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Home My WebLink About215-1891. 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: SL Work 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 10,695 feet See Schematic feet true vertical 10,117 feet 9,484 (fish)feet Effective Depth measured 9,484 feet 1,811 feet true vertical 8,954 feet 1,766 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)N/A Baker Swell Pkr; 2,025'' MD 1,966' TVD Packers and SSSV (type, measured and true vertical depth)N/A 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: Scott Warner, Operations Engineer Contact Email:scott.warner@hilcorp.com Authorized Title:Contact Phone:907-564-4506 7,470psi 5,750psi 10,640psi 2,970'2,846' Burst Collapse 3,090psi Production Liner 10,678' Casing Structural 10,010'10,678' 120'Conductor Surface Intermediate 16" 9-58" 120' 2,970' measured TVD 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-189 50-231-20049-00-00 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-CIRI Deep Creek / HV Beluga-Tyonek Gas Happy Valley B-17 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 400 Size 120' 7 320696 0 364 42 N/A Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 539 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 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 Grace Christianson at 8:03 am, May 08, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.05.07 17:28:54 - 08'00' Noel Nocas (4361) RBDMS JSB 051525 BJM 6/26/25 DSR-5/8/25 Page 1/1 Well Name: DCU HVB-017 Report Printed: 5/6/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-231-20049-00-00 Field Name:Deep Creek Unit State/Province:ALASKA Permit to Drill (PTD) #:215-189 Sundry #: Rig Name/No: Jobs Actual Start Date:11/10/2023 End Date:1/3/2024 Report Number 4 Report Start Date 4/2/2025 Report End Date 4/3/2025 Last 24hr Summary PTW/PJSM. MIRU Pollard SL w/.125 wire. PT PCE to 250 psi low / 2500 psi high. Drifted w/4.60" cent & 4.50" LIB to 8134' KB. LIB face is speckled showing possible fill. Ran 2.5" DD Bailer w/mule shoe bottom to 8136' KB, mule shoe tip is flattened and shows metal to metal marks. Ran 2.70" LIB to 8136' KB, picture of half moon across face. Discuss plan forward w/OE. RDMO Pollard SL. Report Number 5 Report Start Date 4/23/2025 Report End Date 4/24/2025 Last 24hr Summary PTW/PJSM, MIRU PWL, PT250 psi low/2500 psi high. Pressure up tbg to 658psi W/ sales gas. Ran 4.50" swage, 4.0" LIB, See FL @ ~6650', SD @ 8124' SLM, 8142' KB, Jar down 2 times, pull 200lb overpull, LIB clean, 4.50" Swage has marks on leading edge of the 4.50". Ran W/ KJ, 3.82" cent, xo,11" ext., xo, 3.75" cent, 3.25" LIB, SD 8126' SLM, hit down once to 8127' SLM, OOH faint impression of 2.75" OD appears to be mandrel of the 4.24" CIBP W/ fill. Sandy mud stuck in flutes of cent. Ran 3.50" P.bailer, SD @ 8124' SLM recovered 2 cups of sandy mud, slight metal marks. Ran , 4.56" G-ring, SD @ 8126' SLM, 8144' KB, jar down for 1.5 hrs total on 2 runs, ring on taper of G-ring from mandrel of CIBP. Report Number 6 Report Start Date 4/24/2025 Report End Date 4/25/2025 Last 24hr Summary PTW/PJSM, Ran 4.75" g-ring, SD @ 7007' SLM 1 tap fall through, work spot few times cleaned up. PU WT 850#, SD @ 7053' SLM, 1 tap falls through, work spot cleans up, CRIH SD @ 8124' SLM, jar down several times, pick off clean, Ran 4 1/2" GR, BS, 4.75" 2 prong chisel W/ 3" ID, SD @ 6297' fall through, 6313' SLM 6331' KB, 600lb overpull & 1 small spang and , come free PU wt. 1000#, GR sheared Pulled BS, 4.75" 2 prong chisel from 6313' SLM Ran 4.50" chisel, SD @ 8126' SLM, Jar down and run into plug for 25 mins, Marks on chisel indicate possibly split the CIBP mandrel. Ran 4.50" magnet, SD @ 8125' SLM (covered in sand and small metal slivers) Ran 3.50" P. bailer, SD @ 8125' SLM, 8143' KB (recovered 4 cups of sand) Report Number 7 Report Start Date 4/25/2025 Report End Date 4/26/2025 Last 24hr Summary PTW/PJSM, Ran 3.50" P.bailer, FL @ ~6830', SD @ 8124' SLM, 8142' KB (2 cups of sand) Ran 4.50" magnet, SD @ 8125' SLM, (small amount of sand & small metal slivers) Ran 2.63" hydrostatic bailer SD @ 8127' SLM (empty. metal marks on bottom) Ran 4.50" chisel, SD @ 8126' SLM, jar down for 1hr. Chisel flattened on bottom ~2.75" indication of contact with CIBP mandrel. Ran 2.63" hydrostatic bailer, SD @ 8128' SLM, (couple cups of wet sand) Ran 4.50" magnet, SD @ 8126' SLM, (small amount of sand & small metal slivers) Report Number 8 Report Start Date 4/26/2025 Report End Date 4/27/2025 Last 24hr Summary PTW/PJSM, Jar down on 4.24" CIBP @ 8126' SLM (8144' KB) for ~2hr and get blown up hole. Hang up coming into to tree. Limited by most of the lubricator being 3 - 1/2". RBIH to 330', tie upside down rope socket and hang off master with a 3.70" swage. Report Number 9 Report Start Date 4/28/2025 Report End Date 4/29/2025 Last 24hr Summary PTW/PJSM, start rigging up PWL. WLV's not sealing on .125" wire. Take WLV's to shop to repair and test. Report Number 10 Report Start Date 4/30/2025 Report End Date 4/30/2025 Last 24hr Summary PT 250 psi low/ 2500 psi high. Fish wire/ tool string, push plug down hole to 9484'kb Updated by SRW 05-05-25 SCHEMATIC Deep Creek Unit Well: Happy Valley B-17 PTD: 215-189 API: 50-231-20049-00-00 PBTD = 9,800’ / PBTVD = 9,258’ TD = 10,695’ / TVD = 10,117’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-52 Weld 15.00”Surf 120' 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,970’ 5-1/2"Prod Csg 17 P-110 GeoConn 4.892”Surf 10,631’ 1 16” 9-5/8” 5-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 2,025’4.85”8.835”Baker Swell Packer 2 9,484’-4.892”CIBP/Fish Pushed to Bottom (4/30/25) 3 9,825’-4.892”CIBP with 25’ cement on top (5/4/16) 4 9,847’ - 4.892” Failed CIBP with 10’ cement on top (5/4/16) 5 10,200’-4.892”CIBP (4/22/16) RKB = 18’ RA Mkr Jt 4,635’ RA Mkr Jt 3,933’ RA Mkr Jt 6,205’ RA Mkr Jt 9,407’ PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Ft.Date Status T-2B 6,184’6,189’5,852’5,857’5 1/4/2024 Open T-6 Stray 6,270’6,287’5,932’5,948’17 1/4/2024 Open T-6b 6,307’6,316’5,967’5,975’9’4/2/2021 Open T-6b 6,319’6,326’5,978’5,985’7’4/2/2021 Open T-6b 6,328’6,339’5,987’5,997’11’4/1/2021 Open T-6d 6,386’6,397’6,040’6,051’11’4/2/2021 Open T-6L 6,402’6,415’6,056’6,068’13 1/4/2024 Open T-7B 6,527’6,535’6,172’6,180’8 1/4/2024 Open T-7 6,541’6,551’6,185’6,194’10’4/2/2021 Open T-10 6,679’6,711’6,314’±6,343’32’9/24/24 Open T-17U 7,013’7,032’±6,626’6,034’19’4/1/2021 Open T-17L 7,074'7,088'6,683’6,697’14’2/1/2021 Open T-70B 9,136’9,166’8,619’8,648’29’9/23/24 Open T-91 9,442’9,472’8,913’8,942’30’5/9/2016 Open T-119 9,866’9,891’9,320’9,343’25’5/2/2016 Isolated T-125 10,000’10,040’9,448’ 9,486’ 40’4/21/201 6 Isolated T-140 10,216’10,240’9,654’ 9,677’ 24’4/18/201 6 Isolated Est. TOC is 9,800’3 4 5 ToC @ 2,710’ MD per 12/30/15 CBL T-6b T-6d T-7 T-17U/L T-70B T-91 T-119 T-125 T-140 T-6L/7B T-6 Stray T-2B T-10 2 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 10,695 feet See Schematic feet true vertical 10,117 feet N/A feet Effective Depth measured 9,125 feet 1,811 feet true vertical 8,609 feet 1,766 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)N/A Baker Swell Pkr; 2,025'' MD 1,966' TVD Packers and SSSV (type, measured and true vertical depth)N/A 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: Scott Warner, Operations Engineer Contact Email:scott.warner@hilcorp.com Authorized Title:Contact Phone:907-564-4506 7,470psi 5,750psi 10,640psi 2,970'2,846' Burst Collapse 3,090psi Production Liner 10,678' Casing Structural 10,010'10,678' 120'Conductor Surface Intermediate 16" 9-58" 120' 2,970' measured TVD 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-189 50-231-20049-00-00 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-CIRI Deep Creek / HV Beluga-Tyonek Gas Happy Valley B-17 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 525 Size 120' 1 520680 0 440 38 324-527 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 928 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 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 Grace Christianson at 7:55 am, May 08, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.05.07 17:28:03 - 08'00' Noel Nocas (4361) BJM 6/26/25 RBDMS JSB 051525 DSR-5/8/25 Page 1/1 Well Name: DCU HVB-017 Report Printed: 5/6/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-231-20049-00-00 Field Name:Deep Creek Unit State/Province:ALASKA Permit to Drill (PTD) #:215-189 Sundry #:324-527 Rig Name/No: Jobs Actual Start Date:9/23/2024 End Date: Report Number 1 Report Start Date 9/23/2024 Report End Date 9/23/2024 Last 24hr Summary PTW/PJSM. MIRU YJ E-line. SITP 540 psi. PT lubricator to 250/3500 psi - good test. RIH w/ 2 3/4" 60 deg 6SPF guns and perf T-70B from 9,136'-9,165'. POOH and bring well online. Well flowing 860 MCFD @ 44 psi. RIH w/ GPT and find fluid level @ ~8,065'. POOH. Secure well, SDFN. Report Number 2 Report Start Date 9/24/2024 Report End Date 9/24/2024 Last 24hr Summary PTW/PJSM. RU YJ E-line. Well flowing 750 MCFD @ 40 psi. RIH w/ GPT and find fluid level @ ~7,290'. RIH w/ 2 3/4" 60 deg 6SPF guns and perf T-10 from 6,679'-6,711'. Little change in flowrate. RIH w/ 5 1/2" CIBP and set @ 9,125' (isolating T-70B & T-91) . RIH w/ GPT and find fluid level @ ~8,370' (below perfs). Well flowing 675 MCFD @ 38 psi. RD YJ E-line. Report Number 3 Report Start Date 10/18/2024 Report End Date 10/19/2024 Last 24hr Summary Request to AOGCC approved to remove plug with Coil Tubing - waiting on coil availability Report Number 4 Report Start Date 4/8/2025 Report End Date 4/9/2025 Last 24hr Summary Coil schedule was full and decision made to not mill with coil due to perforations being subjected to fluids during milling. Job complete g@p @, RIH w/ 5 1/2" CIBP and set @ 9,125' (isolating T-70B & T-91 perf T-10 from 6,679'-6,711 perf T-70B from 9,136'-9,165 Updated by SRW 05-06-25 SCHEMATIC Deep Creek Unit Well: Happy Valley B-17 PTD: 215-189 API: 50-231-20049-00-00 PBTD = 9,800’ / PBTVD = 9,258’ TD = 10,695’ / TVD = 10,117’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-52 Weld 15.00”Surf 120' 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,970’ 5-1/2"Prod Csg 17 P-110 GeoConn 4.892”Surf 10,631’ 1 16” 9-5/8” 5-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 2,025’4.85”8.835”Baker Swell Packer 2 9,125’-4.892”CIBP (9/24/24) 3 9,825’-4.892”CIBP with 25’ cement on top (5/4/16) 4 9,847’ - 4.892” Failed CIBP with 10’ cement on top (5/4/16) 5 10,200’-4.892”CIBP (4/22/16) RKB = 18’ RA Mkr Jt 4,635’ RA Mkr Jt 3,933’ RA Mkr Jt 6,205’ RA Mkr Jt 9,407’ PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Ft.Date Status T-2B 6,184’6,189’5,852’5,857’5 1/4/2024 Open T-6 Stray 6,270’6,287’5,932’5,948’17 1/4/2024 Open T-6b 6,307’6,316’5,967’5,975’9’4/2/2021 Open T-6b 6,319’6,326’5,978’5,985’7’4/2/2021 Open T-6b 6,328’6,339’5,987’5,997’11’4/1/2021 Open T-6d 6,386’6,397’6,040’6,051’11’4/2/2021 Open T-6L 6,402’6,415’6,056’6,068’13 1/4/2024 Open T-7B 6,527’6,535’6,172’6,180’8 1/4/2024 Open T-7 6,541’6,551’6,185’6,194’10’4/2/2021 Open T-10 6,679’6,711’6,314’±6,343’32’9/24/24 Open T-17U 7,013’7,032’±6,626’6,034’19’4/1/2021 Open T-17L 7,074'7,088'6,683’6,697’14’2/1/2021 Open T-70B 9,136’9,166’8,619’8,648’29’9/23/24 Isolated T-91 9,442’9,472’8,913’8,942’30’5/9/2016 Isolated T-119 9,866’9,891’9,320’9,343’25’5/2/2016 Isolated T-125 10,000’10,040’9,448’ 9,486’ 40’4/21/201 6 Isolated T-140 10,216’10,240’9,654’ 9,677’ 24’4/18/201 6 Isolated Est. TOC is 9,800’3 4 5 ToC @ 2,710’ MD per 12/30/15 CBL T-6b T-6d T-7 T-17U/L T-70B T-91 T-119 T-125 T-140 T-6L/7B T-6 Stray T-2B T-10 2 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: 12/05/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241217 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 8/17/2024 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 9/26/2024 YELLOWJACKET PERF-GPT BCU 24 50133206390000 214112 8/19/2024 YELLOWJACKET PERF BCU 25 50133206440000 214132 9/27/2024 YELLOWJACKET PLUG-PERF BLOSSOM 1 50133206480000 215015 9/30/2024 YELLOWJACKET GPT-PLUG-PERF HV B-17 50231200490000 215189 9/23/2024 YELLOWJACKET GPT KU 24-7 50133203520100 205099 10/3/2024 YELLOWJACKET PERF KU 13-06A 50133207160000 223112 12/5/2024 AK E-LINE Plug Setting KU 22-6X 50133205800000 208135 12/8/2024 AK E-LINE Perf KU 23-07A 50133207300000 224126 12/7/2024 AK E-LINE CBL MPU L-17 50029225390000 194169 10/5/2024 YELLOWJACKET PERF MPU R-103 50029237990000 224114 10/14/2024 YELLOWJACKET CBL MPU C-23 50029226430000 196016 11/29/2024 AK E-LINE Plug/cement MPU D-01 50029206640000 181144 11/26/2024 AK E-LINE Perf PBU 13-24B 50029207390200 224087 9/26/2024 YELLOWJACKET CBL PBU 06-07A 50029202990100 224043 9/29/2024 BAKER MRPM PBU 06-18B 50029207670200 223071 10/1/2024 BAKER MRPM PBU 07-32B 50029225250200 204128 10/28/2024 BAKER SPN PBU 14-32B 50029209990200 224073 10/12/2024 BAKER MRPM PBU H-13A 50029205590100 209044 10/23/2024 BAKER SPN PBU L2-20 50029213760000 185134 10/7/2024 BAKER SPN PBU L3-22A 50029216630100 219051 10/9/2024 BAKER PEARL 10 50133207110000 223028 9/25/2024 YELLOWJACKET GPT-PERF PEARL 11 50133207120000 223032 8/29/2024 YELLOWJACKET GPT-PLUG-PERF SRU 241-33 50133206630000 217047 8/23/2024 YELLOWJACKET PERF Please include current contact information if different from above. T39863 T39864 T39865 T39868 T39869 T39870 T39871 T39872 T39873 T39875 T39874 T39867 T39866 T39876 T39877 T39880 T39878 T39879 T39881 T39882 T39883 T39884 T39885 T39886 T39887 HV B-17 50231200490000 215189 9/23/2024 YELLOWJACKET GPT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.18 08:35:44 -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:Scott Warner Subject:RE: HVB-17 AOGCC 10-403 324-527 PTD 215-189 Approved 09-19-24 Date:Friday, October 18, 2024 3:40:00 PM Scott, Hilcorp has approval to proceed with the CT work described in your email below as part of the sundry 324-527. Condition of approval: CT BOP test to 3000 psi. Provide 24 hrs notice for AOGCC opportunity to witness. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Wednesday, October 9, 2024 9:44 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: FW: HVB-17 AOGCC 10-403 324-527 PTD 215-189 Approved 09-19-24 Bryan, We recently executed this job and after perforating the T-70B and T-10, we decided to set a plug when fluid level increased and rate decreased. We had run a production log prior to these perforations and that had shown minimal contribution from the T-91 that was already open therefore we set a plug at 9,125’ thinking we would shut off water we had just perforated in the T- 70B. Rate fell off ~250-300 mscfd after we set the plug so the production log data wasn’t as accurate as we had hoped. I would like to add a coil tubing step to the open sundry and mill the plug that we set in hopes of getting the rate back that we lost. Plan would be: 1. MIRU CT 2. PT BOPE to 250 psi low / 3,500 psi high 3. RIH with mill and mill out CIBP at 9,125’, push debris to bottom a. ~300’ of rathole is open below the bottom set of perfs 4. RDMO I plan to use minimal fluid/only while milling so I hope to not have to blow the well dry with nitrogen but that would be a contingency depending on how milling goes and how much fluid is needed. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Thursday, September 19, 2024 11:22 AM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: HVB-17 AOGCC 10-403 324-527 PTD 215-189 Approved 09-19-24 FYI – Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis 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: 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): 10,695'See Schematic Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 7,470psi 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 Baker Swell Packer; N/A 2,025' MD/1,966' TVD; N/A 10,117'9,800'9,258' Deep Creek HV Beluga-Tyonek Gas 16" 9-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Happy Valley B-17CO 553A Same 10,055'5-1/2" ~2941 psi 10,631' See Schematic Length September 26, 2024 N/A 10,631' Perforation Depth MD (ft): See Attached Schematic 5,750psi 120'120' 2,970' Size 120' 2,970' MD Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 10,640psi 2,846' 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-CIRI 215-189 50-231-20049-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade: scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: m n P s 66 t N 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 7:55 am, Sep 13, 2024 Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2024.09.12 15:47:35 -08'00' 324-527 SFD 9/18/2024 DSR-9/13/24 10-404 BJM 9/18/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.19 10:35:15 -08'00'09/19/24 RBDMS JSB 092324 Well Prognosis Well: HVB-17 Well Name: HVB-17 API Number: 50-231-20049-00 Current Status: Producing Gas Well Permit to Drill Number: 215-189 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 3832 psi @ 8913’ TVD Based on 0.43 psi/ft Max. Potential Surface Pressure: 2941 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.59 psi/ft using 11.4 ppg EMW FIT at the 9-5/8” int. casing shoe Shallowest Allowable Perf TVD: N/A- Proposed perforations are within existing open perfs Top of Applicable Gas Pool: 2126’ MD/ 2125’ TVD (Tyonek/Beluga) Well Status: Online Gas producer flowing at 886 mmscfd, 3.2 bwpd, 45 psi FTP Brief Well Summary HVB-17 has been one of the stronger producing wells at Deep Creek. Producing around ~1MMCFD consistently since coming online in 2016 in the T-91 sand. Production has only recently started falling off, showing a steady ~50-60% decline since September 2020. The T-17 [Lower] was perforated in February 2021 and was ultimately unsuccessful. A flowing PT survey was run in late February 2021 and did not indicate any production from the T- 17 sand and showed the fluid level to be below the T91. In January 2024 additional perforations were added in the T2 – T7 which showed a slight increase in production. The purpose of this sundry is to add additional perforations in the T10 and T70B sands to increase rate. Notes Regarding Wellbore Condition x Inclination o Max inclination = 22 degrees at 7688’ MD o Max DLS: 4.39° at 8620’ MD x Recent Tags o 4/17/24: SL RIH w/ 4.05” GR to 9478’ KB- tag fluid- tag fill at 9738’ KB o 8/26/24: SL RIH w/ 3.75” GR to 9738’ KB – did not see fluid level Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /3,500 psi high 3. RIH and perforate T10 and T70B sands from bottom up with 2-7/8” 60 deg phased perf guns: Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Sand Top MD Btm MD Top TVD Btm TVD Interval T10 ±6,679’ ±6,714’ ±6,314’ ±6,346’ ±32’ T70B ±9,136’ ±9,166’ ±8,619’ ±8,648’ ±29’ Well Prognosis Well: HVB-17 a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations g. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations Updated by DMA 01-11-24 SCHEMATIC Deep Creek Unit Well: Happy Valley B-17 PTD: 215-189 API: 50-231-20049-00-00 PBTD = 9,800’ / PBTVD = 9,258’ TD = 10,695’ / TVD = 10,117’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-52 Weld 15.00”Surf 120' 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,970’ 5-1/2"Prod Csg 17 P-110 GeoConn 4.892”Surf 10,631’ 1 16” 9-5/8” 5-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 2,025’4.85”8.835”Baker Swell Packer 2 9,825’-4.892”CIBP with 25’ cement on top (5/4/16) 3 9,847’ - 4.892” Failed CIBP with 10’ cement on top (5/4/16) 4 10,200’-4.892”CIBP (4/22/16) RKB = 18’ RA Mkr Jt 4,635’ RA Mkr Jt 3,933’ RA Mkr Jt 6,205’ RA Mkr Jt 9,407’ PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Ft.Date Status T-2B 6,184’6,189’5,852’5,857’5 1/4/2024 Open T-6 Stray 6,270’6,287’5,932’5,948’17 1/4/2024 Open T-6b 6,307’6,316’5,967’5,975’9’4/2/2021 Open T-6b 6,319’6,326’5,978’5,985’7’4/2/2021 Open T-6b 6,328’6,339’5,987’5,997’11’4/1/2021 Open T-6d 6,386’6,397’6,040’6,051’11’4/2/2021 Open T-6L 6,402’6,415’6,056’6,068’13 1/4/2024 Open T-7B 6,527’6,535’6,172’6,180’8 1/4/2024 Open T-7 6,541’6,551’6,185’6,194’10’4/2/2021 Open T-17U 7,013’7,032’±6,626’6,034’19’4/1/2021 Open T-17L 7,074'7,088'6,683’6,697’14’2/1/2021 Open T-91 9,442’9,472’8,913’8,942’30’5/9/2016 Open T-119 9,866’9,891’9,320’9,343’25’5/2/2016 Isolated T-125 10,000’10,040’9,448’9,486’40’4/21/2016 Isolated T-140 10,216’10,240’9,654’9,677’24’4/18/2016 Isolated Est. TOC is 9,800’2 3 4 ToC @ 2,710’ MD per 12/30/15 CBL T-6b T-6d T-7 T-17U T-17L T-91 T-119 T-125 T-140 T-6L/7B T-2B/6 Stray Updated by SRW 08-27-24 PROPOSED Deep Creek Unit Well: Happy Valley B-17 PTD: 215-189 API: 50-231-20049-00-00 PBTD = 9,800’ / PBTVD = 9,258’ TD = 10,695’ / TVD = 10,117’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-52 Weld 15.00”Surf 120' 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,970’ 5-1/2"Prod Csg 17 P-110 GeoConn 4.892”Surf 10,631’ 1 16” 9-5/8” 5-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 2,025’4.85”8.835”Baker Swell Packer 2 9,825’-4.892”CIBP with 25’ cement on top (5/4/16) 3 9,847’ - 4.892” Failed CIBP with 10’ cement on top (5/4/16) 4 10,200’-4.892”CIBP (4/22/16) RKB = 18’ RA Mkr Jt 4,635’ RA Mkr Jt 3,933’ RA Mkr Jt 6,205’ RA Mkr Jt 9,407’ PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Ft.Date Status T-2B 6,184’6,189’5,852’5,857’5 1/4/2024 Open T-6 Stray 6,270’6,287’5,932’5,948’17 1/4/2024 Open T-6b 6,307’6,316’5,967’5,975’9’4/2/2021 Open T-6b 6,319’6,326’5,978’5,985’7’4/2/2021 Open T-6b 6,328’6,339’5,987’5,997’11’4/1/2021 Open T-6d 6,386’6,397’6,040’6,051’11’4/2/2021 Open T-6L 6,402’6,415’6,056’6,068’13 1/4/2024 Open T-7B 6,527’6,535’6,172’6,180’8 1/4/2024 Open T-7 6,541’6,551’6,185’6,194’10’4/2/2021 Open T-10 ±6,679’±6,714’±6,314’±6,346’±32’Proposed TBD T-17U 7,013’7,032’±6,626’6,034’19’4/1/2021 Open T-17L 7,074'7,088'6,683’6,697’14’2/1/2021 Open T-70B ±9,136’±9,166’±8,619’±8,648’±29’Proposed TBD T-91 9,442’9,472’8,913’8,942’30’5/9/2016 Open T-119 9,866’9,891’9,320’9,343’25’5/2/2016 Isolated T-125 10,000’10,040’9,448’ 9,486’ 40’4/21/201 6 Isolated T-140 10,216’10,240’9,654’ 9,677’ 24’4/18/201 6 Isolated Est. TOC is 9,800’2 3 4 ToC @ 2,710’ MD per 12/30/15 CBL T-6b T-6d T-7 T-17U/L T-70B T-91 T-119 T-125 T-140 T-6L/7B T-6 Stray T-2B T-10 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. 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: 5/28/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240528 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 241-23 50283201910000 223061 5/13/2024 AK E-LINE CIBP/Cement HV B-12 50231200310000 207123 4/26/2024 AK E-LINE PPROF HV B-16A 50231200400100 222070 4/24/2024 AK E-LINE PPROF HV B-17 50231200490000 215189 4/23/2024 AK E-LINE Perf KTU 43-6XRD2 50133203280200 205117 5/10/2024 AK E-LINE Perf LRU C-02 50283201900000 223057 5/8/2024 AK E-LINE Perf MPU C-11A 50029213210100 221001 2/17/2024 AK E-LINE SetPacker NCIU A-17 50883201880000 223031 4/13/2024 AK E-LINE Plug/Perf/GPT Please include current contact information if different from above. T38851 T38852 T38853 T38854 T38855 T38856 T38857 T38858 HV B-17 50231200490000 215189 4/23/2024 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.29 09:23:53 -08'00' 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: Date: 1/25/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240125 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# HV B-12 50231200310000 207123 1/3/2024 Yellowjacket GPT-PERF HV B-13 50231200320000 207151 12/13/2023 Yellowjacket SCBL HV B-17 50231200490000 215189 1/4/2024 Yellowjacket GPT-PERF HV B-16A 50231200400100 222070 1/12/2024 Yellowjacket GPT-PERF KBU 22-06Y 50133206500000 215044 12/5/2023 Yellowjacket GPT-PERF KTU 43-6XRD2 50133203280200 205117 12/4/2023 YELLOWJACKET GPT-PERF KU 21X-32 50133202040000 169100 12/23/2023 AK E-Line CALIPER TBU M-11 50733205900000 210145 11/10/2023 AK E-Line PL/PERF Please include current contact information if different from above. T38451 T38452 T38453 T38454 T38455 T38456 T38457 T38458 1/31/2024 HV B-17 50231200490000 215189 1/4/2024 Yellowjacket GPT-PERF Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.31 09:35:23 -09'00' 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 10,695 feet See Schematic feet true vertical 10,117 feet N/A feet Effective Depth measured 9,800 feet 1,811 feet true vertical 9,258 feet 1,766 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)N/A Baker Swell Pkr; 2,025'' MD 1,966' TVD Packers and SSSV (type, measured and true vertical depth)N/A 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: 7,470psi 5,750psi 10,640psi 2,970'2,846' Burst Collapse 3,090psi Production Liner 10,678' Casing Structural 