 16.22 4,825.05 4,811.69 181.04 442.97 185.98 256.99 -3.27 98.06 2.382 Pass- 4,925.00 4,835.83 16.36 4,849.19 4,835.83 182.01 449.11 186.94 262.17 -3.55 97.78 2.402 Pass- 4,950.00 4,859.97 16.50 4,873.33 4,859.97 182.97 455.26 187.89 267.37 -3.82 97.51 2.423 Pass- 4,975.00 4,884.11 16.64 4,897.47 4,884.11 183.94 461.42 188.85 272.57 -4.08 97.25 2.443 Pass- 5,000.00 4,908.25 16.78 4,921.61 4,908.25 184.90 467.59 189.81 277.78 -4.33 97.00 2.464 Pass- 5,025.00 4,932.39 16.92 4,945.75 4,932.39 185.87 473.77 190.76 283.00 -4.58 96.75 2.484 Pass- 5,050.00 4,956.53 17.06 4,969.89 4,956.53 186.84 479.95 191.72 288.23 -4.82 96.51 2.503 Pass- 5,075.00 4,980.67 17.21 4,994.03 4,980.67 187.80 486.15 192.68 293.46 -5.06 96.28 2.523 Pass- 5,100.00 5,004.81 17.35 5,018.17 5,004.81 188.77 492.35 193.64 298.71 -5.28 96.05 2.543 Pass- 5,125.00 5,028.95 17.49 5,042.31 5,028.95 189.73 498.56 194.60 303.96 -5.51 95.82 2.562 Pass- 5,150.00 5,053.09 17.63 5,066.45 5,053.09 190.70 504.78 195.56 309.21 -5.73 95.61 2.581 Pass- 5,175.00 5,077.23 17.77 5,090.59 5,077.23 191.66 511.00 196.53 314.47 -5.94 95.39 2.600 Pass- 5,200.00 5,101.37 17.91 5,114.73 5,101.37 192.63 517.23 197.49 319.74 -6.15 95.19 2.619 Pass- 5,225.00 5,125.51 18.05 5,138.87 5,125.51 193.59 523.47 198.45 325.01 -6.35 94.98 2.638 Pass- 5,250.00 5,149.65 18.19 5,163.01 5,149.65 194.56 529.71 199.42 330.29 -6.55 94.79 2.656 Pass- 5,275.00 5,173.79 18.33 5,187.15 5,173.79 195.53 535.96 200.38 335.58 -6.74 94.59 2.675 Pass- 5,300.00 5,197.92 18.47 5,211.28 5,197.92 196.49 542.22 201.35 340.87 -6.93 94.40 2.693 Pass- 5,325.00 5,222.06 18.62 5,235.42 5,222.06 197.46 548.48 202.32 346.17 -7.11 94.22 2.711 Pass- 5,350.00 5,246.20 18.76 5,259.56 5,246.20 198.42 554.75 203.28 351.47 -7.29 94.04 2.729 Pass- 5,375.00 5,270.34 18.90 5,283.70 5,270.34 199.39 561.02 204.25 356.77 -7.47 93.86 2.747 Pass- 5,400.00 5,294.48 19.04 5,307.84 5,294.48 200.35 567.30 205.22 362.08 -7.64 93.69 2.764 Pass- 5,425.00 5,318.62 19.18 5,331.98 5,316.62 201.32 573.58 206.19 367.40 -7.81 93.52 2.782 Pass- 5,450.00 5,342.76 19.32 5,356.12 5,342.76 202.28 579.87 207.16 372.71 -7.97 93.36 2.799 Pass- 5,475.00 5,366.90 19.46 5,380.26 5,366.90 203.25 586.16 208.13 378.04 -8.13 93.20 2.816 Pass- 5,500.00 5,391.04 19.60 5,404.40 5,391.04 204.22 592.46 209.10 383.36 -8.29 93.04 2.833 Pass- 28 January,2015-20:14 Page 8 of 22 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff Is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Hlghslde Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 5,525.00 5,415.18 19.75 5,428.54 5,415.18 205.18 598.76 210.07 388.70 -8.45 92.89 2.850 Pass- 5,550.00 5,439.32 19.89 5,452.68 5,439.32 206.15 605.07 211.04 394.03 -8.60 92.73 2.867 Pass- 5,575.00 5,463.46 20.03 5,476.82 5,463.46 207.11 611.38 212.01 399.37 -8.75 92.59 2.884 Pass- 5,600.00 5,487.60 20.17 5,500.96 5,487.60 208.08 617.69 212.98 404.71 -8.89 92.44 2.900 Pass- 5,625.00 5,511.74 20.31 5,525.10 5,511.74 209.04 624.01 213.95 410.06 -9.03 92.30 2.917 Pass- 5,650.00 5,535.88 20.45 5,549.24 5,535.88 210.01 630.33 214.93 415.41 -9.17 92.16 2.933 Pass- 5,675.00 5,560.02 20.60 5,573.38 5,560.02 210.98 636.66 215.90 420.76 -9.31 92.02 2.949 Pass- 5,700.00 5,584.16 20.74 5,597.52 5,584.16 211.94 642.99 216.87 426.11 -9.44 91.89 2.965 Pass- 5,725.00 5,608.30 20.88 5,621.66 5,608.30 212.91 649.32 217.85 431.47 -9.57 91.76 2.981 Pass- 5,750.00 5,632.43 21.02 5,645.79 5,632.43 213.87 655.65 218.82 436.83 -9.70 91.63 2.996 Pass- 5,775.00 5,656.57 21.16 5,669.93 5,656.57 214.84 661.99 219.80 442.20 -9.83 91.50 3.012 Pass- 5,800.00 5,680.71 21.30 5,694.07 5,680.71 215.80 668.33 220.77 447.56 -9.95 91.38 3.027 Pass- 5,825.00 5,704.85 21.45 5,718.21 5,704.85 216.77 674.68 221.75 452.93 -10.07 91.26 3.043 Pass- 5,850.00 5,728.99 21.59 5,742.35 5,728.99 217.73 681.03 222.72 458.31 -10.19 91.14 3.058 Pass- 5,875.00 5,753.13 21.73 5,766.49 5,753.13 218.70 687.38 223.70 463.68 -10.31 91.02 3.073 Pass- 5,900.00 5,777.27 21.87 5,790.63 5,777.27 219.67 693.73 224.67 469.06 -10.42 90.91 3.088 Pass- 5,925.00 5,801.41 22.01 5,814.77 5,801.41 220.63 700.09 225.65 474.44 -10.54 90.79 3.103 Pass- 5,950.00 5,825.55 22.16 5,838.91 5,825.55 221.60 706.45 226.63 479.82 -10.65 90.68 3.117 Pass- 5,975.00 5,849.69 22.30 5,863.05 5,849.69 222.56 712.81 227.60 485.21 -10.76 90.57 3.132 Pass- 6,000.00 5,873.83 22.44 5,887.19 5,873.83 223.53 719.17 228.58 490.59 -10.86 90.47 3.146 Pass- 6,025.00 5,897.97 22.58 5,911.33 5,897.97 224.49 725.54 229.56 495.98 -10.97 90.36 3.161 Pass- 6,050.00 5,922.11 22.73 5,935.47 5,922.11 225.46 731.91 230.54 501.37 -11.07 90.26 3.175 Pass- 6,075.00 5,946.25 22.87 5,959.61 5,946.25 226.42 738.28 231.51 506.77 -11.17 90.16 3.189 Pass- 6,100.00 5,970.39 23.01 5,983.75 5,970.39 227.39 744.66 232.49 512.16 -1127 90.06 3.203 Pass- 6,125.00 5,994.53 23.15 6,007.89 5,994.53 228.36 751.03 233.47 517.56 -11.37 89.96 3.217 Pass- 6,150.00 6,018.67 23.29 6,032.03 6,018.67 229.32 757.41 234.45 522.96 -11.47 89.86 3.231 Pass- 6,175.00 6,042.81 23.44 6,056.17 6,042.81 230.29 763.79 235.43 528.36 -11.56 89.77 3.244 Pass- 6,200.00 6,066.94 23.58 6,080.30 6,066.94 231.25 770.17 236.41 533.77 -11.66 89.68 3.258 Pass- 6,225.00 6,091.08 23.72 6,104.44 6,091.08 232.22 776.56 237.39 539.17 -11.75 89.58 3.271 Pass- 6,250.00 6,115.22 23.86 6,128.58 6,115.22 233.18 782.94 238.37 544.58 -11.84 89.49 3.285 Pass- 6,275.00 6,139.36 24.01 6,152.72 6,139.36 234.15 789.33 239.35 549.99 -11.93 89.41 3.298 Pass- 6,300.00 6,163.50 24.15 6,176.86 6,163.50 235.11 795.72 240.33 555.40 -12.01 89.32 3.311 Pass- 28 January,2015-20:14 Page 9 of 22 COMPASS 0 110 Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 6,325.00 6,187.64 24.29 6,201.00 6,187.64 236.08 802.11 241.31 560.81 -12.10 89.23 3.324 Pass- 6,350.00 6,211.78 24.43 6,225.14 6,211.78 237.05 808.51 242.29 566.22 -12.18 89.15 3.337 Pass- 6,375.00 6,235.92 24.57 6,249.28 6,235.92 238.01 814.90 243.27 571.63 -12.27 89.06 3.350 Pass- 6,400.00 6,260.06 24.72 6,273.42 6,260.06 238.98 821.30 244.25 577.05 -12.35 88.98 3.363 Pass- 6,425.00 6,264.20 24.83 6,297.56 6,284.20 239.94 827.70 245.20 582.50 -12.43 88.90 3.376 Pass- 6,450.00 6,308.34 24.94 6,321.70 6,308.34 240.91 834.10 246.15 587.95 -12.51 88.82 3.389 Pass- 6,475.00 6,332.48 25.06 6,345.84 6,332.48 241.87 840.50 247.10 593.40 -12.59 88.74 3.401 Pass- 6,500.00 6,356.62 25.17 6,369.98 6,356.62 242.84 846.90 248.06 598.84 -12.66 88.67 3.414 Pass- 6,525.00 6,380.76 25.26 6,394.12 6,380.76 243.80 853.31 248.72 604.59 -12.74 88.59 3.431 Pass- 6,550.00 6,404.90 25.35 6,41826 6,404.90 244.77 859.71 249.64 610.07 -12.81 88.52 3.444 Pass- 6,575.00 6,429.04 25.43 6,442.40 6,429.04 245.74 866.12 250.57 615.55 -12.89 88.44 3.457 Pass- 6,600.00 6,453.18 25.52 6,466.54 6,453.18 246.70 872.53 251.49 621.04 -12.96 88.37 3.469 Pass- 6,625.00 6,477.31 25.61 6,490.67 6,477.31 247.67 878.94 252.42 626.52 -13.03 88.30 3.482 Pass- 6,650.00 6,501.45 25.70 6,514.81 6,501.45 248.63 885.35 253.35 632.00 -13.10 88.23 3.495 Pass- 6,675.00 6,525.59 25.79 6,538.95 6,525.59 249.60 891.77 254.28 637.49 -13.17 88.16 3.507 Pass- 6,700.00 6,549.73 25.88 6,563.09 6,549.73 250.56 898.18 255.20 642.98 -13.24 88.09 3.519 Pass- 6,725.00 6,573.87 25.97 6,58723 6,573.87 251.53 904.60 256.13 648.46 -13.31 88.02 3.532 Pass- 6,750.00 6,598.01 26.06 6,611.37 6,598.01 252.49 911.01 257.06 653.95 -13.37 87.96 3.544 Pass- 6,775.00 6,622.15 26.15 6,635.51 6,622.15 253.46 917.43 257.99 659.44 -13.44 87.89 3.556 Pass- 6,800.00 6,646.29 26.24 6,659.65 6,646.29 254.43 923.85 258.92 664.93 -13,50 87.83 3.568 Pass- 6,825.00 6,670.43 26.33 6,683.79 6,670.43 255.39 930.27 259.85 670.42 -13.57 87.76 3.580 Pass- 6,850.00 6,694.57 26.42 6,707.93 6,694.57 256.36 936.69 260.78 675.91 -13.63 87.70 3.592 Pass- 6,875.00 6,718.71 26.52 6,732.07 6,718.71 257.32 943.12 261.71 681.40 -13.69 87.64 3.604 Pass- 6,900.00 6,742.85 26.61 6,756.21 6,742.85 25829 949.54 262.64 686.90 -13.75 87.58 3.615 Pass- 6,925.00 6,766.99 26.70 6,780.35 6,766.99 259.25 955.97 263.58 692.39 -13.81 87.52 3.627 Pass- 6,950.00 6,791.13 26.80 6,804.49 6,791.13 260.22 962.39 264.51 697.88 -13.87 87.46 3.638 Pass- 6,975.00 6,815.27 26.89 6,828.63 6,815.27 261.19 968.82 265.44 703.38 -13.93 87.40 3.650 Pass- 7,000.00 6,839.41 26.99 6,852.77 6,839.41 262.15 975.25 266.37 708.87 -13.99 87.34 3.661 Pass- 7,025.00 6,863.55 27.08 6,876.91 6,863.55 263.12 981.68 267.30 714.37 -14.05 87.28 3.673 Pass- 7,050.00 6,667.69 27.18 6,901.05 6,887.69 264.08 988.11 268.24 719.87 -14.10 8723 3.684 Pass- 7,075.00 6,911.82 27.28 6,925.18 6,911.82 265.05 994.54 269.17 725.36 -14.16 87.17 3.695 Pass- 7,100.00 6,935.96 27.37 6,949.32 6,935.96 266.01 1,000.97 270.11 730.86 -1421 87.12 3.706 Pass- 28 January,2015-20:14 Page 10 of 22 COMPASS • . Hilcorp Energy Company HALLI B U RTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 41-18-KU 41-18 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff Is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 7,125.00 6,960.10 27.47 6,973.46 6,960.10 266.98 1,007.40 271.05 736.35 -14.27 87.06 3.717 Pass- 7,150.00 6,964.24 27.57 6,997.60 6,984.24 267.94 1,013.83 271.98 741.85 -14.32 87.01 3.728 Pass- 7,175.00 7,008.38 27.66 7,021.74 7,008.38 268.91 1,020.28 272.78 747.50 -11.56 86.96 3.740 Pass- 7,200.00 7,032.52 27.76 7,045.88 7,032.52 269.88 1,026.77 273.54 753.23 -7.74 86.94 3.754 Pass- 7,225.00 7,056.65 27.85 7,070.01 7,056.65 270.84 1,033.31 274.32 759.00 -3.94 86.94 3.767 Pass- 7,250.00 7,080.76 27.94 7,094.12 7,080.76 271.80 1,039.89 275.10 764.79 -0.18 86.97 3.780 Pass- 7,275.00 7,104.85 28.04 7,118.21 7,104.85 272.77 1,046.52 275.90 770.62 3.50 87.02 3.793 Pass- 7,300.00 7,128.91 28.13 7,142.27 7,128.91 273.73 1,053.18 276.70 776.48 7.10 87.09 3,806 Pass- 7,325.00 7,152.93 28.22 7,166.29 7,152.93 274.69 1,059.88 277.51 782.37 10.58 87.18 3.819 Pass- 7,350.00 7,176.91 28.32 7,190.27 7,176.91 275.65 1,066.63 278.32 788.30 13.93 87.30 3.832 Pass- 7,375.00 7,200.83 28.41 7,214.19 7,200.83 276.61 1,073.41 279.14 794.27 17.16 87.44 3.845 Pass- 7,400.00 7,224.70 28.51 7,238.06 7,224.70 277.56 1,080.24 279.96 800.28 20.24 87.60 3.859 Pass- 7,425.00 7,248.49 28.60 7,261.85 7,248.49 278.51 1,087.10 280.78 806.33 23.18 87.78 3.872 Pass- 7,450.00 7,272.21 28.69 7,285.57 7,272.21 279.46 1,094.02 281.59 812.42 25.99 87.98 3.885 Pass- 7,475.00 7,295.86 28.79 7,309.22 7,295.86 280.41 1,100.95 282.70 818.25 28.45 88.20 3.894 Pass- 7,500.00 7,319.50 28.88 7,332.86 7,319.50 281.35 1,107.85 283.57 824.28 28.68 88.42 3.907 Pass- 7,525.00 7,343.14 28.98 7,356.50 7,343.14 282.30 1,114.76 284.45 830.32 28.90 88.64 3.919 Pass- 7,550.00 7,366.78 29.08 7,380.14 7,366.78 283.25 1,121.69 285.32 836.37 29.11 88.86 3.931 Pass- 7,575.00 7,390.43 29.18 7,403.79 7,390.43 284.19 1,128.64 286.20 842.45 29.33 89.07 3.944 Pass- 7,600.00 7,414.07 29.27 7,427.43 7,414.07 285.14 1,135.61 287.07 848.53 29.54 89.29 3.956 Pass- 7,625.00 7,437.71 29.37 7,451.07 7,437.71 286.08 1,142.59 287.95 854.63 29.75 89.49 3.968 Pass- 7,650.00 7,461.35 29.47 7,474.71 7,461.35 287.03 1,149.58 288.83 860.75 29.96 89.70 3.980 Pass- 7,675.00 7,484.99 29.58 7,498.35 7,484.99 287.97 1,156.59 289.71 866.88 30.16 89.91 3.992 Pass- 7,700.00 7,508.63 29.68 7,521.99 7,508.63 288.92 1,163.62 290.59 873.03 30.36 90.11 4.004 Pass- 7,725.00 7,532.27 29.78 7,545.63 7,532.27 289.87 1,170.65 291.47 879.18 30.56 90.31 4.016 Pass- 7,750.00 7,555.91 29.88 7,569.27 7,555.91 290.81 1,177.71 292.35 885.35 30.76 90.51 4.028 Pass- 7,775.00 7,579.55 29.98 7,592.91 7,579.55 291.76 1,184.77 293.24 891.54 30.96 90.70 4.040 Pass- 7,800.00 7,603.19 30.09 7,616.55 7,603.19 292.70 1,191.85 294.12 897.73 31.15 90.89 4.052 Pass- 28 January,2015-20:14 Page 11 of 22 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13-8 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation Is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highslde Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 18.00 18.00 0.00 10.40 57.04 0.00 272.71 0.87 271.84 -112.34 -112.34 313.390 Pass- 25.00 25.00 0.01 10.40 57.04 0.00 271.80 0.88 270.92 -112.34 -112.34 309.548 Pass- 50.00 50.00 0.04 10.40 57.04 0.00 269.99 0.91 269.09 -112.34 -112,34 297.980 Pass- 61.60 61.60 0.05 14.96 61.60 0.04 269.90 0.96 268.94 -112.34 -112.34 280.403 Pass- 75.00 75.00 0.06 28.36 75.00 0.17 269.90 1.11 268.80 -112.34 -112.34 244.191 Pass- 100.00 100.00 0.09 53.36 100.00 0.41 269.90 1.37 268.53 -112.34 -112.34 196.780 Pass- 125.00 125.00 0.15 78.36 125.00 0.65 269.90 1.67 268.23 -112.34 -112.34 162.000 Pass- 150.00 150.00 0.20 103.36 150.00 0.95 269.90 2.03 267.87 -112.34 -112.34 133.067 Pass- 175.00 175.00 0.26 128.36 175.00 1.70 269.90 2.83 267.07 -112.34 -112.34 95.468 Pass- 200.00 200.00 0.32 153.36 200.00 2.44 269.90 3.63 266.27 -112.34 -112.34 74.436 Pass- 225.00 225.00 0.37 178.36 225.00 3.18 269.90 4.42 265.48 -112.34 -112.34 60.997 Pass- 250.00 250.00 0.43 203.36 250.00 4.00 269.90 5.30 264.61 -112.34 -112.34 50.971 Pass- 275.00 275.00 0.49 228.36 275.00 5.27 269.90 6.63 263.27 -112.34 -112.34 40.734 Pass- 300.00 300.00 0.54 253.36 300.00 6.55 269.90 7.96 261.94 -112.34 -112.34 33.921 Pass- 325.00 325.00 0.60 278.36 325.00 7.82 269.90 9.29 260.61 -112.34 -112.34 29.060 Pass- 350.00 350.00 0.65 303.36 350.00 9.17 269.90 10.69 259.21 -112.34 -112.34 25.248 Pass- 375.00 375.00 0.71 328.36 375.00 10.97 269.90 12.55 257.35 -112.34 -112.34 21.501 Pass- 400.00 400.00 0.77 353.36 400.00 12.78 269.90 14.42 255.48 -112.34 -112.34 18.723 Pass- 425.00 425.00 0.82 378.36 425.00 14.59 269.90 16.28 253.62 -112.34 -112.34 16.580 Pass- 450.00 450.00 0.88 403.36 450.00 16.46 269.90 18.21 251.69 -112.34 -112.34 14.820 Pass- 475.00 475.00 0.94 428.36 475.00 18.80 269.90 20.61 24929 -112.34 -112.34 13.097 Pass- 500.00 500.00 0.99 453.36 500.00 21.14 269.90 23.00 246.90 -112.34 -112.34 11.734 Pass- 525.00 525.00 1.05 478.36 525.00 23.48 269.90 25.40 244.50 -112.34 -112.34 10.627 Pass- 550.00 550.00 1.10 503.36 550.00 25.89 269.90 27.86 242.04 -112.34 -112.34 9.687 Pass- 575.00 575.00 1.16 528.36 575.00 28.76 269.90 30.79 239.11 -112.34 -112.34 8.766 Pass- 600.00 600.00 1.22 553.36 600.00 31.63 269.90 33.72 236.18 -112.34 -112.34 8.005 Pass- 625.00 625.00 1.27 578.36 625.00 34.50 269.90 36.64 233.26 -112.34 -112.34 7.366 Pass- 650.00 650.00 1.33 603.36 650.00 37.44 269.90 39.64 230.26 -112.34 -112.34 6.809 Pass- 675.00 675.00 1.38 628.36 675.00 40.85 269.90 43.10 226.80 -112.34 -112.34 6.262 Pass- 700.00 700.00 1.44 653.36 700.00 44.25 269.90 46.56 223.34 -112.34 -112.34 5.797 Pass- 725.00 725.00 1.50 678.36 725.00 47.65 269.90 50.02 219.88 -112.34 -112.34 5.396 Pass- 750.00 750.00 1.55 703.36 750.00 51.12 269.90 53.55 216.35 -112.34 -112.34 5.040 Pass- 28 January,2015-20:14 Page 12 of 22 COMPASS • 0 Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13-8 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff Is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (waft) (usft) (usft) Bearing Bearing Factor Warning 775.00 775.00 1.61 728.36 775.00 55.06 269.90 57.54 212.36 -112.34 -112.34 4.691 Pass- 800.00 800.00 1.67 753.36 800.00 58.99 269.90 61.53 206.37 -112.34 -112.34 4.387 Pass- 825.00 825.00 1.72 778.36 825.00 62.93 269.90 65.52 204.38 -112.34 -112.34 4.119 Pass- 850.00 850.00 1.78 803.36 850.00 66.93 269.90 69.58 200.32 -112.34 -112.34 3.879 Pass- 875.00 875.00 1.83 828.36 875.00 71.40 269.90 74.10 195.80 -112.34 -112.34 3.642 Pass- 900.00 900.00 1.89 853.36 900.00 75.87 269.90 78.63 191.27 -112.34 -112.34 3.433 Pass- e 925.00 925.00 1.95 878.36 925.00 80.33 269.90 83.15 186.75 -112.34 -112.34 3.246 Pass- 950.00 950.00 2.00 903.36 950.00 84.87 269.90 87.74 182.16 -112.34 -112.34 3.076 Pass- 975.00 975.00 2.06 928.36 975.00 89.87 269.90 92.80 177.10 -112.34 -112.34 2.908 Pass- 1,000.00 1,000.00 2.12 953.36 1,000.00 94.67 269.90 97.85 172.05 -112.34 -112.34 2.758 Pass- 1,025.00 1,025.00 2.17 978.36 1,025.00 99.87 269.90 102.91 166.99 -112.34 -112.34 2.623 Pass- 1,050.00 1,050.00 2.23 1,003.36 1,050.00 104.94 269.90 108.03 161.87 -112.34 -112.34 2.498 Pass- 1,075.00 1,075.00 2.28 1,028.36 1,075.00 110.47 269.90 113.62 156.28 -112.34 -112.34 2.375 Pass- 1,100.00 1,100.00 2.34 1,053.36 1,100.00 116.00 269.90 119.21 150.69 -112.34 -112.34 2.264 Pass- 1,125.00 1,125.00 2.40 1,078.36 1,125.00 121.53 269.90 124.79 145.11 -112.34 -112.34 2.163 Pass- 1,150.00 1,150.00 2.45 1,103.36 1,150.00 126.71 269.90 130.03 139.87 -112.34 -112.34 2.076 Pass- 1,175.00 1,175.00 2.51 1,128.36 1,175.00 129.60 269.90 132.98 136.92 -112.34 -112.34 2.030 Pass- 1,200.00 1,200.00 2.56 1,153.36 1,200.00 132.50 269.90 135.94 133.96 -112.34 -112.34 1.985 Pass- 1,225.00 1,225.00 2.62 1,178.36 1,225.00 135.40 269.90 138.76 131.14 -112.34 -112.34 1.945 Pass- 1,250.00 1,250.00 2.68 1,203.36 1,250.00 137.91 269.90 141.33 128.57 -112.34 -112.34 1.910 Pass- 1,275.00 1,275.00 2.73 1,228.36 1,275.00 137.93 269.90 141.40 128.50 -112.34 -112.34 1.909 Pass- 1,300.00 1,300.00 2.79 1,253.36 1,300.00 137.94 269.90 141.47 128.43 -112.34 -112.34 1.908 Pass- 1,325.00 1,325.00 2.85 1,278.36 1,325.00 137.96 269.90 141.55 128.35 -112.34 -112.34 1.907 Pass- 1,350.00 1,350.00 2.90 1,303.36 1,350.00 137.98 269.90 141.62 128.28 -112.34 -112.34 1.906 Pass- 1,375.00 1,375.00 2.96 1,328.36 1,375.00 138.05 269.90 141.75 128.15 -112.34 -112.34 1.904 Pass- 1,400.00 1,400.00 3.01 1,353.36 1,400.00 138.12 269.90 141.87 128.03 -112.34 -112.34 1.902 Pass- 1,425.00 1,425.00 3.07 1,378.36 1,425.00 138.18 269.90 141.99 127.91 -112.34 -112.34 1.901 Pass- 1,450.00 1,450.00 3.13 1,403.36 1,450.00 138.26 269.90 142.13 127.77 -112.34 -112.34 1.899 Pass- 1,475.00 1,475.00 3.18 1,428.36 1,475.00 138.44 269.90 142.37 127.54 -112.34 -112.34 1.896 Pass- 1,500.00 1,500.00 3.24 1,453.36 1,500.00 138.62 269.90 142.60 127.30 -112.34 -112.34 1.893 Pass- 1,525.00 1,525.00 3.27 1,478.36 1,525.00 138.80 269.90 142.71 127.19 -112.34 -112.34 1.891 Pass- 1,550.00 1,550.00 3.30 1,503.36 1,550.00 139.00 269.90 142.94 126.96 -112.34 -112.34 1.888 Pass- 28 January,2015-20:14 Page 13 of 22 COMPASS 0 ! Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13-8 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation Is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 1,575.00 1,575.00 3.32 1,528.36 1,575.00 139.38 269.90 143.34 126.56 -112.34 -112.34 1.883 Pass- 1,600.00 1,600.00 3.35 1,553.36 1,600.00 139.75 269.90 143.75 126.15 -112.34 -112.34 1.878 Pass- 1,625.00 1,625.00 3.36 1,578.36 1,625.00 140.13 269.90 144.12 125.78 -112.34 -112.34 1.873 Pass- 1,650.00 1,650.00 3.36 1,603.36 1,650.00 140.54 269.90 144.54 125.36 -112.34 -112.34 1.867 Pass- 1,675.00 1,675.00 3.36 1,628.36 1,675.00 141.21 269.90 145.21 124.69 -112.34 -112.34 1.859 Pass- 1,700.00 1,700.00 3.37 1,653.36 1,700.00 141.88 269.90 145.89 124.01 -112.34 -112.34 1.850 Pass- 1,725.00 1,725.00 3.38 1,678.36 1,725.00 142.55 269.90 146.56 123.34 -112.34 -112.34 1.842 Pass- 1,750.00 1,750.00 3.38 1,703.36 1,750.00 143.27 269.90 147.30 122.60 -112.34 -112.34 1.832 Pass- 1,775.00 1,775.00 3.39 1,728.36 1,775.00 144.35 269.90 148.38 121.52 -112.34 -112.34 1.819 Pass- 1,800.00 1,800.00 3.40 1,753.36 1,800.00 145.43 269.90 149.46 120.44 -112.34 -112.34 1.806 Pass- 1,825.00 1,825.00 3.41 1,778.36 1,825.00 146.50 269.90 150.55 119.35 -112.34 -112.34 1.793 Pass- 1,850.00 1,850.00 3.42 1,603.36 1,850.00 147.65 269.90 151.71 118.19 -112.34 -112.34 1.779 Pass- 1,875.00 1,875.00 3.43 1,828.36 1,875.00 149.24 269.90 153.31 116.59 -112.34 -112.34 1.760 Pass- 1,900.00 1,900.00 3.44 1,853.36 1,900.00 150.83 269.90 154.92 114.99 -112.34 -112.34 1.742 Pass- 1,925.00 1,925.00 3.46 1,878.36 1,925.00 152.42 269.90 156.52 113.38 -112.34 -112.34 1.724 Pass- 1,950.00 1,950.00 3.47 1,903.36 1,950.00 154.10 269.90 158.21 111.69 -112.34 -112.34 1.706 Pass- 1,975.00 1,975.00 3.49 1,928.36 1,975.00 156.30 269.90 160.43 109.47 -112.34 -112.34 1.682 Pass- 2,000.00 2,000.00 3.50 1,953.36 2,000.00 158.51 269.90 162.65 107.25 -112.34 -112.34 1.659 Pass- 2,025.00 2,025.00 3.52 1,978.36 2,025.00 160.71 269.74 164.86 104.88 146.32 -112.35 1.636 Pass- 2,050.00 2,049.99 3.53 2,003.35 2,049.99 163.01 269.26 167.13 102.13 146.30 -112.37 1.611 Pass- 2,075.00 2,074.98 3.55 2,028.34 2,074.98 165.90 268.46 169.96 98.49 146.27 -112.40 1.579 Pass- 2,100.00 2,099.95 3.57 2,053.31 2,099.95 168.78 267.33 172.77 94.56 146.22 -112.45 1.547 Pass- 2,125.00 2,124.91 3.59 2,078.27 2,124.91 171.67 265.89 175.54 90.35 146.16 -112.51 1.515 Pass- 2,150.00 2,149.85 3.61 2,10321 2,149.85 174.64 264.12 178.37 85.76 146.09 -112.58 1.481 Pass- 2,175.00 2,174.76 3.63 2,128.12 2,174.76 178.25 262.04 181.79 80.25 146.00 -112.67 1.441 Pass- 2,200.00 2,199.63 3.65 2,152.99 2,199.63 181.85 259.64 185.17 74.47 145.89 -112.78 1.402 Pass- 2,225.00 2,224.48 3.68 2,177.84 2,224.48 185.45 256.92 188.51 68.41 145.77 -112.90 1.363 Pass- 2,250.00 2,249.29 3.70 2,202.65 2,249.29 189.12 253.88 191.89 62.00 145.63 -113.04 1.323 Pass- 2,275.00 2,274.05 3.73 2,227.41 2,274.05 193.45 250.53 195.87 54.66 145.47 -113.20 1.279 Pass- 2,300.00 2,298.77 3.76 2,252.13 2,298.77 197.77 246.86 199.79 47.07 145.29 -113.38 1.236 Pass- 2,325.00 2,323.43 3.80 2,276.79 2,323.43 202.08 242.88 203.67 39.21 145.09 -113.58 1.193 Pass- 2,350.00 2,348.04 3.84 2,301.40 2,348.04 206.42 238.59 207.53 31.06 144.86 -113.81 1.150 Pass- 28 January,2015-20:14 Page 14 of 22 COMPASS • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13.8 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 2,375.00 2,372.60 3.88 2,325.96 2,372.60 211.45 233.98 212.01 21.98 144.61 -114.05 1.104 Pass- 2,400.00 2,397.08 3.92 2,350.44 2,397.08 216.46 229.07 216.42 12.65 144.34 -114.33 1.058 Pass- 2,425.00 2,421.50 3.98 2,374.86 2,421.50 221.46 223.65 220.77 3.09 144.03 -114.64 1.014 Pass- 2,450.00 MEM X94. MEM r'!iT FAIL- ®"'" MIME !' ''+ ECHE ! ® =ME I!MS= ®MEM FAIL- 2,500.00 MEM II! MEM 2 494 3 MEM 206.40 142.88 MN= :11E FAIL- ii MB= MEM ®' •'' ® MEM FAIL- 2,550.00 P mom mimn MEM ME NM= ® MIMI EMCEE IIIIIIIIIIIIIIMI= MFAIL- MEM MIME IEM IIIIIIIIIII E IIIIIIIIIIIIISS IIIIIIIIIIIII IIIIIIIIIIIIIIIII I IIIIIIIIIIIII E IIIIIIIIIIIII!!I FAIL- 2,600.00 2,590.87 M•, ME= 2,590.87 MEICE MIME 258.08 =ME MEM FAIL- 2,625.00 . IIIIIIIIIIIEE IMIES IIIIIIIIIIIIIIIIIIII!sera mem 0.66 FAIL- 2,650.00 =Mr MEE =Mg N' 6 168.90 �r ;, FAIL- 2,675.00 2,663.28 2,616.6• 2,663.28 rl.r =IIMM MEM 11:MEEES -119.80 FAIL- 2,700.00 w IMIME 2,640.7: MEM =an 284.20 IIIIIIIIIIIIIIIIIIII:1:1 IIIIIIIIIIIIIIEE IIIIIIIIIIIIME IIIIIIIIIII II FAIL- MEM =MEE !LEE 2,664.9• NIEMENE FAIL- 2,750.00 a ..10 2,689.0• ®' MEM =IMEM 298.10 MEM MIME =BM 0.48• FAIL- �'•SIi mon =ERE mem =I= II! MIBIE�! ®EN=� FAIL- 2,800.00 2,783.98 IIIIIIIIIIIIIII%4r] 2,783.98 ® IIIIIIIIIIIIIEE IIIIIIIIIIIIIiaEJGI IIIIIIIIIIIIIIIIIIII�IIIIIIIIIIIII I IIIIIIIIIII�Illllllllllllll,x�r. FAIL- 2,825.00 2,808.12 ® mmin 2,808.12 IIMIE =ER IIIIIIIIIIIII'EE =OM IIIIIIIIIII I l FAIL- 2,850.0° MEIMIIIIIIIIIIIIIIIZIT =MI ! MEI 120.4° 378 44 ME==FEE II!IIIIIIIIIIIIIII=. FAIL- 2,875.00 2,856.40 ® 2,809.7. 2,886.40 IIIIIIIIIII'EEM IIIIIIIIIIIII11113 IIIIIIIIIIIIIIIIIIII.0 130.60 -128.06 Illllllllllllll:'5E FAIL- 2,900.00 2,889.5. IIIIIIIIIIIIIII 2,833.9. 2,088.54 MEGI 108 79 344.8 129.06 FAIL- 2,925.00 2,904.68 IIIIIIIIII 2,858.0. 2,904.68 356.90 IME ®��i1® ® !�� FAIL- 2,950.00 2,928.82 . IIIIIIIIIIIOE IIIIIIIIIIIIIII� 361.69 IIIIIIIIIIIIIIIIIIIl C ®II! FAIL- 2,975.00 2,952.96 2,906.3, 2,952.96 Man 92.08 370.69 ®MIRE FAIL- 3,000.00 86.76 380.03 MEIN�E 'y'i FAIL- 3,025.0D ! IIIIIIIIIIIIIII%E MI= MEE= MEEIIIIIIIIIIIIIII:2133 389.50 =NMI118.19 =Er II= FAIL- 3,050.00 MIMI IIIIIIIIIIIIIII! =ME !MI= 1•23M 76.69 MICE IIIIIIIIIIIIIIIII I® IIIIIIIIIIII!I�L)�1!ISE FAIL- 3.078.00 J IIIIIIIIIIIIIII 3,002.8: 3,049.52MEM =EMI 408.95 MEMIIIIIIIIIIIiI:i6�✓i.I FAIL• 3,100.00 MEM 11111312 =I= MIMIIIIIIIIIIII H NEM II! -150.98 :11:131 FAIL=MEM 3,097.79 3,097.79 ® MEM IPILE FAIL- 3,150.00 MIME NEM �' '. IMEIM 11.12M 60.0 98.19 -160.48 �� 1 FAIL- 28 January,2015-20:14 Page 15 of 22 COMPASS • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13.8-KU 13-8 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning MGM 3.146.0IIIIIIIIIIIIIIIr.�' 3.099.43 ®"' Mar MIMI MEE NM -166.10 FAIL- 3,200.00 MEM IIIIIIIIIIIIIII3! I !E !IX IIIIIIIIIIIIIIIIME IIIIIIIIIIII :MIME FAIL- MOE IIIIIIIIIIIIIIIIIE Miff= MEM 1111110333 =ESE 79.68 -178.99 IIIMEP FAIL- 3,250.00 485.09 MOE =ISE IIIIIIIIIIN FAIL- MEM IIIIIIIIIIIII =MI6 =IEEE ®" r ® !BE II!'I 168.67 =WEE 7IFAIL- IIIIIIIIIIIIIII! MEM IIIIIIIIIIIIIII. IIIIIIIIIIIIII!I MICE 1!111 MEM�1,0l FAIL- 3,300.00 ' IIIIIIIIIIIIIIIIEE MEE 8 MBE 505.66 IIIIIIIIIIIIIIIIIIII:1!7 MEM IIIIIIIIIIIIIIII1E MEM FAIL monatrmimmIIIIIIIIIIIIIIIIEf M3,29 9111 IIIIIIIIII0.. r2 MM 1 � ® ' FAIL- 3,350.00 3,268-41 Man IlEalE IIIIIIIIIII RI IIIIIIIIIIIII IIIIIIIIIIIIEE!E FAIL• r6 W !II 534.09 IIIIIIIIIIIIIIIIIIII•, �' i.', MEEr FAIL- 3,400.00 IIIIIIIIIIIIIII 3,316.69 MM MIEE IIIIIIIIIII EE MM IIIIIIIIIIIIIIIIIIII ® MEM!1E FAIL- 3,425.00 111MiS �'• IMEMMEM MIEN! NEM FAIL 3,450.00 mmirm =inn 3.364.97 MEMO Ell= 69.92 562.64 IIIIIIIIIIIIIIIIIIII mem =En IIIIIIIIIIIIIII FAIL- 3.475.00 MME IIIIIIIIIIIIIIIMM =MI MEM ! ®1!,r MEM f FAIL- 3,500.00 ''•,'i 3,459.89 MIE IM mom man FAIL- 6 E" IIIIIIIIIIIIIII"�''t.•� MIM 3,484.03 IIIIIIIIIII ®1!1:6 FAIL- 3,550.00 3,508.16 IIIIIIIIIIIIIII:EE MESE 3,508.16 RIM MEM 603.36 MEM MIME 31M FAIL- ®" =Me IMIE 3.485.6. MM94.96 613.99 1111 111=1M1 IIIIIIIIIIIIII®MOM FAIL- 3,600.00 =BEE 3,509.80 MEEM 111.1013 100.49 M FAIL- 3,625.00 =MEE MEM MIME MIME IIIIIIIIIIIIIIIME IIIIIIIIIIIIIEE MIME IIIIIIIIIIIIIIIII;3E inn IIIIIIIIIIIIIII:11E FAIL- 3,650.00 3,604.72 IIIIIIIIIIIIIII , 3,558.08 ! EMI MEM !MI 106.10 MESE FAIL- 3,675.00 3,628.8. IIIIIIIIIIIIIII 3,628.86 670.06 I IIIIIIIIIIIII2I' MEM 104.6. IS1 FAIL- 3.700.00 3,653.00 3.606.36 3,653.00 =1351 MEM 670.79 IIIIIIIIIIIIIIIIIIII.6 IIIIIIImm I®�i �� FAIL- i �• + 3,630.50 129.48 682.87 IIIIIIIIIIIIIIIIIIII� IIIIIIIIIIIIIIIII� IIIIIIIIIIIIIn9 9=KEE FAIL- 3,750.00 MEM NME =ME M r II! 695.00 I1 i FAH-- MEMME= �i 3,678.78 MESE IIIIIIIIIIIIIIII :1 ® r 100.03 i FAIL- 3,800.00 IIIIIIIIIIIII in MOE IMF= MOM MIMI IIIIIIIII II IIIIIIIIIIIIIIII II ® !XII!II FAIL- 3,825.00 W IIIIIIIIIIIIIEE ®'' W IIIIIIIIIIIIIEE !lf� !SIE 98.26 E FAIL - 3,850.00 3,797.84 Mom 159.83 IIIIIIIIIIIII&F I own ;;Em FAIL- 3,875.00 3,821.98 FAIL � 3,821.98 IE 166.00 MEM IIIIIIIIIIIIIIIIIIII�=ITC IIIIIIIIIIIIIII.W... - 3,900.00 3,846,12 IIIIIIIIIIIIILL!8.•, IImEsz mEn 770.48 mar® 96.08 NM= FAIL- 3,925.00 3,870,26 EWE = mom 1111.11M 783.80 MERE IIKE 95.46 NEM FAIL- 28 January,2015-20:14 Page 16 of 22 COMPASS • • Hilcorp Energy Company HALLIBURTDI*" Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13-8 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 3,950.00 =MC 10.96 MI= 3,894.40 illlllllll E Man Illlllllllll3BEI IIIIIIIIIIIIIIIIIIIlp ENEEE FAIL- 3,975.00 ( 3,918.53 MEE 190.90 ME !� y FAIL- 4,000.00 =IngS Elm 3,896.0 3,942.67 MEM =MS 823.88 IIIIIIIIIIIIIIIIIIII.6 ® IIIIIIIIIIIIIII.,W88r FAIL- 4,025.00 3,966.81 � 3,966.81 * IIIIIIIIIIIII'M1 837.69 mow IIIIIIIIIIIIII�IIIIIIIIIIIIIIm FAIL- 4,050.00 3,990.9 IIIIIIIIIIIIII1149 1E1E= 3,990.9 872.00 mum mum=me lam 92.89 MEM FAIL- 4,075.00 4,015.0• Imo 3,966.45 4,015.09 886.46 216.06 865.50 !� i FAIL- 4,100.00 ! IIIIIIIIIIIII l 3,992.59 4,039.23 900.92 =FM IIIIIIIIIIIII IIIIIIIIIIIIIIIIIIII� IIIIIIIIIIIIIIIII� IIIIIIIIIIIIIII:�w... 1� FAIL- 4,125.00 MUM ®� ' 4,063.37 IIIIIIIIIIIII I 893.70 91.69 IIIIIIIIIIIIIII J FAIL- 4,150.00 4,087.51 =BM 4,040.8 4,087.51 Mom IIIIIIIIIIIII1M12�.�, 908.15 IIIIIIIIIIIII� -10.00 IIIIIIIIIIIIII�IIIIIIIIIIIIIII� FAIL- IIIIIIIIIIIIIEE 4,065.01 =113EIIIIIIIIIIIII II 922.60 IIIIIIIIIIIIIIIIIII.6MEE 90.99 NEM FAIL- 4,200.00 MEM ® 4,089.15 IIIIIIIIIIIIIIIIIIII.6 MOE 90.6X111! FAIL- f f � MEPr� IIIIIIIIIIIII11 IIIIIIIIIII I=LEI FAIL- 4,250.00 4,184.07 = ®" ' IIIIIIIIIIF09Ut6 260.49 966.77 90.08 MEM FAIL- MEM f MIR =En =1E131 1,007.02 266.87 981.74 IIIIIIIIIIIIIII II® 89.80 IIIIIIIIIIIIII'® FAIL- 4,300.00 ® 996.73 MEM MEE =EOM!II FAIL- 4,325.00 =Ear mor 4,209.8 =MEE MEE� 279.64 =ME IIIIIIIIIIIIIIIIIIII� 89.29 I� FAIL- 4,350.00 4,280.63 IIIIIIIIIIIII'B 4,233.99 4,280.63 MEM'II 286.04 MEM IIIIIIIIIIIIIIIIIII� �89.05 FAIL=ainE 4,304.77 MEM l ®�' MEER 1�,042.91 EMIT® 88.82 0�.280 FAIL- 4,400.00 4,328.91 1,086.40 298.84 IIIIIIIIII�61l Ft=Um® 88.60 IIIIIIIIIIIIIII�WEN FAIL- 4,425.00 MEM 1 4,306.40 IIIIIIIIIIIIR MEMMI 88.39 IIIIIIIIIIIIIII '-„ FAIL- 4,450.00 NMI= ® MEM MOIME MEM MN= 1,090.07 88.19 0.286 FAIL- 4,475.00 MIME = F' 4,354.68 =ME ® MIME 1,106.09 MEM MIME 87.99 0.288 FAIL- 4,500.00 !MOM IN11133:1 ® 87.81 0.289 FAIL- r= 4,449.60 IIIIIIIIIIII K 4,402.96 4,449.60 Mil IIIIIIIIIIII M MEE MIME®' NMIIIIIIIIIIIIIII l FAIL- 4,550.00 MEER MIMEO 4,473.74 MEM IN! ] -13.88 87.46 Immcs FAIL- ®" 4,497.88 IIIIIIIIIIIIIIEII:E/ 4,497.88 EMII Mau IIIIIIIII E mum -14.04 MIME Illllllllllllll,WE5! FAIL- 4,600.00 - IIIIIIIIIIIII Y' NMI r MEM IIIIIIIIII II FAIL- 4,625.00 =IIME Min 4.499.5• 86.98 =BM FAIL- 4,650.00 4,570.30 =MI I I MEM IIIIIIIIIIIII=11 MEM IIIIIIIIIIII I MEE 86.83 IIIIIIIIIIIIIII FAIL- 4,675.00 4,594.4• IIIIIIIIIIII r11 4,547.8 ® 369.50 MEM MEI MEE86.69 FAIL- 4,700.00 ! IIIIIIIIIIIIIrIE !''I 4,618.58 MICE� IIIIIIIIIIIII MIMEIIIIIIIIIIIIIIIIIII�111!1IIIIIIIIIIIIII� FAIL- 4,725.00 4,596.0. E6L'QLi IIIIIIIIIIII 1 MEEME IIIIIIIIIIIIIIIIIIII!IIIIIIIIIIIIIIIZE !El FAIL- 25 January,2015-20.'14 Page 17 of 22 COMPASS • • Hilcorp Energy Company HALLIBURTON Kcnai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13-8 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 4,750.00 4,666.86 IIIIIIIIIIII t =TM 4,666.8• 11111116TS811 MECEE MEM !:MOM 86.28 � FAIL- I1 4,6914,691 001 ® 4,644.3' 4,691.00 IIID IIIIIIIIIIII IIIIIIIIIIWJIZLOl IIIIIIIIIIIIIIIIIIII.0®�1 86.16 I I FAIL- 4,800.00 4,668.5. MEM =313I1IIIIIIIIIIIIIIIIIIII.0 86.04 IIIIIIIIIIIIIII FAIL- 4.825.00 4,739.28 IIIIIIIIIIIIIIl.If 4,692.6' MIII:11 MEM IIIIIIIIIM1 MIME !III!I FAIL- 4,850.00 W IIIIIIIIIIIII7E '.) L 1,360.47 U® FAIL- 4,875.00 IIIMUM4,740.91 f�1 MPlPE, MIME IIIIIIIIIIIIIIIIIIIIll l 85.70 smem FAIL- 4,900.00 =Min IIIIIIIIIIIII l 4,765.55 4,811.69 1,436.06 IIIIIIIIIIII! r1IIIIIIIIII396.58 IIIIIIIIIIIIIIIIIIII•0® III 0.306 FAIL- 4,925.00 IIIIIIIIIIIII ti 4,789.1 4,835.83 I� 1.11:13112 IIIIIIIIIIE:iial IIIIIIIIIIIIIIIIIII!MIIIME 85.49 Mr= FAIL- 4,950.00 4,859.97 =RE mmmE 4,859.97 IIEEEE 440.45 MEM IIIIIIIIIIIIIIIEml Piez FAIL- 4,975.00 4,884.11 =an 4,837.4 MUM 1,492.85 446.91 85.29 0.308 FAIL- 5,000.00 4,908.2 4,861.61 4,908.25 IIIIIIIIIIIII� I I ®:1311 '.�I, mXyyy FAIL- 5,025.00 IIIIIIIIIIIIIIL'I��!I ® 459.83 1,488.66 IIIIIIIIIIIIIIIIIIIIU Illllllllllllll,5.' r., 0.309 FAIL- 5,950.50 =KM IIIIIIIIIIIIIM 11 4,909.8' MIME 1,550.60 466.29 Er=IIIIIIIIIIIIIIIIIIIIr'POmlan85.01 I I• FAIL- 5,075.00 4,980.6 ® 4,934.03 4,988.67 MEE imam Nam , -16.40 FAIL• 5,100.00 5.004.8 ! 4,958.17 5004.8 1,590.00 In Ima IIIIIIIIIII m �. '. I I FAIL- 11 5,026.95 MIZE 4,982.31 1,609.70 485.69 1,564.62 IIIIIIIIIIIIIIIIII.0 maim 84.76 I I FAIL- 5,150.00 ME= MIZE 5,006.45 5,053.09 MI= mg= 1,583.82 84.68 FAIL- ®.1 ME= MEN ESc.!4rJ MIMI 1,640.76 498.62 1.112MIE 84.60 FAIL- 5.200.00 ! .l�E 1,669.98 505.09 � FAIL. 11 ® Man ® 1,690.20 IIIIIIII IMI IIIIIIIII�Illlllllllllllllllllrlfl IIIIIIIIIIIII 84.45 IIIIIIIIIIIIIII ID FAIL- 5,250.00 5,149.6 IIIIIIIIIIIII! I I MIME !MINIUM (IIIIIIIIIIIIII IIIIIIIIIIII I FAIL- 11 ® IIIIIIIIIIIII! ® MIRE ® =EEC MEM 1 IIIIIIIIIIIIIIIS 111IIIIIII=1 IIIIIIIIIIII I! FAIL- 5,300.00 MEM IIIIIIIIIIIIIXE MEM MIME I IIIIIIIIIIIIIIIIIIII.0 MIZE 84.24 man FAIL - IIIIIIIIIIIIIM ! FAIL- 5,350.00 MEM IIIIIIIIIIIII1W15 5.199.56 5.246.20 IIIIIIIIIIIIIIIIIIII! I! MIMIC IIIIIIIIIIIIIII! FAIL- MEM MEM18.90 MEM MEE IIIIIIIIIIIII•EIEE 1,763.00 IIIIIIIIIIIIIIIIIIII.0 MEE 84.04 IIIIIIIIIII I! FAIL- 5,400.00 MEM IIIIIIIIIIIII 11•21133 MIME MEM IIIIIIIIIIIIIII M 83.98 MEM FAIL- 5,425.00 MEM EWE14 IIIIIIIIIIIII! 1.804.14 .0 IIIIIIIIIIII I IIIIIIIIIIIIIIh FAIL- 5.450.00 * IIIIIIIIIIIIIEEMEM 111! MUM 569.82 MIME 111111111111111111117'.1 rW 83.86 IIIIIIIIIIIIIIIFAIL- 5,475.00 5,366.90 IIIIIIIIII n 5Y�,366.90 I =NEImm= ® 83.80 IIIIIIIII 0 FAIL- 5,500.00I. 19.60 1,866.78 MEE ® FAIL- 11 MM ® , 1111=31311 MEM ! 1,887.86 ® FAIL- 28 January,2015-20:14 Page 18 of 22 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13-8 Scan Range: 0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 5,550.00 MOM MEMMUM 1,908.93 IN! ., ..� El MI "a". t" MIME MI! IN! ® MEM FAIL- 5,600.00 5,487.60 Min 5,440.9. 5,487.60 2,009.91 608.69 IMECIM mg= m®i FAIL- 5.625.00 MEM 1==lE MEM 1 • IG FAIL- 5,650.00 NM= MMEE 5,489.2' MEM MI= I! 1,995.07 FAIL- 5,675.00 5,560.02 =ME 5,506.0. MEE11IBM =NE . FAIL- 5,700.00 ! 5,506.0. MEM 1E= MEE 2,007.49 -18.00 IEEE FAIL- MICIM 5,608.30 =MEE 5,506 0 =ME IIIIIIIXEM111121111 M FAIL- 5,750.00 Mirran MEM 5,506.0. 2,007.60 �I „ FAIL- .. M. " MOM 5,506.01 MEM lam 662.26 2,007.66 MEM ffrl mom FAIL- 5,800.00 5,680.71 =GEE 5,506.0. MIEEM METE II! I! MIME FAIL- 5,825.00 5,704.8 =ME 5,506.0. IIIIIII•E 684.17 2,007.78 MINIM MEE 31m FAIL- 5,850.00 MEM MEM 5,506.0 MEMIE EMB 696.21 2,007.83 MEE 83.06 FAIL- 5,875.00 IMINSE 5,506.0. MEM WI= 708.93 2,007.89 83.01 lIFE FAIL- 5,900.00 MIME MIME 5,506.0. 11== MECITE MEM 2,007.95 . .. FAIL- .5.925.00 MEM MEI3 5,506.0. MERE IEMEIMEE 2,008.01 . ! FAIL- 5,950.00 MB= MEM 5,506.01 �.;, MIME 750.80 2,008.07 IIMENT -18.44 82.89 FAIL- 5,975.00 5,849.6' IMEE 5,506.0. 765.88 2,008.12 -18.48 82.85 3aM FAIL- 6,000.00 =.r =ma 5,506.00 MEECE MEM MEM 2,008.18 •i �� '.'� FAIL- 6,025.00 5,897.97 MMEE 5,506.0. MEM NM II! 2,008.24 MEM FAIL- 6,050.00 MBE 5,506.0. NE= inzza 814.06 2,008.30 FAIL- 6,075.00 IMEMM mom 5506.0. IMM MIEE 00 2,008.36 IMME MEM IMM FAIL- 6,100.00 MUM MEM 5,506.0. MEM= MEM 848.34 2.008.42 M -18.66 MEM FAIL=MME =117E4 5,506.00 MEC IIIIIII i76S1 866.06 2,008.47 82.64 ��!. FAIL- 6,150.00 6,018.6 5,506.00 2,008.53 82.60 MiiEI' FAIL- 6,175.00 6,042.81 =31M 5,506.0. IIMEM Emig =pm 2,008.59 MEE MEM Mr= FAIL- 6,200.00 6,066.9' MOE 5,506.00 MIMEE MME3 2,008.65 MIME 18.80 MBE MEM FAIL- 6,225.00 6,091.08 ® 5,506.00 940.24 2,008.71 IIIIIII iso 0.468 FAIL- 6,250.00 MIME =ma 5,506.00 Er= mass 2,008.77 -18.8. MRS IMIE FAIL- 6,275.00 6,139.36 MEC 5,506.00 =MI =ME 979.05 MEM -18.89 :E11:10 FAIL- 6,300.00 6,163.50 MIME 5,506.0. MIME EMI 998.83 2,008.88 MEM 1NumFAIL- 6,325.00 6,187.6- MIME 5,506.00 MEM EMME I '-'-1 2,008.84 mon FAIL- 28 January,2015-20:14 Page 19 of 22 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Offset Design:KGF 41-18 Pad-KU 13-8-KU 13-8 Scan Range:0.00 to 10,000.00 usft.Measured Depth. Scan Radius is 1,198.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 6,350.00°] M"` 5,506.0. M„ MEM 1,039.07 2,009.00 . �T j FAIL- 6,375.00 =BM M' I 5,506.0. =Ma EMS 1,059.50 2,009.0• FAIL- 6,400.00 6,260.0. Norm 5,506.0. =M11 NE= 1,080.12 2,009.12 ,. „...„ -19.04 NM= FAIL- 6,425.00 5,506.0' M.