10,010'10,678' 120'Conductor Surface Intermediate 16" 9-58" 120' 2,970' measured TVD 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-189 50-231-20049-00-00 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-CIRI Deep Creek / HV Beluga-Tyonek Gas Happy Valley B-17 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 560 Size 120' 0 5801112 0 492 52 Jake Flora, Operations Engineer 323-662 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 1132 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 jake.flora@hilcorp.com 907-777-8442 p k ft t Fra O s O 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 Grace Christianson at 8:55 am, Jan 12, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.01.11 16:34:24 - 09'00' Noel Nocas (4361) RBDMS JSB 012324 DSR-1/26/24 Page 1/1 Well Name: DCU HVB-017 Report Printed: 1/11/2024www.peloton.com Well Operations Summary Jobs Actual Start Date:1/4/2024 End Date: Report Number 1 Report Start Date 1/4/2024 Report End Date 1/5/2024 Operation YJ Eline arrive on HVB pad, obtain PTW and warm up equipment. Hold PJSM. RDMO off HVB12 and move to HVB 17. Spot support equipment , RU, MU GPT tools and PT 250/3000 psi. Pass. Open swab with well flowing (51 psi) and RIH w/ 2-3/4" OD GPT. Logged through perfs and worked through several sand/mud bridges from 8000' to tag depth of 8627' (800'+ above T-91 perfs) @ 9442'-72'. POOH. M/U 2-7/8" x 8' (6spf/60D) perf gun, RIH, correlate, depth shift +2' and perforate the T-7B interval 6527-6535'. Start: 53 psi 5 mn: 53 psi 10 min: 53 psi 15 min: 53 psi. POOH, M/U Gun #2 (13'), RIH, correlate, depth shift +2' and shoot interval T-6L at 6402'-6415'. Start: 53 psi 5 min: 53 psi 10 min: 53 psi 15 min: 53 psi POOH. M/U Gun #3 (17'). RIH, correlate, confirm on depth and shoot T-6 Stray interval at 6270' -6287. Start: 53 psi 5 min: 53 psi 10 min: 51 psi 15 min: 52 psi. POOH. M/U Gun #4 (5'). RIH, correlate, confirm on depth and shoot interval T-2B at 6184'-6189'. Start: 51 psi 5 min: 53 psi 10 min: 49 psi 15 min: 50 psi. POOH Secure well and RD. SDFN and W/O SL HVB-13 operations API: 50-231-20049-00-00 Field: Deep Creek Unit Sundry #: 323-662 State: ALASKA Rig/Service:Permit to Drill (PTD) #:215-189 Updated by DMA 01-11-24 SCHEMATIC Deep Creek Unit Well: Happy Valley B-17 PTD: 215-189 API: 50-231-20049-00-00 PBTD = 9,800’ / PBTVD = 9,258’ TD = 10,695’ / TVD = 10,117’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-52 Weld 15.00”Surf 120' 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,970’ 5-1/2"Prod Csg 17 P-110 GeoConn 4.892”Surf 10,631’ 1 16” 9-5/8” 5-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 2,025’4.85”8.835”Baker Swell Packer 2 9,825’-4.892”CIBP with 25’ cement on top (5/4/16) 3 9,847’ - 4.892” Failed CIBP with 10’ cement on top (5/4/16) 4 10,200’-4.892”CIBP (4/22/16) RKB = 18’ RA Mkr Jt 4,635’ RA Mkr Jt 3,933’ RA Mkr Jt 6,205’ RA Mkr Jt 9,407’ PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Ft.Date Status T-2B 6,184’6,189’5,852’5,857’5 1/4/2024 Open T-6 Stray 6,270’6,287’5,932’5,948’17 1/4/2024 Open T-6b 6,307’6,316’5,967’5,975’9’4/2/2021 Open T-6b 6,319’6,326’5,978’5,985’7’4/2/2021 Open T-6b 6,328’6,339’5,987’5,997’11’4/1/2021 Open T-6d 6,386’6,397’6,040’6,051’11’4/2/2021 Open T-6L 6,402’6,415’6,056’6,068’13 1/4/2024 Open T-7B 6,527’6,535’6,172’6,180’8 1/4/2024 Open T-7 6,541’6,551’6,185’6,194’10’4/2/2021 Open T-17U 7,013’7,032’±6,626’6,034’19’4/1/2021 Open T-17L 7,074'7,088'6,683’6,697’14’2/1/2021 Open T-91 9,442’9,472’8,913’8,942’30’5/9/2016 Open T-119 9,866’9,891’9,320’9,343’25’5/2/2016 Isolated T-125 10,000’10,040’9,448’9,486’40’4/21/2016 Isolated T-140 10,216’10,240’9,654’9,677’24’4/18/2016 Isolated Est. TOC is 9,800’2 3 4 Note: The top of the T-85 sand (9,134’ MD) corresponds to the edge of the Happy Valley PA. Any sands above this depth are associated with the PA and will need to be allocated appropriately. ToC @ 2,710’ MD per 12/30/15 CBL T-6b T-6d T-7 T-17U T-17L T-91 T-119 T-125 T-140 T-6L/7B T-2B/6 Stray 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): 10,695'See Schematic Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 7,470psi 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 Baker Swell Packer; N/A 2,025' MD/1,966' TVD; N/A 10,117'9,800'9,258' Deep Creek HV Beluga-Tyonek Gas 16" 9-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Happy Valley B-17CO 553A Same 10,055'5-1/2" ~2941 psi 10,631' See Schematic Length December 26, 2023 N/A 10,631' Perforation Depth MD (ft): See Attached Schematic 5,750psi 120'120' 2,970' Size 120' 2,970' MD Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 10,640psi 2,846' 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-CIRI 215-189 50-231-20049-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Jake Flora, Operations Engineer AOGCC USE ONLY Tubing Grade: jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: m n P s 66 t N 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 1:01 pm, Dec 12, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.12.12 10:26:37 - 09'00' Noel Nocas (4361) 323-662 SFD 12/15/2023 10-404 BJM 12/20/23 DSR-12/14/23*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.12.21 10:03:02 -09'00' 12/21/23 RBDMS JSB 122623 Well Prognosis Well Name: HVB-17 API Number: 50-231-20049-00 Current Status: Gas Producer Permit to Drill Number: 215-189 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Second Call Engineer: Chad Helgeson (907) 777-8420 (O) (907) 229-4824 (M) Maximum Expected BHP: ~ 3832 psi @ 8913’ TVD (0.43 psi/ft gradient to bottom open perf) Max. Potential Surface Pressure: ~ 2941 psi (Max expected BHP minus gas to surface) Well Status: Online Gas Producer Last well test: 1180 mcfd @ 52 psi, 2 bw Brief Well Summary HVB-17 has been one of the stronger producing wells at Deep Creek. Producing around ~1MMCFD consistently since coming online in 2016 in the T-91 sand. Production has only recently started falling off, showing a steady ~50-60% decline since September 2020. The T-17 [Lower] was perforated in February 2021 and was ultimately unsuccessful. A flowing PT survey was run in late February 2021 and did not indicate any production from the T- 17 sand and showed the fluid level to be below the T91. The objective of this sundry is to increase productivity by perforating additional Tyonek sands. All sands lie in the HV BELUGA-TYONEK GAS POOL. History: January 2021 Drift and tag to 9795’, FL at 8740’ April 2021 Perforated T6, T7, T17 sands (gross interval: 6307’ – 7088’ MD) Procedure: 1. Review approved COAs 2. MIRU Eline, PT lubricator to 3000 psi. 3. Perforate the below sands from the bottom up: Sand Top MD Btm. MD Top TVD Btm TVD Feet T-2B 6,184 6,189 5,852 5,857 5 T-6 Stray 6,270 6,288 5,932 5,949 17 T-6L 6,402 6,416 6,056 6,069 13 T-7B 6,527 6,535 6,172 6,180 8 a. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. b. If necessary use nitrogen to pressure up well during perforating 4. Return to production Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Nitrogen SOP Updated by DMA 04-05-21 SCHEMATIC Deep Creek Unit Well: Happy Valley B-17 PTD: 215-189 API: 50-231-20049-00-00 PBTD = 9,800’ / PBTVD = 9,258’ TD = 10,695’ / TVD = 10,117’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-52 Weld 15.00”Surf 120' 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,970’ 5-1/2"Prod Csg 17 P-110 GeoConn 4.892”Surf 10,631’ 1 16” 9-5/8” 5-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 2,025’4.85”8.835”Baker Swell Packer 2 9,825’-4.892”CIBP with 25’ cement on top (5/4/16) 3 9,847’ - 4.892” Failed CIBP with 10’ cement on top (5/4/16) 4 10,200’-4.892”CIBP (4/22/16) RKB = 18’ RA Mkr Jt 4,635’ RA Mkr Jt 3,933’ RA Mkr Jt 6,205’ RA Mkr Jt 9,407’ PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Ft.Date Status T-6b 6,307’6,316’5,967’5,975’9’4/2/2021 Open T-6b 6,319’6,326’5,978’5,985’7’4/2/2021 Open T-6b 6,328’6,339’5,987’5,997’11’4/1/2021 Open T-6d 6,386’6,397’6,040’6,051’11’4/2/2021 Open T-7 6,541’6,551’6,185’6,194’10’4/2/2021 Open T-17U 7,013’7,032’±6,626’6,034’19’4/1/2021 Open T-17L 7,074'7,088'6,683’6,697’14’2/1/2021 Open T-91 9,442’9,472’8,913’8,942’30’5/9/2016 Open T-119 9,866’9,891’9,320’9,343’25’5/2/2016 Isolated T-125 10,000’10,040’9,448’9,486’40’4/21/2016 Isolated T-140 10,216’10,240’9,654’9,677’24’4/18/2016 Isolated Est. TOC is 9,800’2 3 4 Note: The top of the T-85 sand (9,134’ MD) corresponds to the edge of the Happy Valley PA. Any sands above this depth are associated with the PA and will need to be allocated appropriately. ToC @ 2,710’ MD per 12/30/15 CBL T-6b T-6d T-7 T-17U T-17L T-91 T-119 T-125 T-140 Updated by DMA 12-06-23 PROPOSED Deep Creek Unit Well: Happy Valley B-17 PTD: 215-189 API: 50-231-20049-00-00 PBTD = 9,800’ / PBTVD = 9,258’ TD = 10,695’ / TVD = 10,117’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-52 Weld 15.00”Surf 120' 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,970’ 5-1/2"Prod Csg 17 P-110 GeoConn 4.892”Surf 10,631’ 1 16” 9-5/8” 5-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 2,025’4.85”8.835”Baker Swell Packer 2 9,825’-4.892”CIBP with 25’ cement on top (5/4/16) 3 9,847’ - 4.892” Failed CIBP with 10’ cement on top (5/4/16) 4 10,200’-4.892”CIBP (4/22/16) RKB = 18’ RA Mkr Jt 4,635’ RA Mkr Jt 3,933’ RA Mkr Jt 6,205’ RA Mkr Jt 9,407’ PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Ft.Date Status T-2B ±6,184’±6,189’±5,852’±5,857’±5 Proposed TBD T-6 Stray ±6,270’±6,288’±5,932’±5,949’±17 Proposed TBD T-6b 6,307’6,316’5,967’5,975’9’4/2/2021 Open T-6b 6,319’6,326’5,978’5,985’7’4/2/2021 Open T-6b 6,328’6,339’5,987’5,997’11’4/1/2021 Open T-6d 6,386’6,397’6,040’6,051’11’4/2/2021 Open T-6L ±6,402’±6,416’±6,056’±6,069’13 Proposed TBD T-7B ±6,527’±6,535’±6,172’±6,180’8 Proposed TBD T-7 6,541’6,551’6,185’6,194’10’4/2/2021 Open T-17U 7,013’7,032’±6,626’6,034’19’4/1/2021 Open T-17L 7,074'7,088'6,683’6,697’14’2/1/2021 Open T-91 9,442’9,472’8,913’8,942’30’5/9/2016 Open T-119 9,866’9,891’9,320’9,343’25’5/2/2016 Isolated T-125 10,000’10,040’9,448’9,486’40’4/21/2016 Isolated T-140 10,216’10,240’9,654’9,677’24’4/18/2016 Isolated Est. TOC is 9,800’2 3 4 Note: The top of the T-85 sand (9,134’ MD) corresponds to the edge of the Happy Valley PA. Any sands above this depth are associated with the PA and will need to be allocated appropriately. ToC @ 2,710’ MD per 12/30/15 CBL T-6b T-6d T-7 T-17U T-17L T-91 T-119 T-125 T-140 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. David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal or FAX to 907 564-4424 Received By: Date: Hilcorp North Slope, LLC Date: 06/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company HVA-10 502312002800 204186 4/16/2021 PERF GAMMA RAY / GPT Yellowjacket HVB-17 502312004900 215189 2/1/2021 PERF/GPT Yellowjacket HVB-17 502312004900 215189 4/1/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. Received By: 06/28/2021 37' (6HW By Abby Bell at 12:10 pm, Jun 28, 2021 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal or FAX to 907 564-4424 Received By: Date: Hilcorp North Slope, LLC Date: 06/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company HVA-10 502312002800 204186 4/16/2021 PERF GAMMA RAY / GPT Yellowjacket HVB-17 502312004900 215189 2/1/2021 PERF/GPT Yellowjacket HVB-17 502312004900 215189 4/1/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. Received By: 06/28/2021 37' (6HW By Abby Bell at 12:10 pm, Jun 28, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: 9825; Total Depth measured 10,695 feet 9847; 10200 feet true vertical 10,117 feet N/A feet Effective Depth measured 9,800 feet 2,025 feet true vertical 9,258 feet 1,966 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)Baker Swell Pkr; N/A 2,025' MD 1,966' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ryan Rupert Authorized Title:Operations Manager Contact Email: Contact Phone:777-8503 ryan.rupert@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 10,640psi 120' 2,846'5,750psi Collapse 3,090psi 7,470psi Casing Structural 16" 9-5/8" Length 120' 2,970' 10,631' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 2,111 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-132 111 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 475 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-189 50-231-20049-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 477 Happy Valley B-17 N/A FEE-CIRI: C061589, C061590, C061588 Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Happy Valley Field - HV Beluga/Tyonek Gas PoolN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 5-1/2"10,631'10,055' WINJ WAG 609 Water-Bbl MD 120' 2,970' 0 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:45 pm, Apr 09, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.04.09 11:31:18 -08'00' Taylor Wellman (2143) BJM 5/7/21 321-131 RBDMS HEW 4/13/2021 SFD 4/15/2021DSR-4/12/21 Rig Start Date End Date E-Line 4/1/21 4/2/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name HVB-17 50-231-20049-00-00 215-189 MIRU YellowJacket E-line. Conduct JSA and approve PTW. MU and RIH with 3-3/8" x 7' perf gun with razor charges, 6 spf, 60 deg phasing. Send Correlation data to Geo, confirm on depth. Perforate with well flowing. Perforate T-6B: 6,319' - 6,326'. Shots fired, gun is wet. MU and RIH with 3-3/8" x 9' perf gun with razor charges, 6 spf, 60 deg phasing. Send Correlation data to Geo, confirm on depth. Perforate with well flowing. Perforate T-6B: 6,307' - 6,316'. Shots fired, gun is wet. MU and RIH with 3-3/8" x 10' perf gun with razor charges, 6 spf, 60 deg phasing. Send Correlation data to Geo, confirm on depth. Perforate with well flowing. Perforate T-7: 6,541' - 6,551'. Shots fired, bullnose plug packed with sand. MU and RIH with 3-3/8" x 11' perf gun with razor charges, 6 spf, 60 deg phasing. Send Correlation data to Geo, confirm on depth. Perforate with well flowing. Perforate T-6D: 6,386' - 6,397'. Shots fired, gun is wet. MU and RIH with GPT toolstring with well flowing. Log from surface to 9,600'. POOH. Laydown toolstring. RDMO. 04/01/2021 - Thursday YellowJacket E-line arrive and conduct JSA and approve PTW. MIRU. MU GPT toolstring. PT lubricator low/high. RIH with 3-3/4" GPT and log from surface to 9,610'. Well flowing at ~ 680 MSCFD and 46 psi. POOH and laydown toolstring. MU and RIH with 3-3/8" x 19' long Perf Gun with razor charges, 60 deg phasing, 6 spf. Send correlation data to Geo, confirm on depth. Perforate T-17U zone: 7,013' - 7,032'. Shots fired, gun is wet MU and RIH with 3-3/8" x 11' long Perf Gun with razor charges, 60 deg phasing, 6 spf Send correlation data to Geo, confirm on depth. Perforate T-6b zone: 6,328 - 6,339'. Shots fired, gun is wet. Laydown E-line equipment for the night. Plan to resume perforating in the morning after monitoring well production through the night. 04/02/2021- Friday Daily Operations: Perforate T-6B: 6,307' - 6,316'. Perforate T-6B: 6,319' - 6,326'. Perforate T-17U zone: 7,013' - 7,032' Perforate T-6b zone: 6,328 - 6,339'. Perforate T-6D: 6,386' - 6,397'. Perforate T-7: 6,541' - 6,551' Updated by DMA 04-05-21 SCHEMATIC Deep Creek Unit Well: Happy Valley B-17 PTD: 215-189 API: 50-231-20049-00-00 PBTD = 9,800’ / PBTVD = 9,258’ TD = 10,695’ / TVD = 10,117’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-52 Weld 15.00” Surf 120' 9-5/8" Surf Csg 40 L-80 BTC 8.835” Surf 2,970’ 5-1/2" Prod Csg 17 P-110 GeoConn 4.892” Surf 10,631’ 1 16” 9-5/8” 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 2,025’ 4.85” 8.835” Baker Swell Packer 2 9,825’ - 4.892” CIBP with 25’ cement on top (5/4/16) 3 9,847’ - 4.892” Failed CIBP with 10’ cement on top (5/4/16) 4 10,200’ - 4.892” CIBP (4/22/16) RKB = 18’ RA Mkr Jt 4,635’ RA Mkr Jt 3,933’ RA Mkr Jt 6,205’ RA Mkr Jt 9,407’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft. Date Status T-6b 6,307’ 6,316’ 5,967’ 5,975’ 9’ 4/2/2021 Open T-6b 6,319’ 6,326’ 5,978’ 5,985’ 7’ 4/2/2021 Open T-6b 6,328’ 6,339’ 5,987’ 5,997’ 11’ 4/1/2021 Open T-6d 6,386’ 6,397’ 6,040’ 6,051’ 11’ 4/2/2021 Open T-7 6,541’ 6,551’ 6,185’ 6,194’ 10’ 4/2/2021 Open T-17U 7,013’ 7,032’ ±6,626’ 6,034’ 19’ 4/1/2021 Open T-17L 7,074' 7,088' 6,683’ 6,697’ 14’ 2/1/2021 Open T-91 9,442’ 9,472’ 8,913’ 8,942’ 30’ 5/9/2016 Open T-119 9,866’ 9,891’ 9,320’ 9,343’ 25’ 5/2/2016 Isolated T-125 10,000’ 10,040’ 9,448’ 9,486’ 40’ 4/21/2016 Isolated T-140 10,216’ 10,240’ 9,654’ 9,677’ 24’ 4/18/2016 Isolated Est. TOC is 9,800’ 2 3 4 Note: The top of the T-85 sand (9,134’ MD) corresponds to the edge of the Happy Valley PA. Any sands above this depth are associated with the PA and will need to be allocated appropriately. ToC @ 2,710’ MD per 12/30/15 CBL T-6b T-6d T-7 T-17U T-17L T-91 T-119 T-125 T-140 T-6b 6,307’6,316’5,967’5,975’9’ 4/2/2021 Open T-6b 6,319’6,326’5,978’5,985’7’ 4/2/2021 Open T-6b 6,328’6,339’5,987’5,997’11’ 4/1/2021 Open T-6d 6,386’6,397’ 6,040’6,051’11’ 4/2/2021 Open T-7 6,541’6,551’6,185’6,194’10’ 4/2/2021 Open T-17U 7,013’7,032’±6,626’6,034’19’ 4/1/2021 Openp 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: N2 / Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: 9825; Total Depth measured 10,695 feet 9847; 10200 feet true vertical 10,117 feet N/A feet Effective Depth measured 9,800 feet 2,025 feet true vertical 9,258 feet 1,966 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)Baker Swell Pkr; N/A 2,025' MD 1,966' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ryan Rupert Authorized Title:Operations Manager Contact Email: Contact Phone:777-8503 WINJ WAG 736 Water-Bbl MD 120' 2,970' 0 Oil-Bbl measured true vertical Packer 5-1/2"10,631'10,055' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Happy Valley Field - HV Beluga/Tyonek Gas PoolN/A measured TVD Tubing Pressure 494 Happy Valley B-17 N/A FEE-CIRI: C061589, C061590, C061588 Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-189 50-231-20049-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-046 47 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 46 Authorized Signature with date: Authorized Name: 440 Casing Pressure Liner 567 0 Representative Daily Average Production or Injection Data 120' 2,970' 10,631' Conductor Surface Intermediate Production 7,470psi Casing Structural 16" 9-5/8" Length 5,750psi Collapse 3,090psi ryan.rupert@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 10,640psi 120' 2,846' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 12:15 pm, Mar 23, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.03.23 11:58:57 -08'00' Taylor Wellman (2143) SFD 3/24/2021DSR-3/23/21BJM 4/26/21 RBDMS HEW 3/26/2021 Rig Start Date End Date E-Line 1/29/21 2/22/21 02/22/2021 - Monday Ran EL P/T survey. Looks like all inflow coming from lower perfs (T-91), and no response at upper perfs (T-17L). FL found below bottom perfs. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name HVB-17 50-231-20049-00-00 215-189 Pollard SL ARRIVE ON LOCATION, START EQUIPMENT, PERMIT, JSA, TGSM. RIG UP, TREE CAP STUCK, TOOK A WHILE TO REMOVE. P/T, STANDBY FOR WELL TO BE SHUT IN. RIH W/ 4.52 GRING TO 7,250' KB, NO OBSTRUCTIONS, POOH. RIH W/ 2 7' 4.5” DRIFT DUMMIES W/ 5' OF STEM IN BETWEEN TO 7,200', NO OBSTRUCTIONS, POOH. RIH W/ 3” 8' DD BAILER WITH BALL BOTTOM TO 9,795' KB, POOH FL AT 8,740'KB, FLUID SAMPLE. RIG DOWN. 02/01/2021 - Monday Sign in. PTW, JSA. SIMOPS w/Yellowjacket and Fox N2. Rig up hard lines and lubricator. PT hard lines and lubricator to 250 psi low and 4,000 psi high. TP 600 psi. RIH w/2-3/4" GPT tool, 3-3/8 x 14' HC, 6spf, 60 deg phase and tie into OHL. Went down to 9,570' and pull back up to 9,457'. BHP at this depth was 839 psi w/725 pdi surface pressure. Ran a GPT log from 9,570' to 8,400'. Found FL at 9,320'. Ran perf correlation log from 6,950' to 7,250'. Send all logs to town. Town said to use same log but perf from 7,074' to 7,088' instead of 7,072' to 7,086' because if we have to set patch we need the. extra 2' to cover collar with patch. Started pressuring up with N2. Starting pressure was 725 psi surface. Pressured up to 1,400 psi, spotted and fired gun from 7,074' to 7,088'. Didn't lose hardly any line tension but felt gun go off holding line. Fired gun w/1,402 psi, 5 min - 1,396 psi, 10 min - 1,394 psi and 15 min - 1,393 psi. POOH. All shots fired/gun was dry. Rig down Fox N2 and Yellowjacket. Secure well and turn over to production. 01/29/2021- Friday Daily Operations: Looks like all inflow coming from lower perfs (T-91), a fired gun from 7,074' to 7,088' Updated by CRR 3/12/21 SCHEMATIC Deep Creek Unit Well: Happy Valley B-17 PTD: 215-189 API: 50-231-20049-00-00 PBTD = 9,800’ / PBTVD = 9,258’ TD = 10,695’ / TVD = 10,117’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-52 Weld 15.00” Surf 120' 9-5/8" Surf Csg 40 L-80 BTC 8.835” Surf 2,970’ 5-1/2" Prod Csg 17 P-110 GeoConn 4.892” Surf 10,631’ 1 16” 9-5/8” 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 2,025’ 4.85” 8.835” Baker Swell Packer 2 9,825’ - 4.892” CIBP with 25’ cement on top (5/4/16) 3 9,847’ - 4.892” Failed CIBP with 10’ cement on top (5/4/16) 4 10,200’ - 4.892” CIBP (4/22/16) RKB = 18’ RA Mkr Jt 4,635’ RA Mkr Jt 3,933’ RA Mkr Jt 6,205’ RA Mkr Jt 9,407’ Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft. Date Status T-17L 7,074' 7,088' 6,683’ 6,697’ 14’ 2/1/2021 Open T-91 9,442’ 9,472’ 8,913’ 8,942’ 30’ 5/9/2016 Open T-119 9,866’ 9,891’ 9,320’ 9,343’ 25’ 5/2/2016 Isolated T-125 10,000’ 10,040’ 9,448’ 9,486’ 40’ 4/21/2016 Isolated T-140 10,216’ 10,240’ 9,654’ 9,677’ 24’ 4/18/2016 Isolated Est. TOC is 9,800’ 2 3 4 Note: The top of the T-85 sand (9,134’ MD) corresponds to the edge of the Happy Valley PA. Any sands above this depth are associated with the PA and will need to be allocated appropriately. ToC @ 2,710’ MD per 12/30/15 CBL T-17L 7,074'7,088'6,683’6,697’14’2/1/2021 Open 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 / Patch___ 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? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,695'See schematic Casing Collapse Structural Conductor Surface 3,090 psi Intermediate Production 7,470 psi 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 Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ryan Rupert Operations Manager Contact Email: Contact Phone: 777-8503 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: March 30, 2021 N/A 10,631' Perforation Depth MD (ft): See Attached Schematic 10,631'10,055'5-1/2" 16" 9-5/8" 120' 2,970'5,750 psi 120' 2,846' 120' 2,970' N/A TVD Burst N/A 10,640 psi MDLengthSize CO 553A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE-CIRI: C061589, C061590, C061588 215-189 50-231-20049-00-00 HVB-17 Happy Valley Field - HV Beluga/Tyonek Gas Pool COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic ryan.rupert@hilcorp.com 10,117'9,800'9,258'1,637 See schematic Baker Swell Packer; N/A 2,025' MD/1,966' TVD; N/A Perforation Depth TVD (ft):Tubing Size: m n P s 66 t _ Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:50 am, Mar 16, 2021 321-131 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.03.15 21:18:25 -08'00' Taylor Wellman (2143) DSR-3/16/21SFD 3/16/2021 10-404 BJM 3/26/21 Comm 3/30/21 dts 3/30/2021 JLC 3/30/2021 RBDMS HEW 3/30/2021 Well Prognosis Well: HVB-17 Date: 3/12/2021 Well Name:HVB-17 API Number:50-231-20049-00 Current Status:Gas Producer Leg:N/A Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:215-189 First Call Engineer:Ryan Rupert (907) 777-8503 (O)(907) 301-1736 (C) Second Call Engineer:Ted Kramer (907) 777-8420 (O)(985) 867-0665 (C) Maximum Expected BHP:~ 2307 psi @ 6,702’ TVD (2016 RFT in T-17L from HBV-17) Max. Potential Surface Pressure:~ 1637 psi Using Max BHP minus 0.1 psi/ft. gas gradient to surface). The T-91 sand is the only currently open interval in this well. Although current reservoir pressure is unknown, after a 50hr SI on 9/3/20 the SITP had flattened out at <800psi. Given this, the anticipated reservoir pressure of the proposed T-17 perf interval has been used above to calculate MASP. Well Summary HVB-17 has been one of the stronger producing wells at Deep Creek. Producing around ~1MMCFD consistently since coming online in 2016 in the T-91 sand. Production has only recently started falling off, showing a steady ~50-60% decline since September 2020. The T-17 [Lower] was perforated in February 2021 and was ultimately unsuccessful. A flowing PT survey was run in late February 2021 and did not indicate any production from the T-17 sand and showed the fluid level to be below the T91. Yellowjacket shot 14’ of 3-3/8” guns (46”+ of API penetration). Given reservoir