„ 1,100.92 2,009.1. — IIIIIIIIIIIIIirra 3monFAIL- 6,450.00 6,308.3' m 5,506.0' MUM 2,009.17 4 !XIIE FAIL- 6,475.00 MEM MEECE 5,506.0' =MEE MEM =OM 2,009.20 !1'7 IIMEEE FAIL- 6,500.00 6,356.62 MOE 5,506.0. MEM MEM MEE 2,009.2, — IIIIIIIIIIIlaxp FAIL- 6,525.00 II=MIE MEM ME= EMEla MESEE MEM 2,009.08 FAIL- Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 18.00 1,500.00 KBU 31-18 WP3 MWD+SC+sag 1,500.00 6,500.00 KBU 31-18 WP3 MWD+SC+sag 6,500.00 10,000.00 KBU 31-18 WP3 MWD+SC+sag Ellipse error terms are correlated across survey tool fie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 28 January,2015-20:14 Page 20 of 22 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Prelim:KBU 31-18©84.64usft.Northing and Easting are relative to KGF 41-18 Pad. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00°,Grid Convergence at Surface is:-1.08°. Ladder Plot N 150 O L o .CO a 100 LEGEND � i $KU 13-8,KU 13-5,KU 13-8 V0 -}KU 41-18,KU 41-18,KU 41-18 VO r---- r----1-- —r---- ----- ----7 7 $KBU 31-18WP3 C 0) U U 0 50 -----'----- ----a a 0 0 1500 3000 4500 6000 7500 Measured Depth(1500 usft/in) 28 January,2015-20:14 Page 21 of 22 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan: KBU 31-18/KBU 31-18 WP3 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor 11.00 --... _._--- --- --- - \ ; 1 _ 10.00— -.__ ..--- `--- ---'i--`- ------'--- s.00— 1 6.00— .-_ — --- I - ' S 1 -.. 7.00— _— — - ----` --------- t 0 io _ N - 6 O 6.00— __-__.. _____-- - - 4. Yel - LEGEND c 5.00— _ ----- _---- ----__ . ;-_-- ^ _ ::. : --- KU 13-8,KU 13-8,KU 13-8 VO R _ I_. _. 4-KU 41-18,KU 41-18,KU 41-18 VO Et- 00_ ._.. Y 3.00 � — ------- ----- - '---- i 2.00— -- Collision Avoidance Req , Zone-Stop Drilling'" ' ---------- , 1.00 MO- iiiiIi II II I IIIIIIiII 1111 i 111111111lj ll1III I I IIII 1111111111111 11111 11II 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 Measued Depth(1500 usWin) 28 January,2015-20:14 Page 22 of 22 COMPASS • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, February 18, 2015 8:56 AM To: 'Monty Myers' Subject: RE: KBU 31-18 (PTD 215-024) Monty, Thanks ... looks like you will be getting closest to KU 13-8 at about 3200 ft. and with the new well KBU 31-18. The well was P&A but only has a cement plug at surface casing shoe (1200 ft). The rest of the wellbore is open hole down to 5506 ft so no casing to intercept if you happen to get close. Updated BTC sheet looks good. 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.schwarfz@alaska.gov). From: Monty Myers [mailto:mmyers(ahilcorp.com] Sent: Wednesday, February 18, 2015 6:54 AM To: Schwartz, Guy L (DOA) Subject: RE: KBU 31-18 (PTD 215-024) Good morning Guy, The KU 13-8 well was P&A'd on 12-8-1964 after being drilled and completed it was a dry hole. See attached pdf document. And you are correct.The tension rating for the BTC is 721klbs. I have updated that sheet and attached it as well. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office:907.777.8431 Cell: 907.538.1168 From: Schwartz, Guy L(DOA) [mailto:guy.schwartzOalaska.gov] Sent: Tuesday, February 17, 2015 3:19 PM To: Monty Myers Subject: KBU 31-18 (PTD 215-024) Monty, 1. Please supply some backup info on the close crossing seen with well KU 13-8. There are lots of red flags in the collision summary. Also, can you double check the BTC calc on the 7 5/8"casing? Looks like the tension SF is off. 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.clov). 2 • • Calculation & Casing Design Factors Kenai Beluga Unit DATE: 2-18-2015 WELL: KBU 31-18 FIELD: Kenai Gas Field DESIGN BY:Monty M Myers Design Criteria: Hole Size 9-7/8" Mud Density: 9.5 ppg Hole Size 6-3/4" Mud Density: 11.5 ppg Hole Size Mud Density: Drilling Mode MASP(sec 1): 1254 psi (see attached MASP determination &calculation) MASP(sec 2&3): 1977 psi (see attached MASP determination &calculation) Production Mode MASP: 3332 psi (see attached MASP determination &calculation) Collapse Calculation: Section Calculation r 0../316i) 1,2, 3 Max MW gradient external stress and the casing evacuated for the internal stress 4'1 et " Casing Section Calculation/Specification 1 2 3 Casing OD 10-3/4" 7-5/8" 5" Top(MD) 0 0 0 Top(TVD) 0 0 0 Bottom (MD) 1,500 6,100 10,000 Bottom (ND) 1,500 5,900 9,683 Length 1,500 6,100 10,000 Weight(ppf) 45.5 29.7 18 Grade L-80 L-80 L-80 Connection BTC BTC DWC/C HT Weight w/o Bouyancy Factor(lbs) 68,250 181,170 180,000 Tension at Top of Section(lbs) 68,250 181,170 180,000 Min strength Tension (1000 lbs) 1040 721 457 Worst Case Safety Factor(Tension) 15.24 3.98 2.54 Collapse Pressure at bottom (Psi) 741 2,915 5,035 Collapse Resistance w/o tension (Psi) 2,480 4,790 10,500 Worst Case Safety Factor(Collapse) 3.35 1.64 2.09 MASP(psi) 1,254 2,232 3,332 Minimum Yield(psi) 5,210 6,890 9,910 Worst case safety factor(Burst) 4.15 3.09 2.97 • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, February 05, 2015 6:06 PM To: 'David Duffy' Subject: RE: KBU 31-18 (PTD#215-024): Property Designation Question Thank You! Steve Davies AOGCC 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. From: David Duffy [mailto:dduffy@hilcorp.com] Sent: Thursday, February 05, 2015 5:13 PM To: Davies, Stephen F (DOA) Subject: RE: KBU 31-18 (PTD #215-024): Property Designation Question Hi Steve, I've attached a copy of the Kenai Unit's exhibits. Per your question below,Section 18 falls within Kenai Unit Tract 14. See exhibit A(map)and Exhibit B(table, page 2). Hilcorp is the 100%mineral owner. The leased acreage is 1478.90. The lease number is "FEE ADL 22330." This should track with the information on the PTD. FEE 028142 (also described as Unit Tract 26) lies immediately north. Hilcorp also owns 100%of the minerals on this tract. Measured from the TPI of KBU 31-18,the unit boundary is—5800 feet; within the unit,the nearest point where property ownership differs (Tract 27B) is^'3500 feet. Please give me a call if you need additional information. 1 • S 278 176A I ea, 6 tobe39! 27 kb. ,aSK.. 1tQ 3 KJI ft;/fM 27B 2YY' KEN.(SMT , 177 I s0000++w RA: :4 ro4 OMB "14 ideli� 16 27 David Duffy, Landman Hilcorp Alaska, LLC Direct: 907-777-8414 Cell: 907-301-2629 dduffy@hilcorp.com This email may contain confidential and /or privileged information and is intended for the recipient(s)only. In the event you receive this message in error, please notify me and delete the message. From: Davies, Stephen F (DOA) [mailto:steve.davies©alaska.gov] Sent: Thursday, February 05, 2015 1:35 PM To: David Duffy Subject: RE: KBU 31-18 (PTD #215-024): Property Designation Question David, The reason that I asked is the according to the information posted to BLM's ACRES website, Section 18 didn't appear to be included in the legal description for A028142. Is this correct? If so,which lease contains Section 18? Thanks for your help! Steve Davies AOGCC 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 2 • • 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. From: David Duffy [mailto:dduffy(ahilcorp.com] Sent: Thursday, February 05, 2015 1:07 PM To: Davies, Stephen F (DOA); Monty Myers Cc: Judy Stanek Subject: RE: KBU 31-18 (PTD #215-024): Property Designation Question Steve- MapMakers data is not current. Over the past several months, BLM has segregated various federal leases within the Kenai Unit. This required splitting former federal leases (jointly joined, e.g., by the state,federal government and CIRI) into separate leases. This process also required a new naming convention for the former federal leases(e.g.,A028142 became FEE A028142). The latest Kenai Units are under review by BLM. After BLM's review is complete, MapMakers will update their data. Regardless,we'll I send you a PDF copy—and this should clear things up. Thanks, David From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Thursday, February 05, 2015 12:49 PM To: Monty Myers; David Duffy Subject: FW: KBU 31-18 (PTD #215-024): Property Designation Question Monty, David: Could you all please check the Property Designation information that is presented on the Permit to Drill application for KBU 31-18? The lease number provided may not be correct. Federal/Fee leases are somewhat difficult for me to check with the resources that I have available. (The map from MapMakers,Alaska is just too small in many instances.) Thank you, Steve Davies AOGCC 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. From: Davies, Stephen F (DOA) Sent: Thursday, February 05, 2015 11:19 AM To: Monty Myers (mmyers@hilcoro.com) Cc: Schwartz, Guy L (DOA) Subject: KBU 31-18 (PTD #215-024): Mud Program Questions 3 • • Monty, The mud properties section on page 38 indicates that between 6100' and 10000' MD, the mud weight will range from 10 to 11 ppg. If I convert the MDs to TVD5 and then plot those mud weights as points on the Offset MW vs TVD Chart on page 60, the planned mud weights below about 8500'TVD fall significantly below the mud-weight profiles for offset wells (11.5 to 12+ ppg). Questions: 1. What is Hilcorp's basis for selecting 11 ppg as the planned maximum mud weight for this well? 2. What are Hilcorp's contingency plans for increasing mud weight in the event of an emergency? Thanks, 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 7`h 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. 4 0 Exhibit A Kenai Unit Effective October 17, 2014 I� T}i66D 147 146 24mi MI 24 24A 48 24 178 -1 149 5N12W j 5P:i 11,',1 152A 3 115A 1 21- 5 15 I 5B 13 153 5A i 154 --4 ---__ 175B 155 ' s ,175 4A i___ 1 175A 4 j 4B 48 .2_741 1 1B 21.22. 71 176B 38 27B. —f'. 26 '1 _76A 1A 27 { 32: fi ' — N2W 3-39 1 411W 177 27B 1611- 14 6 J14 40 27 1 17 rMINIIIII. 14A ®Kenai Unit Tracts I February 1, 2015 Hilcorp Alaska, LLC Scaie: 1:55,000 0 0 CO 0 E % § / K_ § § \ as ( (° S S § §S co \ \ } / §3 § < < < ) < <CI k§ ) ƒ a. ■ E § k o k k a. .5 ° B S S S z ) T ( I I I I f»; kTs/� o f 2 F 7 § 2A , . k; a a @ @ £ @ e K a t| 0 0 0 0 1:2 to to 2 •z b b - - § a 2 a » lit — 0 N ^ § 0 03 4) \ § g @ ..- 4m, a R 2 k / 0 - 0 6 ± )4 § 0 ( K ) ) ) a ) < W @ 0 i 0 ® 0 § > ) 2 0 w re§ o U 2 0 ( < g S S k < k <$ & § I # I & I CO ii co co co 0 e® a® LU CO ^ ®�® «= 2E 2 N \ |§ CD § } [/ §( §c \ <V COH it 9 «Ig 1�jo9 o <oo % e <oo ? /_4 3•-. < § -< < U_< < r< << aOs 0 o m 2 $ ; n = - co` _ } } § .-2 -r., k §ƒ ®`0: a) 7 ) \ ) ( 0 CO z \7\ 2 15 A +) 2 { - \ § k \\ it lc' cci Zz § rc§ \kk �\ \ £ ''§ )®+ 73 .. - ..%t .. ■�; ` 2.o /\\ /($f§ W /r d� /A} / \\j )\\ (U. k - z=® -5 5 =7! «z iri )k] §meq\> /«¥ 1- .. / .. ..m 4 -.K k meq 4mm 4mR \ 7C!. �w .. t- ; g ; g. c �6 �COA =; - Ci �\k kkkkk )$k . I-- /// jkk §§ 1-f) :u w . . _ 0 0 an r «�� in0 t»� 2 k z , f f _ # ■ , a in _ • • CO 4- 0 N a+ e 0 a a a a a e a .a m o o g o $ o `8 o c m co U 0 0 U 0 V U U 0 C C J J J J J J J J J 0 CO CO 0 s CO g s d d c m d < 4 ¢ ¢ Q d < d 'o= a a. a. a a. a. a a a E O0 0 O0 O O O0 O O 00 0 0 0 00 J JJJ J J 3a I I I I _ I I I I Co _. c 1A a a a 0 0 0° 0 a �+m o 0 0 o 0 0 0 0 Ic .W e- r O 2, Z J Z J Z J ZY J Z. 0 0 HN <a: Ha Ha Fa 0 o , U Qr): 0 0 c . . 0 \ / \0s \ \o II ir \ 0 \ ( « / & / ��s en < } } ) co 0 • \ Cl. a. / ( ■z £ I e I I .E Z.; 7a| J■I A" ■ TD ¢ 00 - . . f£ 0 0 0 0 0 I2 7 _ 41,_ 0 011 a K/£(«($ k �m/m[ 44, _ ° Ca c 6- ® - \ 0 .- 0 ® 42 2 j • ) co e ■ 7)ƒ �$ W \ os C /k-�ka2ƒ > ° § 0 0a $//�k §22 3o teta� .\ 0 §a 2kƒ4>;i2 Q / . . W f 2 euso es us oC ai # _ 1 co oi § CO us ) § -- to 0 § 3 2 #2 Z .£ 8 u .®/��%:3 M) e3 ;$\ 2 )) m !m a L. •7 = cfl _ _ 0 V" P. a= a oR e a 0 a al.m. 8 $ 0 0 o o o eac c c J J J -J J J a X c a ril o ¢ 5 (0 5 co CO 5 c a < < a 6 ¢ Q d c c a CC a K K Le a. �}' 0 0 0 0 0 0 pm J 0 0 JJJJ p, S x ,x S .S x 2 a c gs w 72 E > 0 m o c O g' m 0 ° rea c v t• c 68 A.c a a0 0 0 o 0 m u0) {Of), t0q . 0 40') u0) za N N N N N CV Cii eF ..t- 0 0 N P.• * ado 0 0 uN V" N o 0 O N *e 0 O O N N m E /L�. �$©ocev`_'e dCa a°3$Ncmv o ��e p a 3e 2e 0 o go r ii R�u)Nu)�nn O.16 ui 6 nn Ot a O to p op O�'H •N88000004 W O $ $ '� J 'ui ui Lc, N •�O� 0 Q Q t •= 0 m to 2fr. a cm mo- Borg cW m au°g, ggo <a g.g. 2 2 -mg x 0 0 3 aLm2 11 ELLOm ° o-°a� mC�mEtinaEEm $m W $d�av -' as• tea W Y ly "-' cU�r � i�c�xm� �gin� m�'��°� v, c�QQaT m E - 0°°rt m �o 4,0 .30 s c� c� W q `0 E. m�Z,E c m „=Mace 'o m U J.cO c ccc'ux2 a"Tcz•cr'c = cE EZ',_ ° > rt0— c_ 0y 1 m J cwJ 'cn m 0 v ° m m m m m m m c cgp m N fp p- W.c'a m —d =t T= O ° O - V 0Clw2Z>022-50a��Smm- ,xF•c>m YYxviaoo ri a ��x d W E 0 Z m COdi m J mS la m r N O W b au N U) u) u) Q m .p c w J z ca c U p co a g .4.3w N Z N to z el *b `' *tc O c U)N 5 CO ° U)- w ° ms N J y J J j J j J 01 O ,r) 10cO H W CI HN Ft0 OA CD CO 00O) N N r) V a to ° v u1 r ^ 4f1 M F z J • • (0 1 0 E 0 0 0 * 0 e .em S 0 0 S 0 0 0 C C J .-.1 J J J ...1 J Y Y Y X Y In'3 co co c U) c c a a a x rc cc rr . O O0_ 0 00 00 0 00 p . J J J J JJ 3 I I I I I I I co C cy+.m o P.a : o atKom o e O R T 0 .k iz C 6 C 0 t1 Y O g co2 .m o 0 0 0 0 0 0 o U) to to c0 cn N in d' Ir. O N P+ $ T'" 11 C S. 0 J aO O S S O ,Q 0 c 1 Y Y Y Y Y s ` m a g g co co 5 W O O 0 a LL LL LL LL LL U Q' O O O O O m 7 H H F i- F .Fr c 'c -J I..- IQ- I-- F F v 5 D 2 N to N N (0 Cm O M N 0 W E co a. N W aM) O to 0 CI J el Jin -I In J to Q cn J Q n Q 0 JLL Q Q Q W O o Na) M o O O c0 O M O �cpp N m r l) i�7 < CS to O esih N W V C N N <N a 2n s 3 v g �c = Nz`� = c y v Z v 3 N N N Z 3 O } C Z2 N N N LL Lo N Z 3 co W roc c0 G c .0 m V O C C_ . .s L t c 3 mN w ; .c L d 3'§vv a W m c c m 45 a'C » N a� W Lo ig = Y�N On CU Z V a V 8a y •N N , Q rn m N m g rn`O c c E' e a 2' = w o w e E Lo 0.O mco $ v ,,3EJE 0 aH » 0) c (A z U� c w co U? P, C�Z? .0 U.° CA N N¢Q N c 3J 3z 3a.°--.•o zi 3 -,, 3a ¢ �'Qa rn 4 c0 r aQ .-O? 03 - .,+��M .N- '.jN N Q r Ne�-r N r. .-M r r r M(AMZ e-MU M. Nt0 �j 3 r m ZS t V N cn g 'p W �i yi W 2v_ Lig-v- 2 2(4. 2 V m 9v 2 Q v �i �i �i �i O !-co F F co,c.2 I- 0 0 W i-(0�S co Vl W co F-co W co!U I-to to fn(n "0 di CU co 0 r -os D 0 0 0 0 CD -2 8 8 cc 0 S �k / \ c\ < < 0 0 -§o £z I !/ 7»! )}) { 0 f T . 00 . . 2- @ ® To ( t § cca. V V. f 0 I- ca 7 ® / k C4 \ \ c Q ■ ) .5 W 2 2 cii L.L. & > (G 43 I A\g R ) }§\\\ i 8 el 0 V CMt ot } & \ § \ I z � 0 0 \) , \ § § 2 / % #2§ f{ƒ }I e ±j+ §/ ® ui —� ; Q} \\\ /kk ( 2 0- k) [ ( • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, February 05, 2015 2:02 PM To: 'Monty Myers' Subject: RE: KBU 31-18 (PTD #215-024): Mud Program Questions Thank you! From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Thursday, February 05, 2015 1:59 PM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: KBU 31-18 (PTD #215-024): Mud Program Questions Good afternoon Steve, Hilcorp's basis for selecting 11 ppg max is a typo.This should have actually said 11.5 ppg. During the drilling of several recent wells in KGF we have attempted to keep the MW as low as possible to prevent formation damage to the production hole. We have used the PWD tool to monitor real time ECD's,to help us keep the MW near the actual formation pressure. Our contingency plan is to keep enough Barite on location to weight the mud up in the well to an extra ppg over current MW in the hole at any time. We always keep plenty on standby for this. ✓ Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Thursday, February 05, 2015 11:19 AM To: Monty Myers Cc: Schwartz, Guy L (DOA) Subject: KBU 31-18 (PTD #215-024): Mud Program Questions Monty, The mud properties section on page 38 indicates that between 6100' and 10000' MD, the mud weight will range from 10 to 11 ppg. If I convert the MDs to TVDs and then plot those mud weights as points on the Offset MW vs ND Chart on page 60, the planned mud weights below about 8500'TVD fall significantly below the mud-weight profiles for offset wells (11.5 to 12+ ppg). Questions: 1. What is Hilcorp's basis for selecting 11 ppg as the planned maximum mud weight for this well? 2. What are Hilcorp's contingency plans for increasing mud weight in the event of an emergency? 1 • • Thanks, 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 • • Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Thursday, February 05, 2015 11:03 AM To: Davies, Stephen F (DOA) Subject: RE: KBU 31-18 (PTD #215-024): Surface Location Verification Good morning Steve! Sorry about that,the survey from page 11 is only showing the rig orientation on the pad. The PTD, page 2 of the drilling program, and page 59 should have all the correct surface locations.The actual As-Staked from the surveyor is page 59. Let me know if this clarifies your question. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Thursday, February 05, 2015 10:54 AM To: Monty Myers Subject: KBU 31-18 (PTD #215-024): Surface Location Verification Monty, For KBU 31-18,the surface location listed on the Permit to Drill application form and that on the surveyor's plat on page 11 are different. Which is correct? Thanks, 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. 1 • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: l<661 3 l /E PTD: Development Service Exploratory _Stratigraphic Test Non-Conventional FIELD: �-�'tA-.:-, S POOL: ' `t Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) 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 Pilot Hole name ( PH) and API number (50- - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 5/2013 • ! 00 N 0) o d N 3 . w o' o . . . . . . . . ; . U a) N, o`, O . . ' ' 6c: 7)' pmc . . . . , w . ; d (• . . o (6, V/ N, N ea NCD N a _c rn c, y, CO O. Cl), •D 1 -o °, v, a>, 2 �, v. Z O 3, u>, a>, -c. °> ° o c ° a a>, co y, c o, , . o. w m 0 •N E. C, o N N. N, 0 Z c, H. (VO• : (°i ar �' a). 3, O � E. c a o. S,ti c. rn , , , , , 2. 4 U; , 2, c •3 o a>, Fx w `r> ° m, a• °i o w, �, d. , .c _ a) 3. a� 'C L C N O y , y O, - Vl 0) 1 ii D 3. E� o. V• O, U N. y. . 0. c 0j, �� n . c E, C =p O op x o e . N' 3O. y. �, �> . . o c 0 O Ln >,^ a> - u, 0 d 13 a> = v 3 c. o co m, y. O. v. 0) o Z c. °' w 3'. ; . H, , eo 2, c. a), a , o, °o`, ° 3 m, .-E ' a>. a>, 3. O; - o U. 4 0 3, �. Vii, °o' Q - A p. �, a> 3. C, O, O, r, °� U� N, �.� �, w� a N� � N, 0, y� Q ° o ' 0. N, ca. , °, , U, NO, o, a a , ca> o,W ° � a mO, U, .y, 2 3. 1, , �� OO. H . F", - 3o, , , O, a, a v, , s , 0, O OCN o 2 , v, 0, _ , o. _0, CO, y. v) , 3. . 'a , .0, >. y. N. a , 0. �, O. 3. �. 4 •a> a; . c °'' o U L; v, , . , . ; '5, '�. . c '3, 1), 8 N, 3, a -c, M, . o X 2. 0, c, E Z C' m, H• a0' >, c, C' a, , C, c, j Z. co. U. N. 7•. (_p, I7. 7. .O• 0. -O, d, = O U, U, 'y. y °, u). 0 C, a• , N. C C C. 7. >` - a> ❑ 0 N, (_ 0 0 u>, N a ' ., , \o, 0. U. L, ail, o, x. X, �. a) co' c' y, y`. z 0. O. p, p, 0 °. y. (D, 0' ' V) - F.•. M. >, °. °, <' p. N. N. (0, 2, 8. 8- w O. Y, Y. U, o) < v, CO , r-, cn O. �, p, U), g, Z. _. _, a, a u) -0 aZ N , , , -0 w , , , , , , , , , , . , , , a) o , , , , , , , , , , , z N', N, N; (8', N', N', N N, N', 2', N' V> ((A N , N N N N N> N N' y' N N N' < 0 a>, a>, a>, a>, a>, a>, a>, a>, a>, m, a), Q; Q, Q; Q; N, a>, m, o, a>, a>, a>, 4; a), ¢. a), a,, a), a), m, o, Q; a>, a), ¢, Q, ¢, n Z' Z >-, >-, >-, >-, >•, >-, >, }, >- > >., Z Z Z Z }, >-, }, Z >, >- > Z >-, Z >-, >-, >-, >-, >-, Z Z >- �, Z Z Z \ > co ; , , . , , , , " 0a E, 3, �, , , , . , 45 o , , , , , , , , , , N .0= N'iS V Q c' L p, , a E Tr , o E. 3. p 0 , c' Q 3. M. y. 8 Z 8- (..9 do cZ, ° � a , ° , W o. N Z t yy, a , p) ' . , E , , ,O O , 0 . p' (NI iy w. OG NQ , u) X ' , V - , .i . a , .J ,. po 0) . .13 0 a), D pO . N N 2' C' a)' 0, ' a °. N, t, ❑ D .-: N , aN -p, aV , . e6� 0 , �� , N 'p, , 'y, 00, ' �.:- ah C, , 0 Cal of 3, •� , ° >' 3 0, °o ° co. , N u y N �' , c' o, -'' a 3, , cc, v, o. N co J . t 0) ' ac Z y'. m ,. 3. 9 `o' ❑v) C. c) z, °ts' c. y, '. .� -- �, 0. ' Q. y. y. c. 11J U• 0. C, .D, , p. p, 'C �. °. •N. a D O. c. y. co. p. O, 0) 0, a, L. , C. �. Cr c-, 0 .. CO c a), , w, N, M, N� >� V, `- >, 'O� 4 a) y ti)c C O� O, �' pi° E, E .- -O, C C, E r N O M' C C y F-' C O ea' « C C. w a> o. N L O: C C p p c, z, ; v. (o•). 0, m, N, o o, Q, , o3, p. Ci 13. 0,, a a, O. 6, -, •a a a, ° �, 3. o > m, 4' m Z ' d' O' w C' O 7 0 °, 10 03 , O• Y O, 2, w 0 °. c0' E' .0. '0, 0. 5-.C' N, a' cis! >: O, rn p. p. C v1 n c°� (� a>. c o, m E Y -J 22, c c, c, �. as, °. L L• .o, (0. o. N, -o, (0' O .)C, d N. aa>), V-•. 'I, •a-, a). p). 0. . - , mc' oO,' '-'-•-•,' m w CCmma a ' a). ° ° v, E, O. . ' , 3 ( M °. a), o >, ° Noa8' 3Omj c n. ai yal m 33; o, a) y (3y � O ac • ° N ma' o E > ., 0 -- 0 . - o >. , Y. a) oN. m, a Q °, ' o -c' 4-' 0 ° o. w, 0, a, o' �. o 0. -, pco, EoCap. o, o, c. u ° -o, m °. ° oo, 0) c, o, N, N.acn Oa a) a `• Vo0o0 � v ° a) 0,5 ,c a a). 0 a a c ° . a co ya :c' v .m , a � °, °' ' o' Oc 0 N, _ yp rg' c, t, -o Qv ° ECf, 0. o. , rd4 .N, .N. °. , N, om 2mc, co , o' ' QT 'o, o, . _ °, y, 2o a m `a> c . a a mN, > , y °. o. 3, Cv' ) •c, 'c o, o, a> C ( 9 . 3o, oy ;, C, a, LL ( .0 'O '0 -p, °. • C, 0. aa. a. -O w. C y. N 'g. 'O, >. .m . LN3 N . ON •E0 OV. 9, C (6. E O 2 3 d 9 -.(1')' . O, =' C, CE ')2' 9 oa ° ° 3 2 + , ° � o ° Oc °, C. NN, C ' c U C ° 8 Co ymo U. 0o No > , oo •° c2 °s E E °, o ° 8, V) ai ooo' ; ° o c . N, > 3 ° �' °. -9, ° 0 N' ° w a , v. T.) E ✓ >, `m: a°), .c °. p, o 3 '0, a Q E E) � a, 3, E o, o. ? 2 2 m, ' °, o, 0 c O, Oo. p, a y o' co y; 3' o, O ca, _a, D 5; 5, 5, 0' ) OO' a aU, 5' Q; az, U, (nUUc� UQ ¢ 'c 0, co; U, 5' -T, 2, a ❑ co, cnU, W a O N M (L) (O h. 00 0) O e- CN () A 1,:), (D i` 00 O) `0?) ;- N M V' t(> (D 00 O) v- N M V U) (D N- CO 0) �- �- e- �- �- r �- �- N N N N N N N N N M M M M M M M 0N--) M M V•.. U _ a) • O C 0o w o y o c V O U ° ❑ 1- ° N a ° N ❑ oyl 0 0) O. (() (V .0 N N y NH 0 O N O w aIE a ❑ .c a � 0 a ❑ 0 a Q Q w Q C7 Q • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplrfy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infor l ration. Technical Report Title Date Client: Hilcorp Alaska, LLC Field: Kenai Beluga Unit Rig: Saxon 169 Date: April 4, 2015 Surface Data Logging End of Well Report KBU 31-18 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: Hilcorp Alaska, LLC Rig: Saxon 169 Well: KBU 31-18 Field: Kenai Beluga Unit Borough: Kenai Peninsula State: Alaska Country: United States API Number: 50-133-20649-00-00 Sperry Job Number: AK-AM-0902208266 Job Start Date: 13 March 2015 Spud Date: 14 March 2015 Total Depth: 10010’ MD, 9803’ TVD North Reference: True Declination: 16.646° Dip Angle: 73.431° Total Field Strength: 55325 nT Date Of Magnetic Data: 18 November 2015 Wellhead Coordinates N: North 60° 26’ 35.3997” Wellhead Coordinates W: West 151° 14’ 37.2662“ Drill Floor Elevation 84.86’ Ground Elevation: 66.86’ Permanent Datum: Mean Sea Level SDL Engineers: Jeremy Tiegs, Autumn Gould, Jacob Hansen SDL Sample Catchers: Vince Mireless, Chris Medeiros Company Geologist: Jacob Dunston Company Representatives: Rance Pederson, Shane Barber, Doug Yessak, L. Toussant SSDS Unit Number: 117 Monitoring Gas Equipment Summary:Baseline 9000 Gas Analyzer Baseline 8900 Gas Chromatograph Matheson Chrysalis Hydrogen Generator Critical Spare Gas Equipment Summary: Baseline 9000 Gas Analyzer Baseline 8900 Gas Chromatograph Matheson Chrysalis Hydrogen Generator HOLE DATA Dates Drilled Hole Section Total Depth Mud Weight (ppg) Inclination (degrees) Casing Shoe Depth MD TVD MD TVD 03/14/2015 – 03/15/2015 Surface 1520’ 1520’ 9.05- 9.15 0.13° 10.75” 1476’ 1476’ 03/18/2015- 03/23/2015 Intermediate 6354’ 6213’ 9.1-9.2 14.26° 6.875” 6338’ 6198’ 03/26/2015- 03/31/2015 Production 10010’ 9803’ 9.3-11.7 15.68° - - - DAILY SUMMARY 03/13/2015 SDL continues on location from previous well. Spot and set MWD and mudlogging shacks. Wait on the unit to warm up before rigging up. Pipe shed was loaded with drill pipe and heavy weight drill pipe. Began rigging up gas equipment and ran gas line to the unit. Tagged at 120’ MD and began to pick up BHA at time of report. 03/14/2015 Spudded well and continued to drill ahead. Drilled to 488’ MD and made wiper trip and serviced rig while inside the conductor. Drilled ahead to 1,354’ MD and drilling ahead at the time of report. Gas: The max gas was 72 units at 1383’ MD and the average drilling background gas was 6 units. Fluids: There was 0 barrels of water based mud lost down hole. Geology: The samples have been predominantly translucent to clear, occasionally white, very fine to fine grained, sub spherical, moderately to well sorted sandstone with trace amounts of siltstone. 03/15/2015 Continued to drill ahead and TD at 1520’ MD. Conducted a wiper trip to 555’ MD pulling on elevators and then RIH to bottom. Tripped out of the hole on elevators and laid down BHA. Rigged up Weatherford and ran in hole with 10.75” casing to 1513’ MD. Currently attempting to seat casing hanger at time of report. Gas: The max gas was 79 units at 1364’ MD and the average drilling background gas was 5 units. Fluids: There was 0 barrels of water based mud lost down hole. Geology: 80% Siltstone: light grey-grey, soft-firm, silty, non-calcareous, swelling; 10% Sand: clear-opaque, white, light grey-grey, black, lithics, quartz, course-fine grained, moderately sorted, subangular, subspherical; 10% Clay: light grey-grey, light brown-dark brown, plastic, blocky, silty, amorphous. 03/16/2015 The decision was made to lay down one joint of casing to be able to land the hanger. Pressure tested cement lines and lost 67 bbls to hole while putting cement in place and got back 50 bbls of mud push and 48 bbls of cement to surface. Currently nipple down stack and nipple up BOP's at time of report. Gas: The max gas was 72 units. Fluids: There was 0 barrels of water based mud lost down hole. 03/17/2015 Finished N/U BOP and tested BOP's. Pressure tested surface casing with good results. P/U 156 joints of drill pipe and reracked it. Picking up drill pipe at time of report. Gas: No gas to report. Fluids: There was 0 barrels of water based mud lost down hole. 03/18/2015 Continued to pick up drill pipe and then made up BHA. Ran in hole to 1357' MD and tagged up; drilled out shoe and 20' of new formation to 1540' MD. Displaced mud over to 6% KCL mud and performed FIT test to 12 ppg. Passed FIT test and continued to drill ahead to 1904' MD at time of report. Gas: The max gas was 122 units at 1885’ MD and the average drilling background gas was 7 units. Fluids: There was 0 barrels of water based mud lost down hole. Geology: 80% Siltstone: light gray-gray, soft-hard, blocky, non-calcareous, swelling; 10% Sand: clear-opaque, white, black, lithics, Quartz, medium-fine grained, well sorted, subangular- angular, subspherical, trace consolidated sandstone; 10% Shale: dark gray-gray, firm- moderately hard, blocky, homogenous, non-calcareous, non- swelling. 03/19/2015 Continued to drill ahead T/ 2029' MD and pumped a Hi-Vis sweep. Drilled ahead T/ 2341' MD and drilled a Hi-Vis sweep. Continued drilling ahead T/ 2522' MD and pumped an additional Hi- Vis sweep. Wiper tripped to the shoe and RIH to bottom with no issues. Drilled ahead T/ 2896 and pumped a Hi-Vis sweep with 50% cuttings increase at shakers. Drilled ahead T/ 3143' MD and pumped an additional Hi-Vis sweep with a 40% cuttings increase at shakers. Drilled ahead T/ 3517' MD and began POOH for wiper trip. POOH at time of report. Gas: The max gas was 147 units at 1963’ MD and the average drilling background gas was 7 units. Fluids: There were 52 barrels of water based mud lost down hole. Geology: 40% Siltstone: light gray-light brown, soft-loose, blocky, amorphous, non-calcareous; 40% Shale: dark gray-gray, brown, firm-hard, blocky-platy, homogenous, non-calcareous, non- swelling, common black laminations; 10% Sand; 10% Clay. 03/20/2015 Conducted wiper trip T/ 1805' MD. RIH to bottom and washed down the last 3 stands and circulated while MWD got communications with their tool. Continued to drill ahead T/ 4262' MD and started taking moderate to severe losses. Decision was made to spot a pill on bottom and wiper trip T/ 1456' MD to the casing shoe and build more mud volume. RIH to bottom to drill ahead and reduced the pump rate. Drilling ahead at time of report. Gas: The max gas was 721 units at 3961’ MD and the average drilling background gas was 13 units. Fluids: There were 215 barrels of water based mud lost down hole. Geology: 50% Sand: clear-opaque, white-tan, light gray, lithics, quartz, course-very fine grained, poorly sorted, soft, subangular, spherical, silty, common coal, rare clay; 40% Siltstone: light gray-gray, friable-soft, blocky, amorphous, non-calcareous, tuff, sandy, com coal; 10% Shale. 03/21/2015 Continued to drill ahead to 4575' MD and stopped seeing seepage and noticing gains in the pits. Drilled ahead to 5242' MD and wiper tripped to 4147' MD with no over pull. RIH and washed down last 2 stands. Continuing to drill ahead at time of report. Gas: The max gas was 854 units at 5039’ MD and the average drilling background gas was 23 units. Fluids: There were 0 barrels of water based mud lost down hole. Geology: 60% Clay: light gray-gray, light brown-dark brown, plastic, blocky, silty, amorphous; 40% Siltstone: light gray-gray, friable-soft, blocky, amorphous, non-calcareous, tuff, sandy, com coal, clay matrix. 03/22/2015 Continued to drill ahead to 5688' MD and pumped a Hi-Vis sweep. Drilled to 5964' MD and pumped an additional Hi-Vis sweep. Drilling ahead at time of report. Gas: The max gas was 181 units at 5967’ MD and the average drilling background gas was 22 units. Fluids: There were 0 barrels of water based mud lost down hole. Geology: 70% Siltstone: light gray-gray, friable-soft, blocky, amorphous, non-calcareous, sandy, common coal; 20% Sand: clear-opaque, white-tan, light gray, lithics, quartz, course-very fine grained, poorly sorted, soft, subangular, spherical, silty, common coal, r clay, variable tuff; 10% Shale. 03/23/2015 Drilled ahead to 6340' MD and pumped a Hi-Vis sweep. Circulated and conditioned mud to prepare for wiper trip to the casing shoe. Pumped a dry job after pulling 10 stands and tripped out of hole to 1453' MD and slip and cut drill line. Ran in hole back to bottom and pumped an additional Hi-Vis sweep. Spotted 50 bbl LCM pill and started to trip out of hole. Tripping out of hole at time of report. Gas: The max gas was 401 units at 6350’ MD and the average drilling background gas was 0 units. Fluids: There were 0 barrels of water based mud lost down hole. Geology: The last sample collected @ 6354' MD for the intermediate section consisted of: 70% Shale: dark gray-gray, brown, firm-hard, blocky- platy, large fragments, homogenous, non- calcareous, non-swelling, common black laminations; 30% Siltstone: light gray-gray, friable-soft, blocky, amorphous, non-calcareous, sandy, common coal. 03/24/2015 Pulled out of hole and laid down BHA. Changed and tested 7.625" rams, rigged up Weatherford, and made up casing shoe track. Ran in hole with 7.625" casing T/ 5249' MD. Running in hole with casing at time of report. Gas: No gas to report. Fluids: There was 0 barrels of water based mud lost down hole. 03/25/2015 Running in hole with 7.625" casing to 6338' MD. Circulated and conditioned mud while cement crew rigged up, well was losing at 30 BPH. Pumped cement and displaced mud to bump the plug. Lost a total of 111 bbls while pumping cement. Set casing hanger and pack off. Testing BOP's at time of report. Gas: The max gas was 98 units and the average drilling background gas was 0 units. Fluids: There was 336 barrels of water based mud lost down hole. 03/26/2015 Completed testing BOP's and picked up BHA and additional drill pipe. Ran in hole to 6117' MD, and completed a successful casing test. Ran in hole to 6250' MD and tagged. Drilled out float equipment and 20' of new formation; pulled 2 stands and completed a successful FIT test. Running in hole to drill ahead at time of report. Gas: The max gas was 47 units at 6355’ MD and the average drilling background gas was 2 units. Fluids: There was 336 barrels of water based mud lost down hole. Geology: 60% Shale: dark gray-gray, brown, hard, platy, large fragments, homogenous, non- calcareous, non-swelling, common black laminations; 40% Siltstone: light gray-gray, friable-soft, amorphous, non-calcareous, sandy, local clay matrix. 03/27/2015 Drilled ahead to 7173' MD and the decision was made to pull out of hole to replace the BHA. Pulled out of hole to 6336' MD, slugged pipe and flow checked, static. Pulled out of hole to surface, and changing out BHA at time of report. Gas: The max gas was 2861 units at 7112’ MD and the average drilling background gas was 1 units. Fluids: There were 0 barrels of water based mud lost down hole. Geology: 50% Siltstone: light gray-gray, friable-soft, amorphous, non-calcareous, sandy, local clay matrix; 30% Clay: light gray-gray, light brown-dark brown, plastic, blocky, silty, amorphous; 10% Sand; 10% Shale. 03/28/2015 Picked up new BHA and ran in hole to the shoe. Circulated bottoms up at casing shoe which produced no gas. Tripped into hole to 7173' MD and encountered no tight spots. Mad-passed from 6439' MD to 6539' MD and from 7012' MD to 7053' MD. Began directional turn and build. Currently drilling ahead at time of report. Gas: The max gas was 2565 units at 7210’ MD and the average drilling background gas was 2 units. Fluids: There were 0 barrels of water based mud lost down hole. Geology: 70% Siltstone: light gray-gray, friable-soft, amorphous, non-calcareous, sandy, local clay matrix; 20% Clay; 10% Sand. 03/29/2015 Continued directional work from 7367' MD to 7485' MD. Drilled ahead to 8065' MD and CBU at a slow pump rate due to gas breaking out of the mud. Drilling ahead @ 8236' MD at time of report. Gas: The max gas was 9896 units at 7979’ MD and the average drilling background gas was 37 units. Fluids: There were 0 barrels of water based mud lost down hole. Geology: 80% Siltstone: light gray-gray, friable-soft, amorphous, non-calcareous, sandy; 20% Sand: light-gray, v-fine grained, consolidated, sub rounded, subangular; 10% Coal. 03/30/2015 Drilled ahead to 8351' MD and CBU and wiper tripped to 7259' MD with no issues. Had a trip gas max of 1916 units. Ran in hole to the bottom with no problems. CBU and began drilling ahead to 8960' MD and then CBU to let gas break out of the mud. Drilled to 9032' MD and the decision was made to weigh up the mud up to 10.5 ppg mud weight. Drilling ahead at 9034' MD at time of report. Gas: The max gas was 6420 units at 8662’ MD and the average drilling background gas was 33 units. Fluids: There were 0 barrels of water based mud lost down hole. Geology: 40% Sand: light-gray, very-fine grained, consolidated, sub rounded, subangular; 40% Coal: black, firm-hard, fissile, large fragments; 20% Siltstone: light gray-gray, friable-soft, amorphous, non-calcareous, sandy. 04/01/2015 Drilled ahead to 8351' MD and CBU and wiper tripped to 7259' MD with no issues. Had a trip gas max of 1916 units. Ran in hole to the bottom with no problems. CBU and began drilling ahead to 8960' MD and then CBU to let gas break out of the mud. Drilled to 9032' MD and the decision was made to weigh up the mud up to 10.5 ppg mud weight. Drilling ahead at 9034' MD at time of report. Gas: The max gas was 6420 units at 8662’ MD and the average drilling background gas was 33 units. Fluids: There were 0 barrels of water based mud lost down hole. Geology: 40% Sand: light-gray, very-fine grained, consolidated, sub rounded, subangular; 40% Coal: black, firm-hard, fissile, large fragments; 20% Siltstone: light gray-gray, friable-soft, amorphous, non-calcareous, sandy. 