pressure below, the perfs were shot with 500+psi of underbalance (~20% UB). The plan for this project is to perforate additional Tyonek intervals, and possibly perforate the T-17L. Notes Regarding Wellbore Condition x Min ID = 4.767” (Drift ID of 5-1/2” Casing) x Max inclination = 22 degrees x Drifts o 2/1/21: EL made it down to 9570’ (didn’t tag) with a 2.75” GPT tool and a 14’ 3-3/8” perf gun o 1/29/21: SL made it down to 7200’with two 7' 4.5” DRIFT DUMMIES W/ 5' OF STEM IN BETWEEN (19’ OAL) o 1/29/21: SL made it down to 7250’ with a 4.52” gauge ring (no issues) Risks x Nitrogen o Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. o Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) o Ensure all crews are aware of stop work authority Well Prognosis Well: HVB-17 Date: 3/12/2021 EL Perforating 1. MIRU EL 2. PT BOP equipment to 250 psi Low / 4,000 psi High. 3. RU Nitrogen Truck and apply backpressure on well (Consult OE for pressure to use for each interval) 4. Rig up perf gun (Likely 3-3/8” 4-6 spf) 5. RIH and perforate the sands listed in the table below: Consult with OE for what WHP to use. Some interval(s) may be shot flowing as well Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a.Use Gamma/CCL to correlate. b. Record initial and 5/10/15 minute tubing pressures after firing c. Consult with RE/Geo between each perf interval: i. Anthony McConkey: RE - 529-6199 ii. Matthew Petrowsky: Geo – 814-421-6753 6. RD E-Line Unit and turn well over to production. Sand Perforation Top (MD) Perforation Bottom (MD) Perforation Top (TVD) Perforation Bottom (TVD) Total Footage (MD) Expected BHP (psi) T-6a ±6,271’±6,288’±5,933’±5,949’17’~ 1,873 (RFT in HVB-17 – May 2016) T-6b ±6,307’±6,343’±5,967’±6,001’36’~ 1,640 (RFT in HVB-17 – May 2016) T-6c ±6,371’±6,374’±6,027’±6,030’3’~ 2,257 (RFT in HVB-17 – May 2016) T-6d ±6,386’±6,439 ±6,040’±6,090’53’~ 2,257 (RFT in HVB-17 – May 2016) T-6e ±6,453’±6,455 ±6,103’±6,105 2’~ 2,257 (RFT in HVB-17 – May 2016) T-7 ±6,541’±6,551’±6,185’±6,194’10’~ 2,459 (RFT in HVB-17 – May 2016) T-10 ±6,680’±6,713’±6,315’±6,346’33’~ 2,455 (RFT in HVB-17 – May 2016) T-17U ±7,013’±7,032’±6,626’±6,034’19’~ 688 (RFT in HVB-17 – May 2016) T-17L ±7,077’±7,086’±6,686’±6,695’9'~ 2,307 (RFT in HVB-17 – May 2016) Well Prognosis Well: HVB-17 Date: 3/12/2021 Contingency EL Patch 1. MIRU E-line, PT lubricator to 250 psi low / 4,000 psi high 2. RIH W/ GPT tool and find fluid level 3. RU Nitrogen Truck a. Push water back into formation b. Use GPT tool to confirm water level is below interval to perf c. Consult OE for pressure to leave on well for perforating 4. Once fluid level is below interval to patch, RIH and set 5-1/2” Patch 5. RD E-Line Unit and turn well over to production. Attachments: 1. Current schematic 2. Proposed Schematic 3. Standard Well procedure – N2 Operations Updated by CRR 3/12/21 SCHEMATIC Deep Creek Unit Well: Happy Valley B-17 PTD:215-189 API: 50-231-20049-00 PBTD = 9,800’ / PBTVD = 9,258’ TD = 10,695’ / TVD = 10,117’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-52 Weld 15.00”Surf 120' 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,970’ 5-1/2"Prod Csg 17 P-110 GeoConn 4.892”Surf 10,631’ 1 16” 9-5/8” 5-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 2,025’ 4.85” 8.835”Baker Swell Packer 2 9,825’ - 4.892”CIBP with 25’ cement on top (5/4/16) 3 9,847’ - 4.892” Failed CIBP with 10’ cement on top (5/4/16) 4 10,200’ - 4.892”CIBP (4/22/16) RKB = 18’ RA Mkr Jt 4,635’ RA Mkr Jt 3,933’ RA Mkr Jt 6,205’ RA Mkr Jt 9,407’ Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Ft.Date Status T-17L 7,074'7,088'6,683’6,697’14’2/1/2021 Open T-91 9,442’9,472’8,913’8,942’30’5/9/2016 Open T-119 9,866’9,891’9,320’9,343’25’5/2/2016 Isolated T-125 10,000’10,040’9,448’9,486’40’4/21/2016 Isolated T-140 10,216’10,240’9,654’9,677’24’4/18/2016 Isolated Est. TOC is 9,800’2 3 4 Note: The top of the T-85 sand (9,134’ MD) corresponds to the edge of the Happy Valley PA. Any sands above this depth are associated with the PA and will need to be allocated appropriately. ToC @ 2,710’ MD per 12/30/15 CBL Updated by CRR 3/12/21 PROPOSED SCHEMATIC Deep Creek Unit Well: Happy Valley B-17 PTD:215-189 API: 50-231-20049-00 PBTD = 9,800’ / PBTVD = 9,258’ TD = 10,695’ / TVD = 10,117’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-52 Weld 15.00”Surf 120' 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,970’ 5-1/2"Prod Csg 17 P-110 GeoConn 4.892”Surf 10,631’ 1 16” 9-5/8” 5-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 2,025’ 4.85” 8.835”Baker Swell Packer 2 9,825’ - 4.892”CIBP with 25’ cement on top (5/4/16) 3 9,847’ - 4.892” Failed CIBP with 10’ cement on top (5/4/16) 4 10,200’ - 4.892”CIBP (4/22/16) RKB = 18’ RA Mkr Jt 4,635’ RA Mkr Jt 3,933’ RA Mkr Jt 6,205’ RA Mkr Jt 9,407’ Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Ft.Date Status Proposed perfs per sundry T-17L 7,074'7,088'6,683’6,697’14’2/1/2021 Open T-91 9,442’9,472’8,913’8,942’30’5/9/2016 Open T-119 9,866’9,891’9,320’9,343’25’5/2/2016 Isolated T-125 10,000’10,040’9,448’9,486’40’4/21/2016 Isolated T-140 10,216’10,240’9,654’9,677’24’4/18/2016 Isolated Est. TOC is 9,800’2 3 4 Note: The top of the T-85 sand (9,134’ MD) corresponds to the edge of the Happy Valley PA. Any sands above this depth are associated with the PA and will need to be allocated appropriately. ToC @ 2,710’ MD per 12/30/15 CBL 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.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 / Patch___ 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? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,695'See schematic Casing Collapse Structural Conductor Surface 3,090 psi Intermediate Production 7,470 psi 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 Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ryan Rupert Operations Manager Contact Email: Contact Phone: 777-8503 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: February 2, 2021 N/A 10,631' Perforation Depth MD (ft): See Attached Schematic 10,631'10,055'5-1/2" 16" 9-5/8" 120' 2,970'5,750 psi 120' 2,846' 120' 2,970' N/A TVD Burst N/A 10,640 psi MDLengthSize CO 553 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE-CIRI: C061589, C061590, C061588 215-189 50-231-20049-00 HVB-17 Happy Valley Field - HV Beluga/Tyonek Gas Pool COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic ryan.rupert@hilcorp.com 10,118'9,800'9,258'1,637 See schematic Baker Swell Packer; N/A 2,025' MD/1,966' TVD; N/A Perforation Depth TVD (ft):Tubing Size: m n P s 66 t _ Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:42 pm, Jan 22, 2021 321-046 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2021.01.22 14:16:53 -09'00' Taylor Wellman CO 553A DSR-1/22/21 10-404 SFD 1/25/2021 gls 1/27/21 Perforate ___N2 / Patch____ SFD 1/25/2021 -00 SFD 1/25/2021Comm. 1/27/21 dts 1/27/2021 JLC 1/27/2021 RBDMS HEW 1/29/2021 Well Prognosis Well: HVB-17 Date: 1/15/2020 Well Name:HVB-17 API Number:50-231-20049-00 Current Status:Gas Producer Leg:N/A Estimated Start Date:2/2/21 Rig:EL Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:215-189 First Call Engineer:Ryan Rupert (907) 777-8503 (O)(907) 301-1736 (C) Second Call Engineer:Ted Kramer (907) 777-8420 (O)(985) 867-0665 (C) Maximum Expected BHP:~ 2307 psi @ 6,702’ TVD (2016 RFT in T-17 sand from HBV-17) Max. Potential Surface Pressure:~ 1637 psi Using Max BHP minus 0.1 psi/ft. gas gradient to surface). The T-91 sand is the only currently open interval in this well. Although current reservoir pressure is unknown, after a 50hr SI on 9/3/20 the SITP had flattened out at <800psi. Given this, the anticipated reservoir pressure of the proposed T-17 perf interval has been used above to calculate MASP. Well Summary HVB-17 has been one of the stronger producing wells at Deep Creek. Producing around ~1MMCFD consistently since coming online in 2016 in the T-91 sand. Production has only recently started falling off, showing a steady ~50-60% decline since September 2020. The plan for this project is perforate the T17 [Lower] sand. Due to the current rate of the well, we will have a patch on hand to isolate the T17 in the chance that the perforations bring in significant water production. Notes Regarding Wellbore Condition x Min ID = 4.767” (Drift ID of 5-1/2” Casing) x Max inclination = 22 degrees x Last known drift was the 30’ x 3-3/8” perf gun on 5/9/16 Risks x Nitrogen o Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. o Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) o Ensure all crews are aware of stop work authority EL Perforating 1. MIRU EL 2. PT BOP equipment to 250 psi Low / 4,000 psi High. 3. RIH W/ GPT tool and find fluid level 4. Obtain a pressure measurement at mid perf of 9457’ MD Well Prognosis Well: HVB-17 Date: 1/15/2020 5. RU Nitrogen Truck a. Push water back into formation b. Use GPT tool to confirm water level is below interval to perf c. Consult OE for pressure to leave on well for perforating 6. Rig up perf gun (Likely 3-3/8” 4-6 spf) 7. RIH and perforate the sand listed in the table below. Sand MD Top MD Bottom TVD Top TVD Bottom Total Footage (MD) T-17L ±7,064'±7,094'±6,674'±6,702'30’ Consult with OE for what WHP to use Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a.Use Gamma/CCL to correlate. b. Record initial and 5/10/15 minute tubing pressures after firing c. Consult with RE/Geo between each perf interval: i. Anthony McConkey: RE - 529-6199 ii. Matthew Petrowsky: Geo – 814-421-6753 8. RD E-Line Unit and turn well over to production. Contingency Patch 1. MIRU E-line, PT lubricator to 250 psi low / 4,000 psi high 2. RIH W/ GPT tool and find fluid level 3. RU Nitrogen Truck a. Push water back into formation b. Use GPT tool to confirm water level is below interval to perf c. Consult OE for pressure to leave on well for perforating 4. Once fluid level is below T-17L interval, RIH and set 5-1/2” Patch over T-17L perfs 5. RD E-Line Unit and turn well over to production. Attachments: 1. Current schematic 2. Proposed Schematic 3. Standard Well procedure – N2 Operations 30 ft of open perfs T-17L ±7,064'±7,094'±6,674'±6,702'30’ (if T-17L is wet) Updated by CRR 1/18/21 CURRENT SCHEMATIC Deep Creek Unit Well: Happy Valley B-17 PTD:215-189 API: 50-231-20049-00 PBTD = 10,544’ / PBTVD = 9,971’ TD = 10,695’ / TVD = 10,117’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-52 Weld 15.00”Surf 120' 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,970’ 5-1/2"Prod Csg 17 P-110 GeoConn 4.892”Surf 10,631’ 1 16” 9-5/8” 5-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 2,025’ 4.85” 8.835”Baker Swell Packer 2 9,825’ - 4.892”CIBP with 25’ cement on top (5/4/16) 3 9,847’ - 4.892” Failed CIBP with 10’ cement on top (5/4/16) 4 10,200’ - 4.892”CIBP (4/22/16) RKB = 18’ RA Mkr Jt 4,635’ RA Mkr Jt 3,933’ RA Mkr Jt 6,205’ RA Mkr Jt 9,407’ PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Date Size Status T-91 9,442’9,472’8,913’8,942’5/9/2016 3-3/8”Open T-119 9,866’9,891’9,320’9,343’5/2/2016 3-3/8”Isolated T-125 10,000’10,040’9,448’9,486’4/21/2016 3-3/8”Isolated T-140 10,216’10,240’9,654’9,677’4/18/2016 3-3/8”Isolated Est. TOC is 9,800’2 3 4 Note: The top of the T-85 sand (9,134’ MD) corresponds to the edge of the Happy Valley PA. Any sands above this depth are associated with the PA and will need to be allocated appropriately. ToC @ 2,710’ MD per 12/30/15 CBL T-91 Updated by CRR 1/18/21 PROPOSED SCHEMATIC Deep Creek Unit Well: Happy Valley B-17 PTD:215-189 API: 50-231-20049-00 PBTD = 10,544’ / PBTVD = 9,971’ TD = 10,695’ / TVD = 10,117’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-52 Weld 15.00”Surf 120' 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,970’ 5-1/2"Prod Csg 17 P-110 GeoConn 4.892”Surf 10,631’ 1 16” 9-5/8” 5-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 2,025’ 4.85” 8.835”Baker Swell Packer 2 9,825’ - 4.892”CIBP with 25’ cement on top (5/4/16) 3 9,847’ - 4.892” Failed CIBP with 10’ cement on top (5/4/16) 4 10,200’ - 4.892”CIBP (4/22/16) RKB = 18’ RA Mkr Jt 4,635’ RA Mkr Jt 3,933’ RA Mkr Jt 6,205’ RA Mkr Jt 9,407’ Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Ft.Date Status T-17L ±7,064'±7,094'±6,674'±6,702'30’TBD Proposed T-91 9,442’9,472’8,913’8,942’30’5/9/2016 Open T-119 