04/02/2015 Drilled ahead to 8351' MD and CBU and wiper tripped to 7259' MD with no issues. Had a trip gas max of 1916 units. Ran in hole to the bottom with no problems. CBU and began drilling ahead to 8960' MD and then CBU to let gas break out of the mud. Drilled to 9032' MD and the decision was made to weigh up the mud up to 10.5 ppg mud weight. Drilling ahead at 9034' MD at time of report. Gas: The max gas was 6420 units at 8662’ MD and the average drilling background gas was 33 units. Fluids: There were 0 barrels of water based mud lost down hole. Geology: 40% Sand: light-gray, very-fine grained, consolidated, sub rounded, subangular; 40% Coal: black, firm-hard, fissile, large fragments; 20% Siltstone: light gray-gray, friable-soft, amorphous, non-calcareous, sandy. 04/03/2015 Drilled ahead to 8351' MD and CBU and wiper tripped to 7259' MD with no issues. Had a trip gas max of 1916 units. Ran in hole to the bottom with no problems. CBU and began drilling ahead to 8960' MD and then CBU to let gas break out of the mud. Drilled to 9032' MD and the decision was made to weigh up the mud up to 10.5 ppg mud weight. Drilling ahead at 9034' MD at time of report. Gas: The max gas was 6420 units at 8662’ MD and the average drilling background gas was 33 units. Fluids: There were 0 barrels of water based mud lost down hole. Geology: 40% Sand: light-gray, very-fine grained, consolidated, sub rounded, subangular; 40% Coal: black, firm-hard, fissile, large fragments; 20% Siltstone: light gray-gray, friable-soft, amorphous, non-calcareous, sandy. 04/04/2015 Drilled ahead to 8351' MD and CBU and wiper tripped to 7259' MD with no issues. Had a trip gas max of 1916 units. Ran in hole to the bottom with no problems. CBU and began drilling ahead to 8960' MD and then CBU to let gas break out of the mud. Drilled to 9032' MD and the decision was made to weigh up the mud up to 10.5 ppg mud weight. Drilling ahead at 9034' MD at time of report. Gas: The max gas was 6420 units at 8662’ MD and the average drilling background gas was 33 units. Fluids: There were 0 barrels of water based mud lost down hole. Geology: 40% Sand: light-gray, very-fine grained, consolidated, sub rounded, subangular; 40% Coal: black, firm-hard, fissile, large fragments; 20% Siltstone: light gray-gray, friable-soft, amorphous, non-calcareous, sandy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perry Drilling Confidential Document v 3.0 Difficulties experienced: Before the section was started the 7320 datascan that is responsible for the connection to the THA failed to work. After much troublshooting and attempts at different modes of operation the module was replaced. A new barrier box was brought in and hooked up. The normal mode of operation failed to work on this barrier box as well. I then made the connection directly to the front of the datascan. Recommendations: N/A Innovations and/or cost savings: The quick disconnect fitting was replaced on the front of the gas trap motor to one that is hardlined and has to be screwed in. The brine that we constantly drill with out here kept corroding the fitting and this new configuration works much better. Saxon 169 Jeremy Tiegs Kenai Beluga Unit Kenai Peninsula Borough Alaska Surface 17-Mar-2015 What went as, or better than, planned: The data collection during this section was uninterupted and none of the gas equipment failed. KBU 31-18 Hilcorp Alaska LLC AK-XX-0902208266 Surface Data Logging After Action Review Surface Data Logging WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: While drilling ahead, the clocks on the IRIS, MADI, and workstation inexplicably changed their clocks to 1 hour behind the actual time. After checking the computer settings to make sure that the 'change time automatically for daylight savings time' box was unchecked, the times were changed to the correct time. When the time was being changed on the IRIS computer, it had changed it's time zone to Arizona somehow. When I went to change it to the correct time, the computers then thought the time was 2 hours ahead of the correct time. After some trouble shooting to fix the problem, Insite on IRIS was restarted which fixed the issue. Some of the data from 00:00 3/22/15 to 03:50 3/22/15 on the time logs was affected due to time jump. Recommendations: Always keep an eye on the clocks to make sure they are at the correct time. Luckily we were able to catch this problem 10 minutes after it happened and fixed it relatively quickly, some data was lost. Innovations and/or cost savings: Hose clamps were put onto the large tube that carries gas from the gas trap to the drop out jar on both ends to create a tighter connection. This made our gas equipment a closed system. Saxon 169 Autumn Gould Kenai Beluga Unit Kenai Peninsula Borough Alaska Intermediate 23-Mar-2015 What went as, or better than, planned: The gas equipment worked well throughout this entire section. The barrier box we had shipped in to replace the 7320 Datascan worked flawlessly. KBU 31-18 Hilcorp Alaska LLC AK-XX-0902208266 Surface Data Logging After Action Review .%8 +LOFRUS$ODVND//& %DURLG 6D[RQ $.;; DDate Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds % % % ppb Eqv mg/l Ca++ 13-Mar 130 8.85 160 29 46 24/50/61 11.4 104/75/62/47/25/24 3/0 3.5 0.00/96.2 0.03 0.30 10.1 20.0 0.15/0.40 800 - Picking up BHA 14-Mar 1354 9.15 100 29 35 9/27/36 9.8 93/64/52/36/11/9 3/0 6.1 0.0/93.7 1.50 0.15 9.5 20.0 0.10/0.35 500 - Drilling 13.5' Surface Section 15-Mar 1520 9.15 69 34 27 5/7/10 10.4 95/61/47/30/7/5 3/0 6.1 0.0/93.7 1.30 0.20 8.8 20.0 0.10/0.35 400 - RIH with Surface Casing 16-Mar 1520 9.20 82 37 30 8/11/15 10.4 104/67/51/33/9/7 3/0 6.1 0.0/93.7 1.30 0.20 7.0 20.0 0.10/0.35 400 - N/D Stack and N/U BOP's 17-Mar 1520 9.00 44 7 13 6/7/9 5.0 27/20/18/14/6/5 1/1 2.8 0.0/95.0 0.05 0.30 9.7 1.0 0.05/0.30 26500 160 Picking up 4.5" Drill Pipe 18-Mar 1904 9.10 47 8 14 6/8/10 5.0 30/22/18/14/6/5 1/1 3.3 0.0/94.2 0.05 0.35 8.5 1.0 0.10/0.80 30000 240 Drilling 9.875" Intermediate Section 19-Mar 3517 9.10 55 11 19 8/10/12 4.9 41/30/25/19/8/6 1/1 3.5 0.0/94.2 0.15 0.25 9.0 1.5 0.10/0.90 28000 360 Wiper Trip 20-Mar 4510 9.05 52 11 17 6/8/10 5.2 39/28/23/17/6/5 1/1 2.9 0.0/94.6 0.15 0.20 9.2 1.5 0.20/0.90 30000 320 Drilling 9.875" Intermediate Section 21-Mar 5389 9.15 52 12 19 6/8/10 4.8 43/31/25/18/6/5 1/1 3.7 0.0/93.9 0.15 0.45 9.9 2.0 0.30/1.20 30500 160 Drilling 9.875" Intermediate Section 22-Mar 6152 9.20 59 13 18 5/7/9 4.6 44/31/25/18/5/4 1/1 4.0 0.0/93.5 0.25 0.45 9.6 1.5 0.50/1.75 31000 100 Drilling 9.875" Intermediate Section 23-Mar 6354 9.30 54 14 18 6/9/12 4.2 46/32/27/19/6/5 1/1 4.7 0.0/92.8 0.15 0.80 10.0 2.0 0.80/2.10 31000 60 TD 9.875" Intermediate Section 24-Mar 6354 9.15 66 13 18 5/7/10 4.3 44/31/26/19/6/5 1/1 3.6 0.0/93.9 0.15 0.60 10.0 2.0 0.70/2.20 31000 60 Running 7.625" Intermediate Casing 25-Mar 6354 9.35 56 13 19 6/8/11 4.4 45/32/27/19/6/5 1/1 5.3 0.0/92.4 0.10 0.90 9.1 2.3 0.80/3.50 28500 70 Testing BOP's 26-Mar 6374 9.30 54 11 19 5/7/10 4.5 41/30/24/18/6/4 1/2 4.9 0.0/92.8 0.15 2.10 10.1 2.0 0.95/3.30 29000 140 RIH to dril 6.75" Production Section 27-Mar 7173 9.30 54 12 20 6/9/12 4.4 44/32/26/19/6/5 1/2 4.8 0.0/92.8 2.00 1.30 10.6 2.0 0.80/2.60 29500 80 Replacing BHA 28-Mar 7367 9.40 52 12 18 5/7/11 4.2 42/30/25/18/6/5 1/2 5.2 0.0/92.4 0.10 0.90 10.1 2.0 0.60/2.40 30000 70 Drilling 6.75" Production Section 29-Mar 8236 9.85 48 13 19 6/8/12 4.2 45/32/27/19/6/5 1/2 6.6 0.0/91.0 0.15 0.50 9.3 2.0 0.40/2.00 30000 90 Drilling 6.75" Production Section 30-Mar 9034 10.50 49 15 19 5/8/13 3.4 49/34/28/20/6/4 1/2 9.1 0.0/88.4 0.25 0.50 9.5 3.0 0.35/2.00 32000 80 TD 6.75" Production Hole Section 31-Mar 9487 11.45 46 17 20 6/9/15 4.0 54/37/30/22/7/5 1/2 13.2 0.0/84.6 0.25 0.60 9.8 3.5 0.35/1.60 30000 60 BROOH 1-Apr 10010 11.70 46 16 20 6/9/16 4.7 52/36/30/21/6/5 1/2 14.3 0.0/83.4 0.25 0.45 9.4 4.0 0.35/1.60 31000 40 Clean out run 2-Apr 10010 11.70 46 16 20 6/10/15 5.0 52/36/30/22/7/5 1/2 14.4 0.0/83.4 0.20 0.50 9.4 4.0 0.30/2.50 30000 80 Continue clean out run with high gas 3-Apr 10010 11.70 46 17 20 6/10/16 5.6 54/37/31/23/7/5 1/2 14.7 0.0/83.2 0.20 0.20 8.5 4.0 0.10/2.00 29000 80 RIH with Liner and cement into place Casing Record :(//1$0( /2&$7,21.HQDL%HOXJD8QLW 23(5$725 $5($.HQDL3HQLQVXOD%RURXJK 08'&2 67$7($ODVND 5,* 638'0DU 63(55<-2%7'0DU Remarks 16" Conductor @ 130' MD, 130'TVD 10.75" Casing @ 1476' MD, 1476'TVD 6.875" Casing @ 6338' MD, 6198'TVD : D W H U D Q G 2 L O % D V H G 0 X G BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 1 100 1 Varel DT1GJMRS 13.50 126 1520 1394 9.58 0.7394 149.0 14 80 1900 545 1-1-WT-A-E-1-BU-TD TD Surface Section 2 200 2 HDBS MM65 9.875 1520 6354 4834 61.60 0.7777 81.0 8 70 1860 505 2-3-CT-A-X-1-ER-TD TD Intermediate Section 3 300 3 HDBS EM65D 6.75 6354 7173 819 11.31 0.4602 88.0 5 90 2080 290 0-0-NO-A-X-I-NO-BHA POOH due to change MWD tools 4 400 4 HDBS EM65D 6.75 7173 10010 2837 48.76 0.4602 80.0 8 90 2840 305 1-1-CT-G-X-1-NO-TD TD Production Section Alaska RIG:Saxon 169 SPUD:14-Mar-2015 WELL NAME:KBU 31-18 LOCATION:Kenai Beluga Unit OPERATOR:Hilcorp Alaska LLC AREA:Kenai Peninsula Borough MUD CO: SPERRY JOB:AK-XX-0902208266 TD:31-Mar-2015 Baroid STATE: B i t R e c o r d . . * 24 hr Recap:Finished rigging up the mudlogging unit and picking up drill pipe. Tagged @ 120' and began to M/U BHA at time of Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 800 - 14-Mar-2015 23:59 Current Pump & Flow Data: - Max ROP ROP (ft/hr) 5.55 @ Mud Data Depth Morning Report Report # 1 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Condition - Bit # 1 3.5 13.5 - Tricone 8.85 Size Geology: N/A Fluids: 0 bbls Max Gas: N/A 100% Gas In Air=10,000 Units-Connection - Tools N/A API FL Chromatograph (ppm) -130' - WOB N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 2Background (max)Trip Average - Mud Type Lst Type - Spud Mud 11.1130'46 Depth in / out YP (lb/100ft2) 10.10 --- -- CementChtSd C-4i C-4n 24 hr Max Weight - Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - P/U BHA PV - Footage - S. Barber / D. Yessak ShClyst TuffGvlCoal cP 29 Gas Summary - -- (current) Avg to130' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) N/A 130' N/A Max @ ft Current -- Date: Time: report. - in --Minimum Depth C-5n - - C-2 - SPP (psi) Gallons/stroke TFABit Type Depth 20.0160 MBT - pH 0.739 - - - Siltst - - Units* Casing Summary Lithology (%) -- - 907-283-1309Unit Phone: - Autumn Gould Maximum Report By:Logging Engineers:Autumn Gould / Jeremy Tiegs Set AtSize Grade (max)(current) - - Cly - . . * 24 hr Recap : (max)(current) 0 0 Cly 11209 Set AtSize Grade 907-283-1309Unit Phone: 0 Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jeremy Tiegs 60 3033 45 290 99 Units* Casing Summary Litho logy (%) 0 MBT - pH 0.739 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 20.0100 C-5n 1383' 184.9 C-2 72 in 5 849'Minimum Depth Time: T/ 488' MD and made wiper trip and serviced rig while inside the conductor. Drilled ahead T/ 1354' MD and drilling ahead at the 19 130' 1354' 1224' Max @ ft Current 1495'167.8 Date: Avg to130' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 193.1 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) S. Barber / D. Yessak ShClyst TuffGvlCoal cP 29 - Footage - 40 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - Drilling Surface Section PV 24 hr Max W eight 0 Hours C-3 00 CementCht Sd C-4i C-4n YP (lb/100ft2) 9.50 000 - Spud Mud 9.81354'35 Depth in / out Mud Type Lst Type Average -6Backgrou nd (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools N/A API FL Chromatograph (ppm ) -130' - WOB 100% Gas In Air=10,000 Units-Connectio n 0 Geology: 60% Siltstone: lt gy - gy, sft-frm, amor, suc, slty, non calc, swlg; 40% Clay: lt gry-gry, lt brn-dk brn, plas, blky, slty, amor. Fluids: 0 bbls Max Gas: 72 units time of report. Condition - Bit # 1 6.1 13.5 9.15 Tricone 9.15 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Morn ing Re po rt Report # 2 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field ROP ROP (ft/hr) 5.55 @ Mud Data Depth 14-Mar-2015 23:59 Current Pump & Flow Data: 1900 Max 0 Chlorides mg/l 500 Continued to make up BHA. RIH and conducted pressure and pulse test. RIH T/ 126' MD and tagged bottom. Drilled Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap : Continued to drill ahead and TD at 1520' MD. Conducted wiper trip T/555' pulling on elevatos and then RIH to Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400 0 15-Mar-2015 23:59 Current Pump & Flow Data: - Max ROP ROP (ft/hr) 5.55 @ Mud Data Depth Morn ing Re po rt Report # 3 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Condition - Bit # 1 6.1 13.5 9.15 Tricone 9.15 Size Geolo gy: 80% Siltstone: lt gy-gy, sft-frm, amor, suc, slty, non calc, swlg; 10% Sand: clr-opq, wh, lt gry-dk gry, blk, lith, Qtz, crs-f gr, Fluids: 0 bbls Max Gas: 79 units casing hanger at time of report. - 100% Gas In Air=10,000 Units-Connectio n 0 Tools N/A API FL Chromatograph (ppm ) -130' 1521' WOB Surface Casing N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 5Backgrou nd (max)Trip Average - Mud Type Lst Type - Spud Mud 10.41520'27 Depth in / out YP (lb/100ft2) 8.80 000 00 CementCht Sd C-4i C-4n 24 hr Max W eight 0 Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - RIH w/ 10.75" Casing PV 1391' Footage 10.05 S. Barber / D. Yessak ShClyst TuffGvlCoal cP 34 Gas Summary 0 0 0 (current) Avg to130' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 199.9 Flow In (gpm) Flow In (spm) 1354' 1520' 166' Max @ ft Current 1510'0.0 Date: Time: mod srt, subang, subsphr; 10% Clay: lt gy-gy, lt brn-dk brn, plas, blky, slty, amor. bottom. TOOH on elevators and L/D BHA. R/U Weatherford and RIH with 10.75" casing T/1513' MD. Currently attempting to seat 36 in 12 1495'Minimum Depth C-5n 1364' 0.0 C-2 79 SPP (psi) Gallons/stroke TFABit Type Depth 20.069 MBT 1520' pH 0.739 0 0 0 Siltst - - Units* Casing Summary Litho logy (%) 01524 146 907-283-1309Unit Phone: 0 Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jeremy Tiegs Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) 0 0 Cly 10961 . . * 24 hr Recap : (max)(current) 0 0 Cly 140 Set AtSize 45.5 L-80 Grade 10.75'' 907-283-1309Unit Phone: 0 Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jeremy Tiegs 66 23 - - Units* Casing Summary Litho logy (%) 0 MBT 1520' pH 0.739 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 20.085 C-5n - 0.0 C-2 72 in 1 -Minimum Depth Time: and lost 67 bbls to hole while putting cement in place and got back 50 bbls of mud push and 48 bbls of cement to surface. Currently 7 1520' 1520' 0' Max @ ft Current 0'0.0 Date: Avg to130' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) S. Barber / D. Yessak ShClyst TuffGvlCoal cP 37 1391' Footage 10.05 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - N/U BOP's PV 24 hr Max W eight 0 Hours C-3 00 CementCht Sd C-4i C-4n YP (lb/100ft2) 7.00 000 - Spud Mud 10.41520'30 Depth in / out Mud Type Lst Type Average -0Backgrou nd (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools N/A API FL Chromatograph (ppm ) -130' 1521' WOB Surface Casing 100% Gas In Air=10,000 Units-Connectio n 0 Geology: No samples collected. Fluids: 0 bbls Max Gas: 72 units N/D stack and N/U BOP's at time of report. 1476' Condition - Bit # 1 6.1 13.5 9.20 Tricone 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Morn ing Re po rt Report # 4 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field ROP ROP (ft/hr) 5.55 @ Mud Data Depth 16-Mar-2015 23:59 - Max 0 Chlorides mg/l 400 The decision was made to lay down one joint of casing to be able to land the hanger. Pressure tested cement lines Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap : Finished N/U BOP and tested BOP's. Pressure tested surface casing with good results. P/U 156 joints of drill pipe Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 26500 17-Mar-2015 23:59 - Max - ROP ROP (ft/hr) 5.55 @ Mud Data Depth Morn ing Re po rt Report # 5 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Condition - Bit # 1 2.8 13.5 9.00 Tricone 9.00 Size 2 Geology: No samples collected. Fluids: 0 bbls Max Gas: No gas to report 1476' 100% Gas In Air=10,000 Units-Connectio n Tools - API FL Chromatograph (ppm ) - -130' 1520' WOB Surface Casing N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min -Backgrou nd (max)Trip Average - Mud Type Lst Type - - PDC Spud Mud 5.0 1476' 1520'13 - Depth in / out YP (lb/100ft2) 9.70 CementCht Sd C-4i C-4n 24 hr Max W eight Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - P/U 4.5" DP PV 1391' 9.875 0.778 Footage -- 10.05 R. Pederson / D. Yessak ShClyst TuffGvlCoal cP 7 Gas Summary (current) Avg to- Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 0.0 Flow In (gpm) Flow In (spm) 1520' 1520' 0' Max @ ft Current -0.0 Date: Time: and reracked it. Picking up drill pipe at time of report. - in --Minimum Depth C-5n - 0.0 C-2 - SPP (psi) Gallons/stroke TFABit Type Depth 1.044 MBT - pH 0.739 Siltst - - Units* Casing Summary Litho logy (%) 907-283-1309Unit Phone:Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jeremy Tiegs Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) Cly . . * 24 hr Recap : Continued to P/U DP and then M/U BHA. RIH T/ 1357' MD and tagged up; drilled out shoe and 20' of new formation Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 30000 0 18-Mar-2015 23:59 1032 Max - - ROP ROP (ft/hr) 5.50 @ Mud Data Depth Morn ing Re po rt Report # 6 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Condition 1-1-WT-A-E-1-BU-TD Bit # 1 3.3 13.5 9.10 Tricone 9.10 Size 2 Geology: 80% Siltstone: lt gy-gy, sft-hrd, blky, suc, non calc, swlg; 10% Sand: clr-opq, wh, blk, lith, Qtz, m-f gr, wl srt, subang-ang, Fluids: 0 bbls Max Gas: 122 units T/ 1904' MD at time of report. 1476' 100% Gas In Air=10,000 Units-Connectio n 0 Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm ) - 8.0126' 1520' WOB Surface Casing N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 7Backgrou nd (max)Trip Average - Mud Type Lst Type - 70.0 PDC KCI/Polymer 5.0 1476' 1904'14 - Depth in / out YP (lb/100ft2) 8.50 000 00 CementCht Sd C-4i C-4n 24 hr Max W eight 0 Hours C-3 10 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - Drilling 9.875" Intermediate PV 1391' 9.875 0.778 Footage -- 10.05 R. Pederson / D. Yessak ShClyst TuffGvlCoal cP 8 Gas Summary 0 0 0 (current) Avg to1520' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 207.4 Flow In (gpm) Flow In (spm) 1520' 1904' 384' Max @ ft Current 1862'120.2 Date: Time: subsphr, tr cons ss; 10% Shale: dk gy-gy, frm-mod hd, blky, homog, non calc, non swlg. T/ 1540' MD. Displaced mud over to 6% KCL mud and performed FIT test to 12 ppg. Passed FIT test and continued to drill ahead 46 in 4 1543'Minimum Depth C-5n 1885' 108.4 C-2 122 SPP (psi) Gallons/stroke TFABit Type Depth 1.047 MBT - pH 0.739 0 0 0 Siltst 261 89 Units* Casing Summary Litho logy (%) 0 80 6022 134 907-283-1309Unit Phone: 0 Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jeremy Tiegs Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) 0 0 Cly 12061 10 . . * 24 hr Recap : Continued to drill ahead T/ 2029' MD and pumped a Hi-Vis sweep. Drilled ahead T/ 2341' MD and drilled a Hi-Vis Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 28000 0 19-Mar-2015 23:59 0 Max - - ROP ROP (ft/hr) 5.50 @ Mud Data Depth Morn ing Re po rt Report # 7 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Condition 1-1-WT-A-E-1-BU-TD Bit # 1 3.5 13.5 9.10 Tricone 9.10 Size 2 Geology: 40% Siltstone: lt gy-lt brn, sft-lse, blky, amor, non calc, tf; 40% Shale: dk gy-gy, brn, frm-hd, blky-plty, lg frag, homog, non Fluids: 52 bbls Max Gas: 147 units beagn POOH for wiper trip. POOH at time of report. T/ 3143' MD and pumped an additional Hi-Vis sweep with a 40% cuttings increase at shakers. Drilled ahead T/ 3517' MD and bottom with no issues. Drilled ahead T/ 2896 and pumped a Hi-Vis sweep woth 50% cuttings increase at shakers. Drilled ahead 1476' 100% Gas In Air=10,000 Units-Connectio n 0 Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm ) - 8.0126' 1520' WOB Surface Casing N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 7Backgrou nd (max)Trip Average - Mud Type Lst Type - 70.0 PDC KCI/Polymer 4.9 1476' 3517'19 - Depth in / out YP (lb/100ft2) 9.00 000 00 CementCht Sd C-4i C-4n 24 hr Max W eight 0 Hours C-3 4010 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - Wiper Trip PV 1391' 9.875 0.778 Footage -- 10.05 R. Pederson / D. Yessak ShClyst TuffGvlCoal cP 11 Gas Summary 0 0 0 (current) Avg to1520' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 238.9 Flow In (gpm) Flow In (spm) 1904' 3517' 1613' Max @ ft Current 2473'181.2 Date: Time: calc, non swlg, com blk lam; 10% Sand; 10% Clay. sweep. Continued drilling ahead T/ 2522' MD and pumped an additional Hi-Vis sweep. Wiper tripped to the shoe and RIH to 45 in 4 2964'Minimum Depth C-5n 1963' 0.0 C-2 147 SPP (psi) Gallons/stroke TFABit Type Depth 1.555 MBT - pH 0.739 0 0 0 Siltst 0 0 Units* Casing Summary Litho logy (%) 0 40 6454 168 907-283-1309Unit Phone: 0 Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jeremy Tiegs Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) 0 0 Cly 15868 10 . . * 24 hr Recap : (max)(current) 86 0 Cly 94756 50 Set AtSize 45.5 L-80 Grade 10.75'' 907-283-1309Unit Phone: 0 Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jeremy Tiegs 40 26000 2859 223 76 Units* Casing Summary Litho logy (%) 0 MBT - pH 0.739 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 1.552 C-5n 3961' 112.7 C-2 721 in 4 4028'Minimum Depth Time: fri-sft, blky, amor, non calc, tf, sdy, com C, loc Cly mtx; 10% Shale: dk gy-gy, brn, frm-hd, blky-plty, lg frag, non swlg, com blk lam. communications with their tool. Continued to drill ahead T/ 4262' MD and started taking moderate to severe losses. Decision was 199 3517' 4510' 993' Max @ ft Current 3521'129.6 Date: Avg to1520' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 211.8 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) R. Pederson / D. Yessak ShClyst TuffGvlCoal cP 11 1391' 9.875 0.778 Footage -- 10.05 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - Drilling Intermediate Section PV 24 hr Max W eight 15 Hours C-3 10 00 CementCht Sd C-4i C-4n YP (lb/100ft2) 9.20 000 - 70.0 PDC KCI/Polymer 5.2 1476' 4510'17 - Depth in / out Mud Type Lst Type Average -13Backgrou nd (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm ) - 8.0126' 1520' WOB Surface Casing 100% Gas In Air=10,000 Units-Connectio n 0 2 Geology: 50% Sand: clr-opq, wh-tn, lt gry, lith, Qtz, crs-vf gr, pr srt, sft, subang, sphr, slty, com C, r Cly, v tf; 40% Siltstone: lt gry-gry, Fluids: 215 bbls Max Gas: 721 units ahead and reduced the pump rate. Drilling ahead at time of report. made to spot a pill on bottom and wiper trip T/ 1456' MD to the casing shoe and build more mud volume. RIH to bottom to drill 1476' Condition 1-1-WT-A-E-1-BU-TD Bit # 1 2.9 13.5 9.05 Tricone 9.05 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Morn ing Re po rt Report # 8 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field - - ROP ROP (ft/hr) 5.50 @ Mud Data Depth 20-Mar-2015 23:59 1515 Max 0 Chlorides mg/l 30000 Conducted wiper trip T/ 1805' MD. RIH to bottom and washed down the last 3 stands and circulated while MWD got Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap : Continued to drill ahead T/ 4575' MD and stopped seeing seepage and noticing gains in the pits. Drilled ahead Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 30500 0 21-Mar-2015 23:59 1643 Max - - ROP ROP (ft/hr) 5.50 @ Mud Data Depth Morn ing Re po rt Report # 9 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Condition 1-1-WT-A-E-1-BU-TD Bit # 1 3.7 13.5 9.15 Tricone 9.15 Size 2 Geology: 60% Clay: lt gy-gy, lt brn-dk brn, plas, blky, slty, amor; 40% Siltstone: lt gry-gry, fri-sft, blky, amor, non calc, tf, sdy, com C, Fluids: 0 bbls Max Gas: 854 units of report. 1476' 100% Gas In Air=10,000 Units203Connection 0 Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm ) - 8.0126' 1520' WOB Surface Casing N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 13Backgrou nd (max)Trip Average - Mud Type Lst Type - 70.0 PDC KCI/Polymer 4.8 1476' 5389'19 - Depth in / out YP (lb/100ft2) 12.80 000 00 CementCht Sd C-4i C-4n 24 hr Max W eight 9 Hours C-3 60 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - Drilling Intermediate Section PV 1391' 9.875 0.778 Footage -- 10.05 R. Pederson / D. Yessak ShClyst TuffGvlCoal cP 12 Gas Summary 0 0 0 (current) Avg to1520' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 131.5 Flow In (gpm) Flow In (spm) 4510' 5389' 879' Max @ ft Current 4524'74.9 Date: Time: loc Cly mtx. T/ 5242' MD and wiper tripped T/ 4147' MD with no over pull. RIH and washed down last 2 stands. Continuing to drill ahead at time 131 in 5 5258'Minimum Depth C-5n 5039' 26.2 C-2 854 SPP (psi) Gallons/stroke TFABit Type Depth 2.052 MBT - pH 0.739 0 0 0 Siltst 264 90 Units* Casing Summary Litho logy (%) 0 40 16621 110 907-283-1309Unit Phone: 0 Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jacob Hansen Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) 74 0 Cly 113677 . . * 24 hr Recap : (max)(current) 12 0 Cly 24739 20 Set AtSize 45.5 L-80 Grade 10.75'' 907-283-1309Unit Phone: 0 Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jacob Hansen 70 5089 762 261 89 Units* Casing Summary Litho logy (%) 0 MBT - pH 0.739 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 1.559 C-5n 5967' 92.1 C-2 181 in 8 5664'Minimum Depth Time: gr, pr srt, sft, subang, sphr, slty, com C, r Cly, v tf; 10% Shale. Hi-Vis sweep. Drilling ahead at time of report. 40 5389' 6152' 763' Max @ ft Current 5917'58.6 Date: Avg to1520' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 177.5 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) R. Pederson / D. Yessak ShClyst TuffGvlCoal cP 13 1391' 9.875 0.778 Footage -- 10.05 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - Drilling Intermediate Section PV 24 hr Max W eight 1 Hours C-3 10 00 CementCht Sd C-4i C-4n YP (lb/100ft2) 9.60 000 - 70.0 PDC KCI/Polymer 4.6 1476' 6152'18 - Depth in / out Mud Type Lst Type Average -22Backgrou nd (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm ) - 8.0126' 1520' WOB Surface Casing 100% Gas In Air=10,000 Units181Connection 0 2 Geology: 70% Siltstone: lt gry-gry, fri-sft, blky, amor, non calc, sdy, com C, loc Cly mtx; 20% Sand: clr-opq, wh-tn, lt gry, lith, Qtz, crs-vf Fluids: 0 bbls Max Gas: 181 units 1476' Condition 1-1-WT-A-E-1-BU-TD Bit # 1 4.0 13.5 9.10 Tricone 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Morn ing Re po rt Report # 10 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field - - ROP ROP (ft/hr) 5.50 @ Mud Data Depth 22-Mar-2015 23:59 1608 Max 0 Chlorides mg/l 31000 Continued to drill ahead T/ 5688' MD and pumped a Hi-Vis sweep. Drilled T/ 5964' MD and pumped an additional Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap : Drilled ahead T/ 6340' MD and pumped a Hi-Vis sweep. Circulated and conditioned mud to prepare for wiper trip to Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 31000 0 23-Mar-2015 23:59 0 Max - - ROP ROP (ft/hr) 5.50 @ Mud Data Depth Morn ing Re po rt Report # 11 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Condition 1-1-WT-A-E-1-BU-TD Bit # 1 4.7 13.5 9.30 Tricone 9.30 Size 2 Geology: The last sample collected @ 6354' MD for the intermediate section consisted of: 70% Shale: dk gy-gy, brn, frm-hd, blky- Fluids: 0 bbls Max Gas: 401 units pumped an additional Hi-Vis sweep. Spotted 50 bbl LCM pill and started to TOOH. TOOH at time of report. - 1476' 100% Gas In Air=10,000 Units-Connectio n 8 Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm ) - 8.0126' 1520' WOB Surface Casing N/AN/A Avg Min Comments - RPM ECD (ppg) ml/30min 0Backgrou nd (max)Trip Average - Mud Type Lst Type - 70.0 PDC KCI/Polymer 4.2 1520' 6354'18 6354' Depth in / out YP (lb/100ft2) 10.00 000 00 CementCht Sd C-4i C-4n 24 hr Max 29.0 W eight 3 Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - TOOH to Run Intm. Casing PV 1391' 9.875 0.778 Footage 41.25 4834' 10.05 R. Pederson / D. Yessak ShClyst TuffGvlCoal cP 14 Gas Summary 0 0 0 (current) Avg to1520' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 119.5 Flow In (gpm) Flow In (spm) 6152' 6354' 202' Max @ ft Current 6351'0.0 Date: Time: plty, lg frag, homog, non calc, non swlg, com blk lam; 30% Siltstone: lt gry-gry, fri-sft, blky, amor, non calc, sdy, com C, loc Cly mtx. the casing shoe. Pumped a dry job after pulling 10 stands. TOOH T/ 1453' MD and slip and cut drill line. RIH back to bottom and 80 in 19 6192'Minimum Depth C-5n 6350' 0.0 C-2 401 SPP (psi) Gallons/stroke TFABit Type Depth 2.054 L-80 MBT - pH 0.739 0 0 0 Siltst 7.625" 0 0 Units* Casing Summary Litho logy (%) 010327 2550 907-283-1309Unit Phone: 0 Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jacob Hansen Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) Intermediate Casing 29 0 Cly 54956 . . * 24 hr Recap : POOH and laid down BHA. Changed and tested 7.625" rams, rigged up Weatherford, and made up casing shoe Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 31000 24-Mar-2015 23:59 0 Max - - ROP ROP (ft/hr) 5.50 @ Mud Data Depth Morn ing Re po rt Report # 12 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Condition 1-1-WT-A-E-1-BU-TD Bit # 1 3.6 13.5 9.15 Tricone 9.15 Size 2 Geology: No samples collected Fluids: 0 bbls Max Gas: No gas to report - 1476' 100% Gas In Air=10,000 Units-Connectio n Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm ) - 8.0126' 1520' WOB Surface Casing N/AN/A Avg Min Comments - RPM ECD (ppg) ml/30min -Backgrou nd (max)Trip Average - Mud Type Lst Type - 70.0 PDC KCI/Polymer 4.3 1520' 6354'18 6354' Depth in / out YP (lb/100ft2) 10.00 CementCht Sd C-4i C-4n 24 hr Max 29.0 W eight Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - RIH w/ Interm. Casing PV 1391' 9.875 0.778 Footage 41.25 4834' 10.05 R. Pederson / L. Toussant ShClyst TuffGvlCoal cP 13 Gas Summary (current) Avg to1520' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 0.0 Flow In (gpm) Flow In (spm) 6354' 6354' 0' Max @ ft Current 0'0.0 Date: Time: track. RIH with 7.625" casing T/ 5249' MD. RIH with casing at time of report. 0 in 0 -Minimum Depth C-5n - 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 2.066 L-80 MBT 6354' pH 0.739 Siltst 7.625" 0 0 Units* Casing Summary Litho logy (%) 907-283-1309Unit Phone:Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jacob Hansen Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) Intermediate Casing Cly . . * 24 hr Recap : (max)(current) Intermediate Casing 0 0 Cly 13324 Set AtSize 45.5 L-80 Grade 10.75'' 907-283-1309Unit Phone: 0 Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jacob Hansen 1289 30 7.625" 0 0 Units* Casing Summary Litho logy (%) 0 L-80 MBT 6354' pH 0.778 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.356 C-5n - 0.0 C-2 98 in 1 -Minimum Depth Time: at 30 BPH. Pumped cement and displaced mud to bump the plug. Lost a total of 111 bbls while pumping cement. Set casing 17 6354' 6354' 0' Max @ ft Current 0'0.0 Date: Avg to1520' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) R. Pederson / L. Toussant ShClyst TuffGvlCoal cP 13 4834' Footage 41.25 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - Testing BOP's PV 24 hr Max 29.0 W eight 0 Hours C-3 00 CementCht Sd C-4i C-4n YP (lb/100ft2) 9.10 000 - KCI/Polymer 4.46354'19 Depth in / out Mud Type Lst Type Average -0Backgrou nd (max)Trip N/AN/A Avg Min Comments - RPM ECD (ppg) ml/30min Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm ) -1520' 6354' WOB Surface Casing 100% Gas In Air=10,000 Units-Connectio n 0 3 Geology: No samples collected Fluids: 366 bbls Max Gas: 98 units while circulating hanger and pack off. Testing BOP's at time of report. 6338' 1476' Condition 2-3-CT-A-X-1-ER-TD Bit # 2 5.3 9.875 9.35 PDC 9.35 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Morn ing Re po rt Report # 13 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field - ROP ROP (ft/hr) 5.50 @ Mud Data Depth 25-Mar-2015 23:59 0 Max 0 Chlorides mg/l 28500 RIH with 7.625" casing T/ 6338' MD. Circulated and conditioned mud while cement crew rigged up, well was losing Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap : Completed testing BOP's. P/U BHA and additional drill pipe. RIH T/ 6117' MD, and completed a successful casing Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 29000 0 26-Mar-2015 23:59 0 Max - - ROP ROP (ft/hr) 5.50 @ Mud Data Depth Morn ing Re po rt Report # 14 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Condition 2-3-CT-A-X-1-ER-TD Bit # 2 4.9 9.875 9.30 PDC 9.30 Size 3 Geology: 60% Shale: dk gry-gry, brn, hd, plty, lg frag, homog, non calc, non swlg, com blk lam; 40% Siltstone: lt gry-gry, fri-sft, amor, Fluids: 366 bbls Max Gas: 47 units successful FIT test. RIH to drill ahead at time of report. 6338' 1476' 100% Gas In Air=10,000 Units-Connectio n 0 Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm ) - -1520' 6354' WOB Surface Casing N/AN/A Avg Min Comments - RPM ECD (ppg) ml/30min 2Backgrou nd (max)Trip Average - Mud Type Lst Type - - PDC KCI/Polymer 4.5 6354' 6374'19 - Depth in / out YP (lb/100ft2) 10.10 000 00 CementCht Sd C-4i C-4n 24 hr Max 29.0 W eight 0 Hours C-3 60 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - RIH to Drill Prod. Section PV 4834' 6.75 0.460 Footage -- 41.25 R. Pederson / L. Toussant ShClyst TuffGvlCoal cP 11 Gas Summary 0 0 0 (current) Avg to6354' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 87.4 Flow In (gpm) Flow In (spm) 6354' 6374' 20' Max @ ft Current 6369'80.8 Date: Time: non calc, sdy, loc Cly mtx. test. RIH T/ 6250' MD and tagged. Drilled out float equipment and 20' of new formation. Pulled 2 stands and completed a 5 in 3 6374'Minimum Depth C-5n 6355' 63.0 C-2 47 SPP (psi) Gallons/stroke TFABit Type Depth 2.054 L-80 MBT - pH 0.778 0 0 0 Siltst 7.625" 0 0 Units* Casing Summary Litho logy (%) 0 40 355 731 907-283-1309Unit Phone: 0 Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jacob Hansen Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) Intermediate Casing 10 0 Cly 4455 . . * 24 hr Recap : Drilled ahead T/ 7173' MD and the decision was made to POOH to replace the BHA. POOH T/ 6336' MD, slugged Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 29500 5 27-Mar-2015 23:59 0 Max - - ROP ROP (ft/hr) 5.50 @ Mud Data Depth Morn ing Re po rt Report # 15 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Condition 2-3-CT-A-X-1-ER-TD Bit # 2 4.8 9.875 9.30 PDC 9.30 Size 3 Geology: 50% Siltstone: lt gry-gry, fri-sft, amor, non calc, sdy, loc Cly mtx; 30% Clay: lt gry-gry, lt brn-dk brn, plas, blky, slty, amor; Fluids: 0 bbls Max Gas: 2861 units 6338' 1476' 100% Gas In Air=10,000 Units2861Connection 59 Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm ) - -1520' 6354' WOB Surface Casing N/AN/A Avg Min Comments - RPM ECD (ppg) ml/30min 1Backgrou nd (max)Trip Average - Mud Type Lst Type - - PDC KCI/Polymer 4.4 6354' 7173'20 - Depth in / out YP (lb/100ft2) 10.60 000 00 CementCht Sd C-4i C-4n 24 hr Max 29.0 W eight 26 Hours C-3 1030 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - Changing Out BHA PV 4834' 6.75 0.460 Footage -- 41.25 R. Pederson / L. Toussant ShClyst TuffGvlCoal cP 12 Gas Summary 0 0 0 (current) Avg to6354' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 150.6 Flow In (gpm) Flow In (spm) 6374' 7173' 799' Max @ ft Current 6883'88.6 Date: Time: 10% Sand; 10% Shale. pipe and flow checked, static. POOH T/ surface, and changing out BHA at time of report. 