9,866’9,891’9,320’9,343’25’5/2/2016 Isolated T-125 10,000’10,040’9,448’9,486’40’4/21/2016 Isolated T-140 10,216’10,240’9,654’9,677’24’4/18/2016 Isolated Est. TOC is 9,800’2 3 4 Note: The top of the T-85 sand (9,134’ MD) corresponds to the edge of the Happy Valley PA. Any sands above this depth are associated with the PA and will need to be allocated appropriately. ToC @ 2,710’ MD per 12/30/15 CBL T-17L T-91 swell packer 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. `9 oN N = 3 d sc2 I \ E D I Z 21 e w = \Z e U co 8 L oto z W Z B v N a -i 8 6 I 8 121its p N g g g o % • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT 1a. Test: L) Initial LJ Annual LJ Special 1b. Type Test: U Stabilized Lj Non Stabilized U Mullipoint ❑ Constant Time ❑ Isochronal R] Other: Nodal 2. Operator Name: 5. Date Completed: 11. Permit to Drill Number: Hilcorp Alaska, LLC 5/9/2016 215-189 3. Address: 6, Date TD Reached: 12. API Number: 3800 Cenlerpoinl Drive, Suite 1400, Anchorage, AK 99503 December 13, 2015 50- 231-20049-00-00 4a. Location of Well (Governmental Section): 7. KB Elevation above MSL (feet): 13. Well Name and Number: 2947' FSL, 406' FEL, Sec 21, T2S, R13W, SM, AK 611.5" Happy Valley B-17 Top of Productive Horizon: 8. Plug Back Depth(MD+TVD): 14. Field/Pool(s): 4 53' FNL, 223' FWL, Sec 22, T2S, R13W, SM ,AK 10,544' MD 19,971' TVD Happy Valley Field Total Depth: HV Beluga/Tyonek Gas Pool 9. Total Depth (MD + TVD): 243' FSL, 402' FWL, Sec 15, T2S, R13W, SM, AK 10,695' MD / 10,117' TVD 4b. Location of Well (State Base Plane Coordinates NAD 27): 110. Land Use Permit: 15. Property Designation: Surface: x- 223621 y- 2190946 Zone- 4 N/A C061589(SHL), C061590, C061588(BHL) TPI: x- 224308 y- 2193826 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 224493 y- April 16, 7907 Zone- 4 5-1/2" Production String, Perforated 17. Casing Size Weight per foot, Ib. I.D. in inches Set at ft. 19. Perforations: From To 5.1/2" 17# 4.892" 10,631' 9,442'-9,472- 18. Tubing Size Weight per foot, Ib. I.D. In Inches Set at ft. N/A 20. Packer set at ft: 21. GOR cf/bbl: 22. API Liquid Hydrocardbons: 23. Specific Gravity Flowing Fluid (G): 2,025' N/A N/A 0.57 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure (Pa): ❑ Tubing Q Casing 156 F° 3,179 psia @ Datum 8,359' TVDSS psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % CO2: % N2: % H2S: Prover: Meier Run: Tops: 0.57 0 0 26. FLOW DATA TUBING DATA CASING DATA No. Prover Choke Line X Orifice Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow Size (in.) Size (in.) psig Hw F° psig F° psig F° Hr. 1. X 2. X 3. X 4. X 5. X Basic Coefficient Pressure Flow Temp. Gravity Factor Super Comp. Rate of Flow No. (24 -Hour) h Pm Factor F9 Factor Q, Mcfd Fb or Fp Ft Fpv 1. 2. 3. 4. 5. Temperature No. Pr T Tr z for Separator for Flowing Gas Fluid Gg G 1. 2. 3• Critical Pressure 4 Critical Temperature 5. Form 10.421 Rev. 7/2009 CONTINUED ON REVERSE SIDE Submit in Duplicate q,f�? �Ps ,),qI,U Pc Pct Pf pf2 No. Pt P12 c2 P 2 PwPWIP 2_ ps Ps 2 2 1. 2. 3. 4. 5. 25. AOF (Mcfd) 2.705 n Remarks: The Happy Valley 817 is a low rate gas well flowing up a 5-1/2' monobore completion. Due to the partially loaded conditions identified in a flowing-buildup survey, it was determined to not perform a step rate test that would risk loading the well up. The well wasn't making any water during the initial testing conditions, however the flowing survey identified a partially loaded (slugging) region between 5,300'& 9,500'. The AOF was calculated with nodal analysis utilizing flowing and SI buildup data. The attached report from Prosper summarizes the calculated IPR system. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Reservoir Engineer Date 01/09/17 DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing 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= 1> Z mensionless 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 Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 7/2009 Side 2 ######################################## # INFLOW PERFORMANCE DATA (GAS WELL) # ######################################## Reservoir Model MultiRate C and n Reservoir Pressure 3164.00 (psig) Reservoir Temperature 157.00 (deg F) Water -Gas Ratio 0 (STB/MMscf) Condensate Gas Ratio 0 (STB/MMscf) Absolute Open Flom (AOF) 2.705 (MMscf/day) ++++++++++++++++++++++++++++++++++++++++++++++++++++++ + MULTIRATE TEST DATA AND DERIVED MODEL PARAMETERS + ++++++.....++*.....++++++++++++++++++++++++++++++++++++ Gas Rate Pressure (MMscf/day) (prig) 1.828 1996.00 C 0.011509 (Msef/day/psi2) n 0.76681 +++++++++++++++++++++++++++++ + IPR Calculation Results + +++++++++++++++++++++++++++++ dP dP dP Sand Sand dP dP dP dP Total Total Completion Completion Control Control Perforation Damage Penetration Deviation Perforation Damage Penetration Deviation Rate Pressure Temperature Skin Skin Skin Skin Skin Skin Skin Skin Skin Skin Skin Skin Skin Skin (MMscf/day) (ps_i-g) (deg F) (psi) (psi) (psi) (psi) (psi) ----------- -------- (psi) ----------- ----------- (psi) ----- ------ ----------- ----- ---------- --------- ---------- -------------- ----------- ------ le-5 3164.00 ----------- 157.00 0 0 0 --------- 0 0 0 0 0 0 0 0 0 0 0 0.14237 3129.65 156.47 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.28474 3078.48 155.68 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.4271 3017.47 154.74 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.56946 2948.36 153.65 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.71183 2871.89 152.44 0 0 0 0 0 0 0 0 0 0 0 0 0 0 -i- 0.85419 2788.31 L �0 0 0 0 0 0 0 0 t 0 0 0 0 0 0 0.99656 2697.58 149.62 0 0 0 0 0 0 0 0 0 0, 0 0 0 0 1.139 2599.46 147.99 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1.281 2493.46 146.21 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1.424 2378:88 144:24 0 0 0 0 0 0 0 0- 0 0 0 0 0 0 1.566 2254.71 142.05 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1.708 2119.54 139.61 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1.851 1971.35 136.84 -0 0 0 0 0 0 0 0 0 0 0 0- 0 0 1.993 1807.22 133.66 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2.135 1622.56 129.87 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2.278 1409.65 125.26 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2.420 1153.39 119.20 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2.563 814.80 104.56 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2.705 1.42 47.57 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Total Skin : 0 ( = Entered + Perforation + Deviation + Partial Penetration ) Completion Skin 0 ( = Entered + Peirforation + Sand Control ) Perforation Skin 0 Damage Skin 0 Partial Penetration Skin 0 Deviation Skin 0 Sand Control Skin : 0 -2- DATA SUBMITTAL COMPLIANCE REPORT 9/12/2016 Permit to Drill 2151890 Well Name/No. HAPPY VALLEY B-17 Operator HILCORP ALASKA LLC API No. 50-231-20049-00-00 MD 10695 TVD 10117 Completion Date 5/9/2016 Completion Status 1 -GAS Current Status 1 -GAS UIC No REQUIRED INFORMATIONJ / Mud Log JW' �Samples Directional Survey Yes V ' t� p1� DATA INFORMATION U Types Electric or Other Logs Run: ROP/DGR/EWR/ALD/CTN,ALD Borehole Image Dip Interpretation, 5" (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 26660 Digital Data 128 10695 1/22/2016 Electronic Data Set, Filename: Happy Valley B- 17 TC_final.las ED C 26660 Digital Data 3031 10599 1/22/2016 Electronic Data Set, Filename: Hilcorp Alaska _HV_B-17_R0400_ALD dip interp_Final_com plete.las ED C 26660 Digital Data 3031 10599 1/22/2016 Electronic Data Set, Filename: Hilcorp Alaska _HV_B-17_R0400_ALD dip interp_Final_simple.las ED C 26660 Digital Data 1/22/2016 Electronic File: Happy Valley B-17 TC MD.cgm ' ED C 26660 Digital Data 1/22/2016 Electronic File: Happy Valley B-17 TC TVD.cgm ° ED C 26660 Digital Data 1/22/2016 Electronic File: Happy Valley B-17 - Definitive, Survey.pdf ED C 26660 Digital Data 1/22/2016 Electronic File: HVB-17 EOW PlanvsActual_11 x8.5_Landscape.pdf ED C 26660 Digital Data 1/22/2016 Electronic File: HVB-17 GEO Format.txt ED C 26660 Digital Data 1/22/2016 Electronic File: HVB-17 GIS Format.txt ED C 26660 Digital Data 1/22/2016 Electronic File: HVB-17.txt ED C 26660 Digital Data 1/22/2016 Electronic File: Happy Valley B-17 TC_final.dlis ED C 26660 Digital Data 1/22/2016 Electronic File: Happy Valley B-17 TC_final.ver ' ED C 26660 Digital Data 1/22/2016 Electronic File: Happy Valley B-17 TC MD.emf . ED C 26660 Digital Data 1/22/2016 Electronic File: Happy Valley B-17 TC TVD.emf ED C 26660 Digital Data 1/22/2016 Electronic File: Hilcorp Alaska_HV B- 17_R0400_5MD_ALD dip interp_Final.emz AOG(C Page 1 of 7 Monday, September 12, 2016 DATA SUBMITTAL COMPLIANCE REPORT 9/12/2016 Permit to Drill 2151890 Well Name/No. HAPPY VALLEY B-17 Operator HILCORP ALASKA LLC API No. 50-231-20049-00-00 MD 10695 TVD 10117 Completion Date 5/9/2016 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 26660 Digital Data P 1/22/2016 Electronic File: Hilcorp Alaska _HV B- 17_R0400_5MD_ALD dip interp_Final.tif ' ED C 26660 Digital Data 1/22/2016 Electronic File: Hilcorp Alaska _HV_B- 17_R0400_ALD dip interp_Final_Stat2.tiff + ED C 26660 Digital Data 1/22/2016 Electronic File: Hilcorp Alaska _HV_B- 17_R0400_ALD dip interp_Final_Stat3.tiff ED C 26660 Digital Data 1/22/2016 Electronic File: Hilcorp Alaska_HV_B- , 17_RO400_ALD images.dlis ED C 26660 Digital Data 1/22/2016 Electronic File: Hilcorp Alaska _HV_B- 17_R0400_ALD images_dlis.ver ED C 26660 Digital Data 1/22/2016 Electronic File: Happy Valley B-17 TC MD.pdf ED C 26660 Digital Data el/22/2016 Electronic File: Happy Valley B-17 TC TVD.pdf , ED C 26660 Digital Data 1/22/2016 Electronic File: Happy Valley B-17 TC MD.tif ED C 26660 Digital Data 1/22/2016 Electronic File: Happy Valley B-17 TC TVD.tif ' Log C 26660 Log Header Scans 0 0 2151890 HAPPY VALLEY B-17 LOG HEADERS Log C 26661 Mud Log 25 138 10695 1/22/2016 Final Well Report ' 2" MD/TVD Gas Ratio Log 2" MD/TVD Drilling Dynamics Log 2" MD/TVD LWD Combo Log 2" MD/TVD Formation Log 5" MD/TVD Formation Log ED C 26661 Digital Data 10 10750 1/22/2016 Electronic Data Set, Filename: HV_13-17.las fVkAAgL-2, ED C 26661 Digital Data 1/22/2016 Electronic File: HVB-17.dbf ED C 26661 Digital Data 1/22/2016 Electronic File: HVB-17.mdx ED C 26661 Digital Data 1/22/2016 Electronic File: HVB-17 SCL.DBF ED C 26661 Digital Data 1/22/2016 Electronic File: HVB-17 SCL.MDX ED C 26661 Digital Data 1/22/2016 Electronic File: HVB-17 tvd.dbf ED C 26661 Digital Data 1/22/2016 Electronic File: HVB-17 tvd.mdx ' ED C 26661 Digital Data 1/22/2016 Electronic File: hvb-17.hdr " ED C 26661 Digital Data 1/22/2016 Electronic File: hvb-17r.dbf. ED C 26661 Digital Data 1/22/2016 Electronic File: hvb-17r.mdx* ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 11-27-2015.pdf + ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 11-28-2015.pdf . AOG('(' Page 2 of 7 Monday, September 12, 2016 DATA SUBMITTAL COMPLIANCE REPORT 9/12/2016 Permit to Drill 2151890 Well Name/No. HAPPY VALLEY B-17 Operator HILCORP ALASKA LLC API No. 50-231-20049-00-00 MD 10695 TVD 10117 Completion Date 5/9/2016 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 11-29-2015.pdf - ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 11-30-2015.pdf - ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-1-2015.pdf- ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-10-2015.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-11-2015.pdf' ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-12-2015.pdf - ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-13-2015.pdf - ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-14-2015.pdf . ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-15-2015.pdf . ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-16-2015.pdf• ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-17-2015.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-18-2015.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-2-2015.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-3-2015.pdf' ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-4-2015.pdf- ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-5-2015.pdf' ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-6-2015.