283 in 1 6660'Minimum Depth C-5n 7112' 0.0 C-2 2861 SPP (psi) Gallons/stroke TFABit Type Depth 2.054 L-80 MBT - pH 0.778 0 24 0 Siltst 7.625" 0 0 Units* Casing Summary Litho logy (%) 1 50 40619 0 907-283-1309Unit Phone: 0 Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jacob Hansen Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) Intermediate Casing 215 0 Cly 340820 10 . . * 24 hr Recap : P/U new BHA and RIH T/ Shoe. CBU @ casing shoe which produced no gas. TIH T/7173' MD and encountered no Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 30000 8 28-Mar-2015 23:59 1804 Max - ROP ROP (ft/hr) 5.50 @ Mud Data Depth Morn ing Re po rt Report # 16 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Condition 0-0-NO-A-X-I-NO-BHA Bit # 3 5.2 6.75 9.40 PDC 9.40 Size 4 Geology: 70% Siltstone: lt gry-gry, fri-sft, amor, non calc, sdy, loc Cly mtx; 20% Clay; 10% Sand. Fluids: 0 bbls Max Gas: 2565 units ahead at time of report. 6338' 1476' 100% Gas In Air=10,000 Units2565Connection 129 Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm ) - -6354' 7173' WOB Surface Casing N/AN/A Avg Min Comments - RPM ECD (ppg) ml/30min 2Backgrou nd (max)Trip Average - Mud Type Lst Type - - PDC KCI/Polymer 4.2 7173' 7367'18 - Depth in / out YP (lb/100ft2) 10.10 000 00 CementCht Sd C-4i C-4n 24 hr Max 29.0 W eight 26 Hours C-3 20 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - Drilling 6.75" Prod. Section PV 819' 6.75 0.460 Footage -- 19.89 R. Pederson / L. Toussant ShClyst TuffGvlCoal cP 12 Gas Summary 0 12 0 (current) Avg to7173' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 122.2 Flow In (gpm) Flow In (spm) 7173' 7367' 194' Max @ ft Current 7229'53.1 Date: Time: tight spots. Mad-passes F/ 6439' MD T/ 6539' MD and F/ 7012' MD T/ 7053' MD. Began directional turn and build. Currently drilling 369 in 27 7255'Minimum Depth C-5n 7210' 14.9 C-2 2565 SPP (psi) Gallons/stroke TFABit Type Depth 2.052 L-80 MBT - pH 0.460 0 40 0 Siltst 7.625" 293 100 Units* Casing Summary Litho logy (%) 2 70 41514 4479 907-283-1309Unit Phone: 0 Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jacob Hansen Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) Intermediate Casing 203 0 Cly 328139 10 . . * 24 hr Recap : Continued directional work F/7367' MD T/ 7485' MD. Drilled ahead T/ 8065' MD and CBU at a slow pump rate due to Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 30000 28 29-Mar-2015 23:59 Current Pump & Flow Data 2227 Max - ROP ROP (ft/hr) 5.50 @ Mud Data Depth Morn ing Re po rt Report # 17 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Condition 0-0-NO-A-X-I-NO-BHA Bit # 3 6.6 6.75 9.85 PDC 9.90 Size 4 Geology: 80% Siltstone: lt gry-gry, fri-sft, amor, non calc, sdy, loc Cly mtx; 20% Sand:lt-gy, v-fn grn, cons, sbrn, sbang, pos cly Fluids: 0 bbls Max Gas: 9896 units 6338' 1476' 100% Gas In Air=10,000 Units9896Connection 134 Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm ) - -6354' 7173' WOB Surface Casing N/AN/A Avg Min Comments - RPM ECD (ppg) ml/30min 37Backgrou nd (max)Trip Average - Mud Type Lst Type - - PDC KCI/Polymer 4.2 7173' 8236'19 - Depth in / out YP (lb/100ft2) 9.30 010 00 CementCht Sd C-4i C-4n 24 hr Max 29.0 W eight 62 Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - Drilling 6.75" Prod. Section PV 819' 6.75 0.460 Footage -- 19.89 R. Pederson / L. Toussant ShClyst 10 TuffGvlCoal cP 13 Gas Summary 0 8 0 (current) Avg to7173' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 207.4 Flow In (gpm) Flow In (spm) 7367' 8236' 869' Max @ ft Current 7888'90.9 Date: Time: mtrx; 10% Coal. gas breaking out of the mud. Drilling ahead @ 8236' MD at time of report. 732 in 5 8184'Minimum Depth C-5n 7979' 19.8 C-2 9896 SPP (psi) Gallons/stroke TFABit Type Depth 2.048 L-80 MBT - pH 0.460 0 22 0 Siltst 7.625" 105 308 Units* Casing Summary Litho logy (%) 4 80 80791 29 907-283-1309Unit Phone: 0 Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jacob Hansen Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) Intermediate Casing 293 13 Cly 369945 20 . . * 24 hr Recap : (max)(current) Intermediate Casing 546 8 Cly 615858 40 Set AtSize 45.5 L-80 Grade 10.75'' 907-283-1309Unit Phone: 0 Autumn Gould Maximu m Report By:Logging Engineers:Autumn Gould / Jacob Hansen 20 83081 9559 7.625" 305 104 Units* Casing Summary Litho logy (%) 6 L-80 MBT - pH 0.460 6 63 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 3.049 C-5n 8662' 2.7 C-2 6420 in 4 8276'Minimum Depth Time: amor, non calc, sdy, loc Cly mtx. RIH T/ Bottom with no problems. CBU and began drilling ahead T/ 8960' MD and then CBU to let gas break out of the mud. Drilled 641 8236' 9034' 798' Max @ ft Current 8678'94.1 Date: Avg to7173' Yesterday 's Depth: Current Depth: 24 Hour Pr ogress : 166.7 Flow In (gpm) Flow In (spm) Gas Summary 0 20 0 (current) R. Pederson / L. Toussant ShClyst 40 TuffGvlCoal cP 15 819' 6.75 0.460 Footage -- 19.89 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - Drilling 6.75" Prod. Section PV 24 hr Max 29.0 W eight 79 Hours C-3 00 CementCht Sd C-4i C-4n YP (lb/100ft2) 9.50 020 - - PDC KCI/Polymer 3.4 7173' 9034'19 - Depth in / out Mud Type Lst Type Average 191633Backgrou nd (max)Trip N/AN/A Avg Min Comments - RPM ECD (ppg) ml/30min Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm ) - -6354' 7173' WOB Surface Casing 100% Gas In Air=10,000 Units6420Connection 347 4 Geology: 40% Sand: lt-gy, v-fn grn, cons, sbrn, sbang, pos cly mtrx; 40% Coal: blk, frm-hd, fis, lg frag; 20% Siltstone: lt gry-gry, fri-sft, Fluids: 0 bbls Max Gas: 6420 units T/ 9032' MD and the decision was made to weigh up the mud up to 10.5 ppg MW. Drilling ahead @ 9034' MD at time of report. 6338' 1476' Condition 0-0-NO-A-X-I-NO-BHA Bit # 3 9.1 6.75 10.50 PDC 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activ ity : N/A Saxon 169 Report For: Morn ing Re po rt Report # 18 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field - ROP ROP (ft/hr) 5.50 @ Mud Data Depth 30-Mar-2015 23:59 Current Pump & Flow Data 2695 Max 39 Chlorides mg/l 32000 Drilled ahead T/ 8351' MD and CBU and wiper tripped T/ 7259' MD with no issues. Had a trip gas max of 1916 units. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . . * 24 hr Recap:Continued drilling to 9,156', pumped Hi-Vis/WALL-NUT sweep, 25% increase in cuttings, mostly 1/4" - 1/2" Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 30000 53 31-Mar-2015 23:59 Current Pump & Flow Data 2054 Max - ROP ROP (ft/hr) 2.94 @ Mud Data Depth Morning Report Report # 19 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Condition 0-0-NO-A-X-I-NO-BHA Bit # 3 13.2 6.75 11.45 PDC 11.45 Size 4 Geology: 50% Sand:lt-gry, wh-crm, lt brn, vf-f grn, cons, sbrnd-sbang, sft cly mtrx, v tf, slty; 30% Coal; 10% Clay; 10 Shale Fluids: 0 bbls Max Gas: 7159 units sweep at 9,598'- 10% increase in cuttings. Drilled ahead to 10,010'- TD. Pumping Hi-Vis/WALLNUT sweep at time of report. Continued drilling ahead while weighting up 0.1 ppg at a time. Weighted up from 10.5 ppg to 11.5 ppg. Pumped Hi-Vis/WALLNUT 6338' 1476' 100% Gas In Air=10,000 Units7159Connection 275 Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm) - -6354' 7173' WOB Surface Casing N/AN/A Avg Min Comments - RPM ECD (ppg) ml/30min 274Background (max)Trip Average 1916 Mud Type Lst Type - - PDC KCI/Polymer 4.0 7173' 10010'20 - Depth in / out YP (lb/100ft2) 9.80 022 0 CementChtSd C-4i C-4n 24 hr Max 29.0 Weight 116 Hours C-3 10 0 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 - - TD 6.75" Prod. Section PV 6.75 0.460 Footage -- 19.89 R. Pederson / L. Toussant ShClyst 30 TuffGvlCoal cP 17 Gas Summary 0 19 35 (current)10 Avg to7173' Yesterday's Depth: Current Depth: 24 Hour Progress: 166.7 Flow In (gpm) Flow In (spm) 9034' 10010' 976' Max @ ft Current 9034'94.3 Date: Time: coal fragments. Drilled to 9,342' and pumped Hi-Vis/WALLNUT sweep- 15% coal in samples. Drilled to 9,342' and pumped a 963 9034'Minimum Depth C-5n 9985' 0.0 C-2 7159 SPP (psi) Gallons/stroke TFABit Type Depth 3.546 in 9 L-80 MBT - pH 0.460 0 59 0 7.625" 249 85 Units* Casing Summary Lithology (%)Siltst 819' 105126 246 Jeremy Tiegs / Jacob Hansen 5 907-283-1309Unit Phone: 0 Jeremy Tiegs Maximum Report By:Logging Engineers: 50 Set AtSize 45.5 L-80 Grade 10.75'' Hi-Vis/WALLNUT sweep, returned a 15% increase in cuttings. (max)(current) Intermediate Casing 596 0 Cly 546583 . . . * 24 hr Recap: and ream at 9000', CBU- max gas 7395 units. TIH to bottom. Washed down last stand- 25' fill. Circulated Hi-Vis/WALLNUT sweep (max)(current) Intermediate Casing 1435 0 Cly 644606 Size 45.5 L-80 Grade 10.75'' 907-283-1309Unit Phone: 0 Jeremy Tiegs Maximum Report By:Logging Engineers:Jeremy Tiegs / Jacob Hansen 1 28490 43 7.625" Units* Casing Summary Lithology (%)Siltst 819' - pH 0.460 0 152 0 SPP (psi) Gallons/stroke TFABit Type Depth 4.046 in C-5n - 0.0 C-2 7395 -Minimum Depth Time: wiper tripped to 6,642', CBU, then continued to pull up to 6,300'. CBU while servicing rig and ran back in hole to 9000'. Had to wash 226 10010' 10010' 0' Max @ ft Current -0.0 Date: Avg to7173' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 0 47 77 (current) R. Pederson / L. Toussant ShClyst TuffGvlCoal cP 16 6.75 0.460 Footage -- 19.89 L-80 Set At 0 Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 POOH PV 24 hr Max 29.0 Weight 37 Hours C-3 3 MBT 0 CementChtSd C-4i C-4n YP (lb/100ft2) 9.40 011 - - PDC KCI/Polymer 4.7 7173' 10010'20 - Depth in / out Mud Type Lst Type Average 73951Background (max)Trip N/AN/A Avg Min Comments - RPM ECD (ppg) ml/30min Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm) - -6354' 7173' WOB Surface Casing 100% Gas In Air=10,000 Units0Connection 795 4 Fluids: 0 bbls loss Max Gas: 7395 units Pumped dry job, and POOH at time of report. around- 35% increase in cuttings, sweep began coming back appx. 200 strokes late. Weighted up active system to 11.7 ppg. 6338' 1476' Condition 0-0-NO-A-X-I-NO-BHA Bit # 3 14.3 6.75 11.70 PDC 11.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 20 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field - ROP ROP (ft/hr) 2.94 @ Mud Data Depth 1-Apr-2015 23:59 Current Pump & Flow Data Max 13 Chlorides mg/l 31000 Circulated out sweep- 25% increase in cuttings. Pulled 5 stands and flow checked- static. Slugged pipe and Density (ppg) out (sec/qt) Viscosity Cor Solids % . . . * 24 hr Recap:TOOH to casing shoe while racking back DP in derrick. Flow-checked well- good. Began L/D DP. Once at heavy Density (ppg) out (sec/qt) Viscosity Cor Solids %mg/l 30000 4 Chlorides 2-Apr-2015 23:59 Current Pump & Flow Data Max Depth ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 21 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: 14.4 6.75 11.70 PDC 11.70 Size 6338' 1476' Condition 0-0-NO-A-X-I-NO-BHA Bit # 3 - Fluids: 0 bbls loss Max Gas: 88 units 100% Gas In Air=10,000 Units0Connection 64 Tools Gamma, Resistivity, Nuclear Sources API FL Chromatograph (ppm) - -6354' 7173' WOB Surface Casing N/AN/A Avg Min Comments - RPM ECD (ppg) ml/30min 1Background (max)Trip Average 88 Mud Type Lst Type 4 PDC KCI/Polymer 5.0 7173' 10010'20 - Depth in / out 9.40 000 - - CementChtSd C-4i C-4n Hours C-3 1 MBT YP (lb/100ft2) Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 TIH with Casing PV 24 hr Max TuffGvlCoal cP 16 Footage - L-8029.0 0 0 0 (current) Avg to7173' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 10010' 10010' 0' Max @ ft Current -0.0 Date: weight, TIH out of derrick, and then L/D rest of DP. Slip & Cut Drill line, L/D BHA. Flow-checked well multiple times- good. 7 0-Minimum Depth Time:R. Pederson / L. Toussant ShClyst C-5n - 0.0 C-2 88 SPP (psi) Gallons/stroke TFABit Type Depth 4.046 in 17 0 0 819' - pH 0.460 6.75 0.460 - 19.89 7.625" Units* Casing Summary Lithology (%)Siltst 1 699 22 0 2 907-283-1309Unit Phone: 0 Jeremy Tiegs Maximum Report By:Logging Engineers:Jeremy Tiegs / Jacob Hansen Size 45.5 L-80 Grade 10.75'' Set At Weight Tested upper rams and bag- good. R/U Weatherford to run 5 1/2" casing. RIH w/ casing at time of report. (max)(current) Intermediate Casing 58 0 Cly 12614 d . . . * 24 hr Recap: Cly 559722 10.75'' Set At Weight shoe. CBU with a max gas of 5097u. Recorded casing parameters and continued RIH with casing. Established circulation at (max)(current) Intermediate Casing 765 0 907-283-1309Unit Phone: 0 Jeremy Tiegs Maximum Report By:Logging Engineers:Jeremy Tiegs / Jacob Hansen 3 51409 31 0 78 Units* Casing Summary Lithology (%)Siltst Size 45.5 L-80 Grade - pH 0.460 6.75 0.460 - 19.89 66 0 0 Gallons/stroke TFABit Type Depth 4.046 in C-5n - 0.0 C-2 5100 -Minimum Depth Time:R. Pederson / L. Toussant ShClyst reciprocated and rotated slowly until pressure settled down. Had a small amount of coal at shakers. Continued RIHwith casding to 386 0 10010' 10010' 0' Max @ ft Current -0.0 Date: Avg to7173' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) SPP (psi) 20 29 (current) - L-8029.07.625" Sst (ppb Eq) C-1 C-5i AK-AM-0902208266 Pumping Cement PV 24 hr Max C-3 10 MBT YP (lb/100ft2)cP 17 Footage Cht Sd C-4i C-4n TuffGvlCoal 011 0 PDC KCI/Polymer 5.6 7173' 10010'20 - Depth in / out - - Mud Type Lst Type 4 Average 51000Background (max)Trip N/A Avg Min Comments - RPM ECD (ppg) ml/30min 8.50 Chromatograph (ppm) - -6354' 7173' WOB Surface Casing Cement 100% Gas In Air=10,000 Units0Connection 366 Fluids: 0 bbls loss Max Gas: 5100 units PT'd lines, pumped 20 bbls 13 ppg mud-push, 129.1 bbls 15.3 ppg cement, and chased it with 176 bbls 4%. 7540' MD and 8777' MD. Continued RIH to 9990' MD, CBU while building mud-push and R/U cementers. Pumped 5bbls water and 6338' 1476' Condition 0-0-NO-A-X-I-NO-BHA Bit # 3 - 14.7 6.75 11.70 PDC 11.70 Size Hours 819' Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 22 Customer: Well: Area: Location: Rig: KBU 31-18 Hilcorp Alaska LLC Kenai Peninsula Kenai Gas Field ROP ROP (ft/hr) 2.94 @ Mud Data Tools Gamma, Resistivity, Nuclear Sources API FL N/A Depth 47 Chlorides 3-Apr-2015 23:59 Current Pump & Flow Data Max mg/l 29000 Continuede to RIH with casing to 4869' MD. CBU with a max gas 2745u. Pump pressure increased while circulating, Density (ppg) out (sec/qt) Viscosity Cor Solids % Definitive Survey Report 08 April, 2015 Hilcorp Energy Company Kenai Gas Field KGF 41-18 Pad KBU 31-18 50-133-20649-00 50-133-20649-00 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Kenai Gas Field KGF 41-18 Pad Halliburton Definitive Survey Report Well: Wellbore: KBU 31-18 KBU 31-18 Survey Calculation Method:Minimum Curvature Actual @ 84.86usft Design:KBU 31-18 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual @ 84.86usft North Reference: Well KBU 31-18 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Kenai Gas Field Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: KBU 31-18 usft usft 0.00 0.00 2,356,026.01 275,392.65 66.86Wellhead Elevation:0.00 usft0.00 60° 26' 35.400 N 151° 14' 37.266 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) KBU 31-18 Model NameMagnetics BGGM2014 3/11/2015 16.64 73.43 55,325 Phase:Version: Audit Notes: Design KBU 31-18 1.0 ACTUAL Vertical Section:Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:18.00 275.070.000.0018.00 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 4/8/2015 Survey Date MWD+SC+sag Fixed:v2:standard dec & axial correction + sag198.61 3,417.82 KBU 31-18 MWD+SC+sag1 (KBU 31-18 03/12/2015 MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth + sag3,480.02 3,603.79 KBU 31-18 Interm Azm (KBU 31-18)03/20/2015 MWD+SC+sag Fixed:v2:standard dec & axial correction + sag3,666.67 9,977.36 KBU 31-18 MWD+SC+sag2 (KBU 31-18 03/20/2015 MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 18.00 0.00 0.00 18.00 0.00 0.00-66.86 2,356,026.01 275,392.65 0.00 0.00 UNDEFINED 198.61 0.66 208.47 198.61 -0.91 -0.50113.75 2,356,025.11 275,392.14 0.37 0.41 MWD+SC+sag (1) 260.98 0.63 209.35 260.97 -1.53 -0.84176.11 2,356,024.50 275,391.79 0.05 0.70 MWD+SC+sag (1) 323.62 0.05 195.32 323.61 -1.86 -1.01238.75 2,356,024.17 275,391.60 0.93 0.84 MWD+SC+sag (1) 386.68 0.02 276.28 386.67 -1.88 -1.03301.81 2,356,024.15 275,391.59 0.08 0.86 MWD+SC+sag (1) 446.48 0.55 214.34 446.47 -2.12 -1.20361.61 2,356,023.92 275,391.41 0.90 1.01 MWD+SC+sag (1) 509.16 0.15 277.52 509.15 -2.35 -1.45424.29 2,356,023.68 275,391.15 0.80 1.24 MWD+SC+sag (1) 570.55 0.25 176.10 570.54 -2.48 -1.52485.68 2,356,023.56 275,391.08 0.51 1.30 MWD+SC+sag (1) 631.83 0.43 180.91 631.82 -2.84 -1.52546.96 2,356,023.20 275,391.08 0.30 1.26 MWD+SC+sag (1) 693.14 0.50 172.85 693.13 -3.34 -1.49608.27 2,356,022.70 275,391.10 0.16 1.19 MWD+SC+sag (1) 755.56 0.44 182.57 755.54 -3.85 -1.47670.68 2,356,022.19 275,391.11 0.16 1.12 MWD+SC+sag (1) 817.76 0.88 180.89 817.74 -4.56 -1.48732.88 2,356,021.48 275,391.08 0.71 1.07 MWD+SC+sag (1) 4/8/2015 2:13:53PM COMPASS 5000.1 Build 73 Page 2 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Kenai Gas Field