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-7-2015.pdf' ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-8-2015.pdf - ED C 26661 Digital Data 1/22/2016 Electronic File: AM Report 12-9-2015.pdf . ED C 26661 Digital Data 1/22/2016 Electronic File: Happy Valley B-17 - Final Well. Report.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: Happy Valley B-17 EOW ' Report.docx ED C 26661 Digital Data 1/22/2016 Electronic File: HVB-17 - 5in Formation Log ' MD.pdf ED C 26661 Digital Data f 1/22/2016 Electronic File: HVB-17 - 5in Formation Log, 1 TVD.pdf ED C 26661 Digital Data p 1/22/2016 Electronic File: HVB-17 - Drilling Dynamics Log' MD.pdf AOGCC Page 3 of 7 Monday, September 12, 2016 DATA SUBMITTAL COMPLIANCE REPORT 9/12/2016 Permit to Drill 2151890 Well Name/No. HAPPY VALLEY B-17 Operator HILCORP ALASKA LLC API No. 50-231-20049-00-00 MD 10695 TVD 10117 Completion Date 5/9/2016 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 26661 Digital Data p 1/22/2016 Electronic File: HVB-17 - Drilling Dynamics Log - 1 TVD.pdf ED C 26661 Digital Data Q 1/22/2016 Electronic File: HVB-17 - Formation Log MD.pdf ED C 26661 Digital Data P 1/22/2016 Electronic File: HVB-17 - Formation Log TVD.pdf ED C 26661 Digital Data P 1/22/2016 Electronic File: HVB-17 - Gas Ratio Log MD.pdf ED C 26661 Digital Data P 1/22/2016 Electronic File: HVB-17 -Gas Ratio Log TVD.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HVB-17 - LWD Combo Log . MD.pdf ED C 26661 Digital Data p 1/22/2016 1 Electronic File: HVB-17 - LWD Combo Log TVD.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 - 5in Formation Log , MD.tif ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 - 5in Formation Log TVD.tif ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 - Drilling Dynamics Log MD.tif ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 -Drilling Dynamics Log , TVD.tif ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 - Formation Log MD.tif , ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 - Formation Log TVD.tif ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 -Gas Ratio Log MD.tif . ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 - Gas Ratio Log TVD.tif ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 - LWD Combo Log , MD.tif ED C 26661 Digital Data 1/22/2016 Electronic File: HV 6-17 - LWD Combo Log, TVD.tif ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #1 3096' - , 3265'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #10 5520' - 5585'. pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #11 5600' - . 5700'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #12 5806' - . 5896'.pdf AOGCC Page 4 of 7 Monday, September 12, 2016 DATA SUBMITTAL COMPLIANCE REPORT 9/12/2016 Permit to Drill 2151890 Well Name/No. HAPPY VALLEY B-17 Operator HILCORP ALASKA LLC API No. 50-231-20049-00-00 MD 10695 TVD 10117 Completion Date 5/9/2016 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #13 5940' - 6050'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #14 6250'- - 6420'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #15 6510' -' 6560'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #16 6680' - 6920'. pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #17 7050' - 7200'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #18 7230' - . 7330'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #19 7430'-' 7597'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #2 3270' - . 3367'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #20 7680' - , 7800'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #21 7995' - 8100'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #22 8655' - 8788'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #23 8800' - . 8900'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #24 8950' - 9075'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #25 9410' - . 9485'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #26 9500' - , 9575'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #27 9650' - . 9725'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #28 9855' - 10050'.pdf ED C 26661 Digital Data 1/22/2016 Electronic File: HV B-17 Show #29 10200' - 10250'.pdf AOGCC Page 5 o1'7 Monday, September 12, 2016 DATA SUBMITTAL COMPLIANCE REPORT 9/12/2016 Permit to Drill 2151890 Well Name/No. HAPPY VALLEY B-17 MD 10695 TVD 10117 Completion Date 5/9/2016 ED C 26661 Digital Data ED C 26661 Digital Data ED C 26661 Digital Data ED C 26661 Digital Data ED C 26661 Digital Data ED C 26661 Digital Data ED C 26661 Digital Data ED C 26661 Digital Data Log C 26661 Log Header Scans ED C 26883 Digital Data ED C 26883 Digital Data ED C 26883 Digital Data ED C 26883 Digital Data ED C 26883 Digital Data Log C 26883 Log Header Scans Well Cores/Samples Information: Name Cuttings INFORMATION RECEIVED Interval Start Stop 138 10695 Operator HILCORP ALASKA LLC API No. 50-231-20049-00-00 Completion Status 1 -GAS Current Status 1 -GAS UIC No 1/22/2016 Electronic File: HV B-17 Show #3 3930' - 4050'.pdf 1/22/2016 Electronic File: HV B-17 Show #30 10300'-, 10360'.pdf 1/22/2016 Electronic File: HV B-17 Show #4 4100' - 4280'.pdf 1/22/2016 Electronic File: HV B-17 Show #5 4320' - 4450'.pdf 1/22/2016 Electronic File: HV B-17 Show #6 4565'-, 4684'.pdf 1/22/2016 Electronic File: HV B-17 Show #7 4700' - 4850'.pdf 1/22/2016 Electronic File: HV 6-17 Show #8 4890' - 4970'.pdf 1/22/2016 Electronic File: HV B-17 Show #9 5150' - 5300'.pdf 0 0 2151890 HAPPY VALLEY B-17 LOG HEADERS 1954 1739 3/8/2016 Electronic Data Set, Filename: HVB- , 17_CBL_30DEC15_REPEAT.las 925 1050 3/8/2016 Electronic Data Set, Filename: HVB- 17_CBL_30DEC15_FREE PIPE.las 10557 1748 3/8/2016 Electronic Data Set, Filename: HV6- 17_CBL_30DEC 15_MAIN.las 3/8/2016 Electronic File: HVB-17_CBL_30DEC15.pdf 3/8/2016 Electronic File: HVB-17_CBL _ 30DEC15_img.tiff 0 0 2151890 HAPPY VALLEY B-17 LOG HEADERS - Sent Received 1/29/2016 Sample Set Number Comments 1571 AOGCC Page 6 of 7 Monday, September 12, 2016 DATA SUBMITTAL COMPLIANCE REPORT 9/12/2016 Permit to Drill 2151890 Well Name/No. HAPPY VALLEY B-17 Operator HILCORP ALASKA LLC API No. 50-231-20049-00-00 MD 10695 TVD 10117 Completion Report U Production Test Information Y / 1 Geologic Markers/Tops (Y� COMPLIANCE HISTORY Completion Date: 5/9/2016 Release Date: 10/28/2015 Description Comments: Compliance Reviewed By: Completion Date 5/9/2016 Completion Status 1 -GAS Current Status 1 -GAS UIC No Directional / Inclination Data (D Mud Logs, Image Files, Digital Data NA Core Chips Y /6 Mechanical Integrity Test Information Y /Q Composite Logs, Image, Data Files D Core Photographs Y / p� Daily Operations Summary 0 Cuttings Samples 0Y NA Laboratory Analyses Y / IIiVAJ)J Date Comments - Date: AOGCC Page 7 of 7 Monday, September 12, 2016 STATE OF ALASKA !IJN1 0 2 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas F,-/] - SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: _ 1 ` 1b. Well Class: Development Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Aband.: 5/9/2016 14. Permit to Drill Number/ Sundry: . 215-189 / 315-761 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: November 28, 2015 15. API Number: 50-231-20049-00-00 ` 4a. Location of Well (Governmental Section): Surface: 2947' FSL, 406' FEL, Sec 21, T2S, R13W, SM, AK - Top of Productive Interval: 53' FNL, 223' FWL, Sec 22, T2S, R13W, SM ,AK Total Depth: 243' FSL, 402' FWL, Sec 15, T2S, R13W, SM, AK 8. Date TD Reached: December 13, 2015 16. Well Name and Number: HV B-17 9. Ref Elevations: KB: 611.5'. GL:593.5' BF:593.5' • 17. Field / Pool(s): Happy Valley Field HV Beluga/Tyonek Gas Pool 10. Plug Back Depth MD/TVD: . 10,544' MD / 9,971' TVD 18. Property Designation: C061589(SHL), C061590, C061588(BHL) 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 223621. y- 2190946 • Zone- 4 TPI: x- 224308 y- 2193826 Zone- 4 Total Depth: x- 224493 y- 2194118 Zone- 4 11. Total Depth MD/TVD: . 10,695' MD / 10,117' TVD • 19. Land Use Permit: N/A 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes [ ](attached) No µG Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 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 2"/5" ROP-DGR-EWR-ALD-CTN MD, 2"/5" DGR-EWR-ALD-CTN TVD, 5" ALD Borehole Image Dip Interpretation, 5" Formation Log MD/TVD, 2" Formation Log MD/TVD, 2" LWD Combo Log MD/TVD, 2" Gas Ratio Log MD/TVD, 2" Drilling Dynamics Log MD/TVD, 2"/5" ROP-DGR-EWR-ALD-CTN MD, 2"/5" DGR- EWR-ALD-CTN TVD, END OF WELL REPORT - 5,�kr-A3icd C v Jzt I tc. MG 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 84# X-52 Surface 120' Surface 120' Driven Driven 9-5/8" 40# L-80 Surface 2,970' Surface 2,845' 12-1/4" 305.4 bbls 103 bbls 5-1/2" 17# Pilo Surface 10,631' Surface 10,055' 8-1/2" 490 bbls 0 bbls 24. Open to production or injection? Yes ❑✓ No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): 9,442'- 9,472' MD / 8,913'- 8,942' TVD 9,866' - 9,891' MD 19,320' - 9,343' TVD COMPLETION 10,000'- 10,040' MD / 9,448'- 9,486' TVD 10,216' - 10,240' MD / 9,654' - 9,677' TVD DATE 6 ((p VERIFIED �V 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes [J No [A Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 5/12/2016 Method of Operation (Flowing, gas lift, etc.): Flowing Date of Test: 5/20/2016 Hours Tested: 24 Production for Test Period Oil -Bbl: 0 Gas -MCF: 2517 Water -Bbl: 0 Choke Size: 0 Gas -Oil Ratio: 0 Flow Tubing Press. 1383 Casing Press: 600 Calculated 24 -Hour Rate __No� Oil -Bbl: 0 Gas -MCF: 2517 • Water -Bbl: 0 Oil Gravity - API (corr): N/A Form 10-407 Revised 11/2015 `" CONTINUED ON PAGE 2 RBDMS LLQ �(_�� 6 2016 Submit ORIGINIAL onl 28. CORE DATA Conventional G .�s): Yes ❑ No ❑✓ Sidewall Cores. (es ❑ No E] If 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 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top N/A N/A Permafrost - Base N/A N/A Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 9,442' 8,913' information, including reports, per 20 AAC 25.071. BLG-29 3,090' 2,957' BLG-36 3,342' 3,192' BLG-45 3,937' 3,750' BLG 120 5,614' 5,319' BLG 135 5,982' 5,664' Tyonek 6,089' 5,763' T8 6,538' 6,183' T25 7,391' 6,980' T80 8,946' 8,437' T100 9,422' 8,894' T140 9,957' 9,407' T150 10,377' 9,809' T155 10,434' 9,864' Formation at total depth: iTyonek 31. List of Attachments: Wellbore Schematic, Completion Composite 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(@_hi1qg1p.com Printed Name: Mont M ers Title: Drilling Engineer Signature: Coo b0114- TVV/ 6/ ZPhone: 777-8431 �3$ � Date: / Z Zo It, 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 1a: 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 1b: 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, Ground Level, and Base Flange 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 11/2015 Submit ORIGINAL Only Deep Creek Unit CUKRENT SCHEMATIC Well: Happy Valley B-17 PTD: 215-189 API: 50-231-20049-00 11il-1, Alaska, LLC RKB = 18' 16"4:k;' a i:Sid I t tiv 9-5/8" CASING DETAIL Size Type Wt Grade Conn. ID I Top Btm 16" Conductor- Driven to Set Depth 84 X-52 Weld 15.00" Surf 120' 9-5/8" Surf Csg 40 L-80 BTC 8.835" Surf 2,970' 5-1/2" Prod Csg 17 P-110 GeoConn 4.892" Surf 10,631' JEWELRY DETAIL No. Depth ID OD Item 1 2,025' 4.85" 8.835" Baker Swell Packer 2 9,825' - 4.892" CIBP 3 9,847' 4.892" CIBP 4 10,200' 8,942' 4.892" CIBP RA Mkr Jt 1 " 5 3,933' PERFORATION DETAIL PBTD = 10,544'/ PBTVD = 9,971' TD = 10,695' / TVD = 10,117' Updated by CJD 6/2/16 *.' Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Size Status T-100 9,442' 9,472' 8,913' 8,942' 5/9/2016 3-3/8" Open ' T-140 9,866' 9,891' 9,320' 9,343' 5/2/2016 3-3/8" Isolated RA Mkr Jt , , T-140 10,000' 10,040' 9,448' 9,486' 4/21/2016 3-3/8" Isolated 4,635'r. T-150 10,216' 10,240' 9,654' 9,677' 4/18/2016 3-3/8" Isolated RA Mkr Jt , 6,205' Z RA Mkr Jt 9,407' ` • ' t : Est. TOC is 2 ,° 9,800' 3 + M t 4 P .... 