KGF 41-18 Pad Halliburton Definitive Survey Report Well: Wellbore: KBU 31-18 KBU 31-18 Survey Calculation Method:Minimum Curvature Actual @ 84.86usft Design:KBU 31-18 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual @ 84.86usft North Reference: Well KBU 31-18 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 879.77 0.18 177.11 879.75 -5.14 -1.49794.89 2,356,020.90 275,391.07 1.13 1.03 MWD+SC+sag (1) 941.95 0.68 164.24 941.92 -5.59 -1.38857.06 2,356,020.45 275,391.16 0.81 0.88 MWD+SC+sag (1) 1,003.16 0.00 262.40 1,003.13 -5.94 -1.28918.27 2,356,020.10 275,391.26 1.11 0.75 MWD+SC+sag (1) 1,065.29 0.14 31.81 1,065.26 -5.87 -1.24980.40 2,356,020.16 275,391.30 0.23 0.72 MWD+SC+sag (1) 1,127.50 0.55 51.62 1,127.47 -5.62 -0.971,042.61 2,356,020.41 275,391.58 0.68 0.47 MWD+SC+sag (1) 1,190.35 0.00 59.25 1,190.32 -5.44 -0.731,105.46 2,356,020.59 275,391.82 0.88 0.25 MWD+SC+sag (1) 1,252.55 0.08 84.27 1,252.52 -5.43 -0.691,167.66 2,356,020.59 275,391.86 0.13 0.21 MWD+SC+sag (1) 1,313.45 0.00 95.61 1,313.42 -5.43 -0.651,228.56 2,356,020.60 275,391.90 0.13 0.16 MWD+SC+sag (1) 1,376.19 0.33 114.48 1,376.16 -5.50 -0.481,291.30 2,356,020.52 275,392.06 0.53 -0.01 MWD+SC+sag (1) 1,438.28 0.27 112.55 1,438.25 -5.63 -0.181,353.39 2,356,020.38 275,392.36 0.10 -0.32 MWD+SC+sag (1) 1,481.48 0.13 102.31 1,481.45 -5.68 -0.041,396.59 2,356,020.33 275,392.50 0.33 -0.46 MWD+SC+sag (1) 1,556.48 0.17 133.92 1,556.45 -5.78 0.121,471.59 2,356,020.23 275,392.66 0.12 -0.63 MWD+SC+sag (1) 1,620.29 0.45 120.09 1,620.26 -5.97 0.411,535.40 2,356,020.04 275,392.94 0.45 -0.93 MWD+SC+sag (1) 1,681.88 0.36 142.51 1,681.85 -6.24 0.731,596.99 2,356,019.75 275,393.27 0.29 -1.28 MWD+SC+sag (1) 1,743.79 0.34 138.17 1,743.75 -6.53 0.971,658.89 2,356,019.46 275,393.50 0.05 -1.55 MWD+SC+sag (1) 1,805.85 0.26 231.30 1,805.81 -6.76 0.991,720.95 2,356,019.23 275,393.51 0.71 -1.58 MWD+SC+sag (1) 1,867.62 0.97 242.60 1,867.58 -7.09 0.411,782.72 2,356,018.92 275,392.93 1.16 -1.04 MWD+SC+sag (1) 1,929.29 1.63 254.45 1,929.23 -7.56 -0.891,844.37 2,356,018.47 275,391.61 1.15 0.22 MWD+SC+sag (1) 1,992.02 2.23 260.03 1,991.93 -8.01 -2.961,907.07 2,356,018.05 275,389.54 1.00 2.24 MWD+SC+sag (1) 2,053.96 2.89 259.52 2,053.81 -8.51 -5.681,968.95 2,356,017.61 275,386.81 1.07 4.90 MWD+SC+sag (1) 2,115.72 3.67 258.98 2,115.46 -9.17 -9.152,030.60 2,356,017.02 275,383.33 1.26 8.30 MWD+SC+sag (1) 2,177.02 4.28 261.67 2,176.62 -9.87 -13.342,091.76 2,356,016.39 275,379.13 1.04 12.41 MWD+SC+sag (1) 2,240.01 5.00 260.67 2,239.40 -10.66 -18.372,154.54 2,356,015.70 275,374.08 1.15 17.36 MWD+SC+sag (1) 2,301.75 6.05 260.72 2,300.85 -11.62 -24.242,215.99 2,356,014.85 275,368.20 1.70 23.12 MWD+SC+sag (1) 2,364.02 6.75 262.87 2,362.73 -12.60 -31.112,277.87 2,356,014.00 275,361.31 1.19 29.87 MWD+SC+sag (1) 2,426.46 7.62 263.50 2,424.68 -13.53 -38.862,339.82 2,356,013.22 275,353.54 1.40 37.52 MWD+SC+sag (1) 2,486.33 8.65 263.39 2,483.95 -14.50 -47.282,399.09 2,356,012.41 275,345.11 1.72 45.81 MWD+SC+sag (1) 2,548.08 9.41 262.41 2,544.93 -15.70 -56.902,460.07 2,356,011.39 275,335.47 1.26 55.29 MWD+SC+sag (1) 2,612.92 10.34 262.15 2,608.81 -17.19 -67.922,523.95 2,356,010.10 275,324.42 1.44 66.13 MWD+SC+sag (1) 2,672.75 11.02 261.67 2,667.61 -18.75 -78.892,582.75 2,356,008.75 275,313.42 1.15 76.93 MWD+SC+sag (1) 2,736.46 11.66 260.97 2,730.07 -20.65 -91.282,645.21 2,356,007.09 275,301.00 1.03 89.09 MWD+SC+sag (1) 2,798.02 12.49 261.14 2,790.27 -22.65 -104.002,705.41 2,356,005.33 275,288.25 1.35 101.59 MWD+SC+sag (1) 2,860.10 13.41 260.62 2,850.77 -24.86 -117.732,765.91 2,356,003.38 275,274.47 1.49 115.07 MWD+SC+sag (1) 2,922.38 13.88 260.43 2,911.29 -27.27 -132.222,826.43 2,356,001.24 275,259.94 0.76 129.30 MWD+SC+sag (1) 2,984.12 14.59 260.84 2,971.14 -29.74 -147.202,886.28 2,355,999.05 275,244.92 1.16 144.00 MWD+SC+sag (1) 3,046.50 15.31 260.93 3,031.40 -32.29 -163.092,946.54 2,355,996.80 275,228.98 1.15 159.60 MWD+SC+sag (1) 3,105.86 16.05 260.86 3,088.55 -34.83 -178.933,003.69 2,355,994.56 275,213.10 1.25 175.15 MWD+SC+sag (1) 3,170.23 16.62 260.52 3,150.33 -37.76 -196.803,065.47 2,355,991.97 275,195.18 0.90 192.69 MWD+SC+sag (1) 3,232.36 17.29 259.50 3,209.76 -40.91 -214.643,124.90 2,355,989.16 275,177.28 1.18 210.19 MWD+SC+sag (1) 3,294.11 17.86 260.16 3,268.62 -44.20 -232.993,183.76 2,355,986.22 275,158.87 0.98 228.17 MWD+SC+sag (1) 4/8/2015 2:13:53PM COMPASS 5000.1 Build 73 Page 3 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Kenai Gas Field KGF 41-18 Pad Halliburton Definitive Survey Report Well: Wellbore: KBU 31-18 KBU 31-18 Survey Calculation Method:Minimum Curvature Actual @ 84.86usft Design:KBU 31-18 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual @ 84.86usft North Reference: Well KBU 31-18 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,356.33 18.72 257.64 3,327.70 -47.97 -252.153,242.84 2,355,982.82 275,139.65 1.88 246.92 MWD+SC+sag (1) 3,417.82 18.41 258.75 3,385.99 -51.97 -271.313,301.13 2,355,979.17 275,120.42 0.76 265.65 MWD+SC+sag (1) 3,480.02 17.45 257.94 3,445.17 -55.84 -290.063,360.31 2,355,975.66 275,101.60 1.59 283.99 MWD_Interp Azi+sag (2) 3,541.69 17.54 257.09 3,503.99 -59.84 -308.173,419.13 2,355,972.00 275,083.42 0.44 301.67 MWD_Interp Azi+sag (2) 3,603.79 18.39 256.25 3,563.06 -64.26 -326.803,478.20 2,355,967.93 275,064.71 1.43 319.84 MWD_Interp Azi+sag (2) 3,666.67 17.88 255.42 3,622.81 -69.05 -345.783,537.95 2,355,963.50 275,045.64 0.91 338.32 MWD+SC+sag (3) 3,728.61 17.67 257.04 3,681.80 -73.55 -364.143,596.94 2,355,959.35 275,027.20 0.87 356.21 MWD+SC+sag (3) 3,791.29 17.25 258.86 3,741.59 -77.48 -382.533,656.73 2,355,955.77 275,008.74 1.10 374.18 MWD+SC+sag (3) 3,851.86 16.36 259.65 3,799.57 -80.75 -399.733,714.71 2,355,952.83 274,991.48 1.52 391.03 MWD+SC+sag (3) 3,914.44 16.46 260.22 3,859.60 -83.84 -417.143,774.74 2,355,950.06 274,974.02 0.30 408.10 MWD+SC+sag (3) 3,976.61 16.54 259.66 3,919.21 -86.92 -434.533,834.35 2,355,947.31 274,956.58 0.29 425.14 MWD+SC+sag (3) 4,038.79 16.19 259.92 3,978.87 -90.03 -451.773,894.01 2,355,944.53 274,939.28 0.58 442.04 MWD+SC+sag (3) 4,101.03 16.08 259.45 4,038.66 -93.13 -468.793,953.80 2,355,941.75 274,922.21 0.27 458.72 MWD+SC+sag (3) 4,162.30 16.13 258.97 4,097.53 -96.31 -485.484,012.67 2,355,938.89 274,905.46 0.23 475.07 MWD+SC+sag (3) 4,223.21 16.15 258.57 4,156.04 -99.61 -502.094,071.18 2,355,935.91 274,888.79 0.19 491.32 MWD+SC+sag (3) 4,286.01 15.64 258.81 4,216.44 -102.98 -518.954,131.58 2,355,932.85 274,871.87 0.82 507.82 MWD+SC+sag (3) 4,347.97 15.43 258.22 4,276.13 -106.28 -535.224,191.27 2,355,929.86 274,855.54 0.42 523.73 MWD+SC+sag (3) 4,410.09 15.69 258.05 4,335.98 -109.71 -551.524,251.12 2,355,926.74 274,839.18 0.42 539.67 MWD+SC+sag (3) 4,471.98 15.67 258.45 4,395.56 -113.12 -567.904,310.70 2,355,923.64 274,822.74 0.18 555.68 MWD+SC+sag (3) 4,533.85 15.34 258.42 4,455.18 -116.43 -584.104,370.32 2,355,920.63 274,806.48 0.53 571.52 MWD+SC+sag (3) 4,595.62 15.04 258.33 4,514.79 -119.69 -599.964,429.93 2,355,917.67 274,790.57 0.49 587.03 MWD+SC+sag (3) 4,657.59 15.40 258.78 4,574.59 -122.92 -615.904,489.73 2,355,914.75 274,774.56 0.61 602.62 MWD+SC+sag (3) 4,719.03 15.00 259.82 4,633.88 -125.91 -631.734,549.02 2,355,912.05 274,758.68 0.79 618.13 MWD+SC+sag (3) 4,781.90 14.88 260.08 4,694.62 -128.74 -647.694,609.76 2,355,909.53 274,742.67 0.22 633.77 MWD+SC+sag (3) 4,844.67 15.33 260.28 4,755.23 -131.53 -663.814,670.37 2,355,907.04 274,726.51 0.72 649.58 MWD+SC+sag (3) 4,906.27 15.50 260.18 4,814.61 -134.31 -679.944,729.75 2,355,904.57 274,710.32 0.28 665.41 MWD+SC+sag (3) 4,966.83 15.38 259.77 4,872.98 -137.12 -695.824,788.12 2,355,902.06 274,694.39 0.27 680.97 MWD+SC+sag (3) 5,029.84 14.67 259.46 4,933.84 -140.06 -711.894,848.98 2,355,899.42 274,678.28 1.13 696.72 MWD+SC+sag (3) 5,092.84 14.57 259.72 4,994.80 -142.93 -727.534,909.94 2,355,896.85 274,662.58 0.19 712.04 MWD+SC+sag (3) 5,154.47 14.46 260.70 5,054.46 -145.56 -742.754,969.60 2,355,894.51 274,647.32 0.44 726.97 MWD+SC+sag (3) 5,216.69 14.45 260.23 5,114.71 -148.13 -758.065,029.85 2,355,892.22 274,631.96 0.19 742.00 MWD+SC+sag (3) 5,278.76 14.28 260.43 5,174.84 -150.72 -773.255,089.98 2,355,889.92 274,616.73 0.29 756.89 MWD+SC+sag (3) 5,340.37 14.33 259.70 5,234.54 -153.35 -788.245,149.68 2,355,887.58 274,601.69 0.30 771.60 MWD+SC+sag (3) 5,402.88 14.63 259.35 5,295.07 -156.19 -803.615,210.21 2,355,885.03 274,586.27 0.50 786.66 MWD+SC+sag (3) 5,465.35 14.59 258.45 5,355.52 -159.22 -819.075,270.66 2,355,882.29 274,570.75 0.37 801.79 MWD+SC+sag (3) 5,526.75 14.85 258.80 5,414.90 -162.30 -834.375,330.04 2,355,879.50 274,555.40 0.45 816.75 MWD+SC+sag (3) 5,589.58 14.54 258.93 5,475.68 -165.38 -850.005,390.82 2,355,876.72 274,539.71 0.50 832.06 MWD+SC+sag (3) 5,651.89 14.98 256.62 5,535.93 -168.74 -865.515,451.07 2,355,873.65 274,524.14 1.18 847.21 MWD+SC+sag (3) 5,714.11 15.34 257.36 5,595.98 -172.40 -881.375,511.12 2,355,870.29 274,508.22 0.66 862.68 MWD+SC+sag (3) 5,776.55 15.39 258.36 5,656.19 -175.88 -897.545,571.33 2,355,867.11 274,491.98 0.43 878.48 MWD+SC+sag (3) 4/8/2015 2:13:53PM COMPASS 5000.1 Build 73 Page 4 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Kenai Gas Field KGF 41-18 Pad Halliburton Definitive Survey Report Well: Wellbore: KBU 31-18 KBU 31-18 Survey Calculation Method:Minimum Curvature Actual @ 84.86usft Design:KBU 31-18 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual @ 84.86usft North Reference: Well KBU 31-18 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 5,838.74 15.61 259.04 5,716.12 -179.14 -913.845,631.26 2,355,864.17 274,475.63 0.46 894.43 MWD+SC+sag (3) 5,900.11 15.37 259.73 5,775.26 -182.16 -929.955,690.40 2,355,861.45 274,459.47 0.49 910.21 MWD+SC+sag (3) 5,962.76 15.20 259.47 5,835.70 -185.14 -946.195,750.84 2,355,858.78 274,443.17 0.29 926.12 MWD+SC+sag (3) 6,024.48 15.26 257.53 5,895.25 -188.37 -962.085,810.39 2,355,855.85 274,427.23 0.83 941.66 MWD+SC+sag (3) 6,086.42 15.15 258.15 5,955.02 -191.79 -977.965,870.16 2,355,852.72 274,411.28 0.32 957.18 MWD+SC+sag (3) 6,148.60 14.83 258.11 6,015.08 -195.10 -993.705,930.22 2,355,849.71 274,395.49 0.51 972.56 MWD+SC+sag (3) 6,210.54 14.61 257.87 6,074.99 -198.38 -1,009.095,990.13 2,355,846.73 274,380.03 0.37 987.61 MWD+SC+sag (3) 6,272.07 14.77 259.22 6,134.51 -201.47 -1,024.386,049.65 2,355,843.92 274,364.69 0.61 1,002.56 MWD+SC+sag (3) 6,316.96 14.26 259.43 6,177.97 -203.56 -1,035.446,093.11 2,355,842.05 274,353.59 1.14 1,013.39 MWD+SC+sag (3) 6,394.25 13.88 258.36 6,252.94 -207.17 -1,053.886,168.08 2,355,838.78 274,335.09 0.60 1,031.44 MWD+SC+sag (3) 6,456.13 14.65 258.96 6,312.91 -210.17 -1,068.836,228.05 2,355,836.07 274,320.09 1.27 1,046.06 MWD+SC+sag (3) 6,518.63 15.91 259.12 6,373.20 -213.30 -1,085.006,288.34 2,355,833.24 274,303.86 2.02 1,061.89 MWD+SC+sag (3) 6,579.57 15.87 260.71 6,431.81 -216.22 -1,101.426,346.95 2,355,830.63 274,287.39 0.72 1,078.00 MWD+SC+sag (3) 6,642.01 15.90 261.14 6,491.87 -218.92 -1,118.306,407.01 2,355,828.26 274,270.46 0.19 1,094.57 MWD+SC+sag (3) 6,704.20 15.73 261.01 6,551.70 -221.55 -1,135.046,466.84 2,355,825.94 274,253.67 0.28 1,111.02 MWD+SC+sag (3) 6,766.51 15.84 261.64 6,611.66 -224.10 -1,151.806,526.80 2,355,823.70 274,236.87 0.33 1,127.48 MWD+SC+sag (3) 6,828.67 15.40 262.10 6,671.53 -226.47 -1,168.376,586.67 2,355,821.65 274,220.26 0.74 1,143.77 MWD+SC+sag (3) 6,889.80 15.07 262.12 6,730.51 -228.68 -1,184.286,645.65 2,355,819.74 274,204.31 0.54 1,159.43 MWD+SC+sag (3) 6,950.91 15.03 261.90 6,789.52 -230.88 -1,199.996,704.66 2,355,817.84 274,188.56 0.11 1,174.89 MWD+SC+sag (3) 7,013.78 15.18 262.69 6,850.22 -233.08 -1,216.236,765.36 2,355,815.95 274,172.29 0.41 1,190.86 MWD+SC+sag (3) 7,076.57 15.20 263.64 6,910.82 -235.04 -1,232.566,825.96 2,355,814.30 274,155.92 0.40 1,206.96 MWD+SC+sag (3) 7,137.84 14.81 263.22 6,970.00 -236.85 -1,248.326,885.14 2,355,812.78 274,140.13 0.66 1,222.50 MWD+SC+sag (3) 7,200.76 15.51 269.90 7,030.73 -237.81 -1,264.726,945.87 2,355,812.13 274,123.72 2.99 1,238.75 MWD+SC+sag (3) 7,263.45 15.94 277.01 7,091.08 -236.78 -1,281.657,006.22 2,355,813.48 274,106.81 3.15 1,255.70 MWD+SC+sag (3) 7,325.39 16.17 283.70 7,150.61 -233.70 -1,298.477,065.75 2,355,816.88 274,090.05 3.01 1,272.73 MWD+SC+sag (3) 7,387.43 16.70 288.66 7,210.12 -228.80 -1,315.317,125.26 2,355,822.10 274,073.31 2.42 1,289.94 MWD+SC+sag (3) 7,447.84 18.31 294.82 7,267.73 -222.04 -1,332.157,182.87 2,355,829.17 274,056.60 4.06 1,307.31 MWD+SC+sag (3) 7,511.80 18.65 295.79 7,328.40 -213.37 -1,350.487,243.54 2,355,838.18 274,038.44 0.72 1,326.33 MWD+SC+sag (3) 7,570.48 18.46 296.44 7,384.03 -205.15 -1,367.247,299.17 2,355,846.72 274,021.83 0.48 1,343.76 MWD+SC+sag (3) 7,635.18 17.84 297.33 7,445.51 -196.04 -1,385.227,360.65 2,355,856.17 274,004.03 1.05 1,362.47 MWD+SC+sag (3) 7,697.83 17.53 296.55 7,505.20 -187.42 -1,402.197,420.34 2,355,865.11 273,987.23 0.62 1,380.13 MWD+SC+sag (3) 7,759.73 19.06 297.74 7,563.97 -178.55 -1,419.477,479.11 2,355,874.31 273,970.12 2.54 1,398.13 MWD+SC+sag (3) 7,821.92 19.02 298.63 7,622.75 -168.96 -1,437.357,537.89 2,355,884.22 273,952.42 0.47 1,416.79 MWD+SC+sag (3) 7,883.93 18.83 298.83 7,681.41 -159.30 -1,454.997,596.55 2,355,894.22 273,934.97 0.32 1,435.21 MWD+SC+sag (3) 7,945.72 19.02 300.29 7,739.86 -149.41 -1,472.427,655.00 2,355,904.43 273,917.73 0.83 1,453.45 MWD+SC+sag (3) 8,007.18 18.51 300.74 7,798.05 -139.37 -1,489.457,713.19 2,355,914.79 273,900.89 0.86 1,471.30 MWD+SC+sag (3) 8,069.79 18.41 301.13 7,857.44 -129.18 -1,506.467,772.58 2,355,925.30 273,884.09 0.25 1,489.14 MWD+SC+sag (3) 8,132.39 18.04 301.62 7,916.90 -118.99 -1,523.177,832.04 2,355,935.81 273,867.57 0.64 1,506.69 MWD+SC+sag (3) 8,194.55 17.85 302.51 7,976.04 -108.82 -1,539.407,891.18 2,355,946.28 273,851.53 0.54 1,523.76 MWD+SC+sag (3) 8,256.19 19.27 300.85 8,034.47 -98.53 -1,556.107,949.61 2,355,956.88 273,835.03 2.46 1,541.30 MWD+SC+sag (3) 4/8/2015 2:13:53PM COMPASS 5000.1 Build 73 Page 5 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Kenai Gas Field KGF 41-18 Pad Halliburton Definitive Survey Report Well: Wellbore: KBU 31-18 KBU 31-18 Survey Calculation Method:Minimum Curvature Actual @ 84.86usft Design:KBU 31-18 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual @ 84.86usft North Reference: Well KBU 31-18 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,318.95 18.98 300.51 8,093.77 -88.04 -1,573.798,008.91 2,355,967.71 273,817.55 0.49 1,559.84 MWD+SC+sag (3) 8,380.19 18.73 301.30 8,151.72 -77.87 -1,590.778,066.86 2,355,978.19 273,800.76 0.58 1,577.66 MWD+SC+sag (3) 8,441.94 17.94 301.95 8,210.34 -67.69 -1,607.318,125.48 2,355,988.68 273,784.42 1.32 1,595.03 MWD+SC+sag (3) 8,504.22 18.06 302.33 8,269.57 -57.45 -1,623.618,184.71 2,355,999.23 273,768.32 0.27 1,612.17 MWD+SC+sag (3) 8,566.45 17.68 302.40 8,328.80 -47.23 -1,639.738,243.94 2,356,009.75 273,752.39 0.61 1,629.14 MWD+SC+sag (3) 8,627.45 19.02 301.38 8,386.69 -37.09 -1,656.048,301.83 2,356,020.20 273,736.27 2.26 1,646.28 MWD+SC+sag (3) 8,689.77 18.89 301.81 8,445.63 -26.48 -1,673.288,360.77 2,356,031.13 273,719.23 0.31 1,664.39 MWD+SC+sag (3) 8,751.88 19.24 299.81 8,504.34 -16.10 -1,690.718,419.48 2,356,041.84 273,702.01 1.19 1,682.67 MWD+SC+sag (3) 8,813.80 19.31 300.73 8,562.79 -5.79 -1,708.368,477.93 2,356,052.47 273,684.56 0.50 1,701.16 MWD+SC+sag (3) 8,875.40 19.35 301.55 8,620.91 4.75 -1,725.818,536.05 2,356,063.35 273,667.31 0.45 1,719.48 MWD+SC+sag (3) 8,935.36 18.73 302.44 8,677.59 15.11 -1,742.408,592.73 2,356,074.02 273,650.92 1.14 1,736.92 MWD+SC+sag (3) 8,999.81 18.35 303.19 8,738.70 26.22 -1,759.638,653.84 2,356,085.45 273,633.91 0.70 1,755.05 MWD+SC+sag (3) 9,063.02 18.76 297.86 8,798.63 36.42 -1,776.948,713.77 2,356,095.97 273,616.79 2.76 1,773.20 MWD+SC+sag (3) 9,124.21 18.49 299.13 8,856.61 45.74 -1,794.118,771.75 2,356,105.61 273,599.80 0.80 1,791.13 MWD+SC+sag (3) 9,186.59 18.66 299.95 8,915.74 55.53 -1,811.408,830.88 2,356,115.73 273,582.70 0.50 1,809.22 MWD+SC+sag (3) 9,248.60 18.79 299.96 8,974.47 65.47 -1,828.658,889.61 2,356,126.00 273,565.64 0.21 1,827.28 MWD+SC+sag (3) 9,310.22 18.48 300.50 9,032.86 75.39 -1,845.668,948.00 2,356,136.23 273,548.82 0.58 1,845.10 MWD+SC+sag (3) 9,370.33 17.82 301.91 9,089.98 85.08 -1,861.689,005.12 2,356,146.23 273,532.99 1.32 1,861.91 MWD+SC+sag (3) 9,433.69 17.70 304.16 9,150.32 95.62 -1,877.889,065.46 2,356,157.06 273,516.99 1.10 1,878.98 MWD+SC+sag (3) 9,497.38 17.55 304.37 9,211.02 106.47 -1,893.829,126.16 2,356,168.22 273,501.26 0.26 1,895.81 MWD+SC+sag (3) 9,558.17 16.57 305.79 9,269.14 116.72 -1,908.419,184.28 2,356,178.73 273,486.86 1.75 1,911.26 MWD+SC+sag (3) 9,618.68 16.55 307.32 9,327.14 126.99 -1,922.279,242.28 2,356,189.26 273,473.21 0.72 1,925.97 MWD+SC+sag (3) 9,682.03 16.65 307.54 9,387.85 137.99 -1,936.649,302.99 2,356,200.53 273,459.05 0.19 1,941.25 MWD+SC+sag (3) 9,744.66 16.19 309.14 9,447.92 148.97 -1,950.529,363.06 2,356,211.77 273,445.37 1.03 1,956.06 MWD+SC+sag (3) 9,806.11 16.54 310.76 9,506.88 160.09 -1,963.799,422.02 2,356,223.14 273,432.31 0.94 1,970.26 MWD+SC+sag (3) 9,867.52 16.14 311.51 9,565.81 171.45 -1,976.819,480.95 2,356,234.75 273,419.52 0.74 1,984.22 MWD+SC+sag (3) 9,929.94 15.82 313.06 9,625.82 183.01 -1,989.529,540.96 2,356,246.54 273,407.02 0.85 1,997.91 MWD+SC+sag (3) 9,977.36 15.68 314.23 9,671.46 191.89 -1,998.839,586.60 2,356,255.60 273,397.88 0.73 2,007.97 MWD+SC+sag (3) 10,010.00 15.68 314.23 9,702.89 198.05 -2,005.169,618.03 2,356,261.87 273,391.68 0.00 2,014.81 PROJECTED to TD Approved By:Checked By:Date: 4/8/2015 2:13:53PM COMPASS 5000.1 Build 73 Page 6