5-1/2" PBTD = 10,544'/ PBTVD = 9,971' TD = 10,695' / TVD = 10,117' Updated by CJD 6/2/16 Hila.. p Energy Company Composit- Aeport Well Name: DCU HVB-17 Field: Happy Valley County/State: , AK (LAT/LONG): :vation (RKB): API #: 50-231-20049-00 Spud Date: Job Name: 1512577C HVB-17 COMPLETION Contractor AFE #: AFE $: Activity Date Ops Summary 12/29/2015 Weather delay due to high winds, rain on ice.,Began permits and rig up. Logged CBL from tag depth of 10,542'-1,750'. RDMO, 3/11/2016 Obtain PTW. Hold safety meting. Discuss site specific hazards.,RU SLB CTU 12 with 1.75" CT.,Start BOPE test. Test all rams and valves to 250 low and 4500 high for 5 minues. Aogcc 24hr witness notification sent 3/10/16 @ 1730 hrs. Witness waived by Jimr Regg on 3/10/16 @ 1819. BOPE test completed no failures. Fluid pack IA with field triplx. Pressure up to 2500 psi. Triplex out of fluid. Shut down for night with coil crew. Fill triplex and leave IA shut in. Location secure. 3/12/2016 Obtain PTW. Hold safety meeting. Discuss job procedure/ Pump rates and expected returns. Discuss N2 Hazards.,No flow night cap and remove. Pick injector head. Stab 10' lubricator. Make up Roll-on Ct connector, 2 straight bars and 2.5" Ball drop nozzle. Air Liquid on location. Transfer N2 . Stab on well.,Pressure test lubricator to 250/4500 psi . Good test. Bleed down . RIH Hook up Field triplex to 9 5/8" x 5 1/2" casing (IA) . Pressure test IA to 2500 psi for 30 minutes with no more than 10% loss. Start time 0908 @ 2570 psi. End 0941@ 2415 psi. Loss of 155 psi over 30 minute test.,Perform weight checks while RIH. Fire N2 pump. Pt n2 lines to 250/4500 psi. Cooling down N2. ONline with n2 at 800 scf/min while RIH at 7031'. Weight check 9982'17k. Continue RIH tagged PBTD @ 10537'. Pick up and tag again. Solid tag. PU off PBTD 2'.,Increase N2 rate to 1500 scf/min. Good returns to tank. Continue to Blow well dry.,240 bbls returned to OT. Wellbore volume 245 bbls. Mostly N2 at surface. Small drips of fluid. 243 bbls returned. All N2 gas at return tank.,Start POOH to surface. Tagged up at surface. 1973 psi WHP .,Increase N2 rate to 2950 scf/min. 2587 psi. Down on N2 pump. Close master and swab. Bleed down stack. 275,000 scf pumped for N2 lift. 1500 gallons of N2 left. 243 bbls of KCL recovered from wellbore. SITP 2587 psi.,Start rigging down CTU 12. Crews off location. Gate closed. Crew will stage equipment at Kena Gas fields. 4/18/2016 PTW and JSA. Spot equipment rig up lubricator. PT to 250 psi low and 3500 psi high. TP - 2416 psi,RIH w/3 -3/8"x24' HC, 6 spf, 60 deg phase and tie into Halliburton CBL log. Got to 9400' and gama ray tool quit working. POOH,Trouble shoot GR tool. RIH w/3 -3/8"x24' HC, 6 spf, 60 deg phase and tie into Halliburton CBL log. Run correlation log and send to town. Get ok to perforate T-140 zone from 10,216' to 10,240'. Spotted shot and fired gun with 2416 psi on tubing. Pressure bobbled a few lbs and then settled back to 2416 psi. POOH and all shots fired. Gun was wet.,Rig down lubricator and equipment for job at gas field tomorrow. Field was going to bleed 500 psi from 2416 psi to 1916 psi. 4/21/2016 PTW and JSA. Spot equipment rig up lubricator. PT to 250 psi low and 3500 psi high. TP - 2416 psi,RIH w/ 3-1/8" GR$/JB,GPT tool and tie into Halliburton CBL log and found fluid level at 9770'. POOH with no problems.,RIH w/5-1/2 CIBP and tie into Halliburton CBL log. Run correlation log and send to town. Get ok to set plug at 10,200'. Set plug, pick up 50' and slack back down and lightly tag plug. Good set. POOH. Had 1900psi on tubing when plug weas set.,RIH w 3-3/8"x20' HC, 6 spf, 60 deg phase and tie into Halliburton CBL log. Send correction log to sound and get it approved. Spot shot from 10.020' to 10.040'w/ 1916 psi. Fired shot and didn't see any psi increase. POOH. All shots fired. and guns were wet.,RIH w 3-3/8"x20' HC, 6 spf, 60 deg phase and tie into Halliburton CBL log. Send correction log to sound and get it approved. Spot shot from 10.000' to 10.020'w/ 1916 psi. Fired shot and didn't see any psi increase. POOH. All shots fired. and guns were wet.TP -1913 psi.,Rig down lubricator and turn well over to field. 4/25/2016 SIMOPS, PTW and JSA. Mobe to location and rig up SLB Pump trk and pollards lubricator. PT SLB lines to 5000 psi and Pollard lub to 250 psi low and 3500 psi high,Pumped 252,000 SCF of N2 with surface pressure of 3700 psi. Decided to run Pollard GPT tool. Went in hole with tool and found fluid level at 8770'. Call town and discussed and decision to put 4200 psi on well.,Pressure tubing tubing up to 4400 psi with N2 (303k scf total). Ran Pollard GPT tool and found FL at 8870'. 100' deeper. Plan is to pressure up to 45-4600 psi and leave it overnight and check if we lost pressure. got up to surface and found leak between the two master valves. Shut bottom master and waited on hammer wrench. Hammered up flange., Pressure back up to 4500 psi and shut well in. Will see how much it pushes water back in formation. Rig for standby. Shut both masters and swab. 4/29/2016 PTW and JSA. PT lines to 5000 psi. Pressure up tubing from 4250 psi to 4600 psi to push the water back into formation.,Rig down line and secure well. 5/2/2016 PTW & JSA. Pressured up well with N2 from 4250 psi to 4600 psi again on sunday and left it on til today. Rigged up lubricator, PT to 250 psi low to 3500 psi.,Open well and had 4500 psi on well. Went in hole with GPT tool and tied into Halliburton CBL log.. Found fluid level at 10,030' and tagged at 10,101. POOH',RIH w/5-1/2" CIBP and tied into Halliburton CBL log. Send log to town and get ok to set plug at 9990'. Spot plug at 9990' and set plug. Lost some line wt. Pulled up hole 50' and went back down and tagged plug. Good set. POOH everything looks good.,RIH w/3-3/8" (3-1/8" charge)x25' HC, 6 spf, 60deg phase and tie into Halliburton CBL.. Run correlati0on log and send to town. Get ok to perf from 9866' to 9891'. Bled pressure from 4500 psi down to 1941 psi. Spotted and fired gun from 9866' to 9891'. pressure went to 1946 psi and after five min went to 1967'. POOH All shots fired.,RIH w/3-3/8" (3-1/8" charge)x25' HC, 6 spf, 60deg phase and tie into Halliburton CBL. Tools set down at 9890' Tried numerous times to get past but could not. It was solid and didn't hang tools up. It was 1' from bottom of first perf run. POOH. Called town and was to;ld to get slickline set up for tomorrow.,Rig down a -line and secure well. Got ahold of Pollard and they will have a crew here at 7 am. 5/3/2016 RU Slickline. PT lubricator to 3,500 psig,Good test.,RIH with DD bailer to 9,869'. Work tool, wouldn't pass. POOH with metal marks on tool.,RIH with 3.5" LIB with centralizer to 9,862'. Hit one time and POOH. Impression of possible CIBP. Discuss with production.,RIH with 2" LIB with centralizer to 9,862'. Hit one time and POOH. Impression of same.,RIH with tri -gauges at 120 fpm to 9,852'. POOH with gauges, download data - good.,RD slickline, secure well for production, sign out, turn in permit. 5/4/2016 PTW and Jsa. Spot and rig up lubricator. PT to 250 psi low and 3500 psi high. Put 4" bailer together.,RIH with 4"x20' bailer filled with cement and tie into Halliburton CBL log. Tagged at 9847'. Get ok from town to dump cement at 9847'. Dumped bailed 10' of 15 PPG cement. TOC is 9837'.,RIH with 5-1/2" plug and tie into Halliburon CBL log. Run correlation log and send to town. Get ok to set plug at 9825. Set plug with 2106 psi on tubing.Plug acted like it set good.. POOH and everything looked ok.,RIH with 4"x30' bailer filled with cement and tie into Halliburton CBL log. Tag plug lightly pick up 10' and dump 12-1/2' cement on top of plug. POOH. Good dump.,RIH with 4"x30' bailer filled with cement and tie into Halliburton CBL log. Stop at 9815' and dump 12-1/2' cement on top of plug. POOH. Good dump. Est TOC at 9800' and cement in place at 1800 hrs.,Rig down lubricator and rig for standby 5/9/2016 Meet at office. Mobe to location. PTW, JSA and spot equipment. Rig up lubricator and arm gun. PT lubricator to 250 psi low and 3500 psi high.,RIH with 3-3/8"x30' HC , 6 spf, 60 deg phase perf gun and tie into Halliburton CBL log. Tagged TOC at 9768'. Run correlation log and send to town. Town said to move correlation log down 4' because it was 4' high to OHL. Adjusted log 4 ft and send back to town.. Get ok to perforate from 9442' to 9472'. Bled well down from 2080 psi to 1909.4 psi. Fired gun and after 5 min pressure was 1912.9 psi. POOH,Rig down lubricator and turn well over to field. Up in lubricator and tubing pressure was 1918 psi. THE STATE Chad Helgeson GOVERNOR BILL WALKER Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Happy Valley Field, Beluga/Tyonek Gas Pool, Happy Valley B-17 Permit to Drill Number: 215-189 Sundry Number: 315-761 Dear Mr. Helgeson: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov 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 DATED this L3day of April, 2016. RBDMS L L ,CD4 1 4 2016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 _IEC 17 2015 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Initial Perforate ❑� Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CT N2 Jetting_ ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑✓ • Stratigraphic ❑ Service ❑ 215-189 • 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, Alaska 99503 50-231-20049-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 553 Will planned perforations require a spacing exception? No x) Happy Valley B-17 - y 9. Property Designation (Lease Number): 10. Field/Pool(s): FEE-CIRI: C061589, C061590, C061588 Happy Valley Field - HV Beluga/ryonek Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,695' 10,118' 10,592' 10,017' 3,877psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' Surface 2,970' 9-5/8" 2,970' 2,846' 5,750 psi 3,090 psi Intermediate Production 10,678' 5-1/2" 10,678' 10,101' 10,640 psi 7,470 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Swell Packer; N/A 1,811' MD/1,766' TVD; N/A 12. Attachments: Proposal Summary Wellbore schematic 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: CommencingOperations: December 31, 2015 p OIL❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS �' WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Nasse - 777-8354 Email Wasse hilcor .com Printed Name Chad Helgeson Title Operations Manager Signature Phone 907-777-8405 Date ( Z COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. , w t -7`-� \ (ail Plug Integrity ❑ BOP Test d Mechanical IntegrityTest ❑ Location Clearance ❑ Other: yt- 1.{S 02, �Af t (�' S ( C, T, Post Initial Injection MIT Req'd? Yes ❑ ; No ❑ Spacing Exception Required? Yes d No ❑ Subsequent Form Required: ! J -- �t'i R13DMS L.` fiOR 1 4 2016 APPROVED BY Approved by: P COMMISSIONER THE COMMISSION Date: i OffiGiNA-aLd Submit Form and Form 10-403 Revised 11/2015 for 12 months from the date of approval. Attachments in Duplicate Hilcorp Alaska, LL - Well Prognosis Well: HVB-17 Date:12/17/2015 Well Name: HVB-17 API Number: 50-231-20049-00 Current Status: New Grassroots Well Leg: N/A Estimated Start Date: Dec. 31St, 2015 Rig: Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-189 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (C) AFE Number: 1512577C Maximum Expected BHP: — 4,307 psi @ 10,017' TVD (Assumed 0.43 psi/ft gradient) Max. Potential Surface Pressure: — 3,305 psi (Based on expected BHP and gas gradient to surface (0.10psi/ft) Brief Well Summary Happy Valley B-17 is a grass roots development well targeting gas sands in the Beluga and Tyonek formations. This new well reached TD on 12/13/15. The purpose of this work/sundry is to run a CBL, jet the well dry with CT, and perforate. Notes Regarding Wellbore Condition • Well will be filled with filtered 6% KCI. • Slickline tag and make gauge ring run prior to starting work. Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Consider tank placement based on wind direction and current weather forecast (venting methane and Nitrogen during this job) • Ensure all crews are aware of stop job authority Usti /4 l r T 4 � s E -Line Procedure 1. MIRU a -line and PT lubricator to 3,500 psi Hi 250 Low. 2. RIH w/ CBL tool and run bond log from PBTD to +/- 1,800'. POOH. Coiled Tubing Procedure: 3. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. Notify AOGCC 24 hrs. in advance of BOP test. 4. RIH w/ 1-3/4" coiled tubing and 2-1/4" jet nozzle BHA to ±10,592' MD and tag PBTD. 5. PU 10ft and displace well fluids with Nitrogen. a. Estimated volume of displaced 6% KCI is 246 bbl. - 6. Leave well with ± 2,500 psi Nitrogen SITP. 7. POOH w/ coil. LD 2-1/4" jet nozzle BHA. 8. RD Coiled Tubing. I ilcorp Alaska, LL E -Line Procedure Well Prognosis Well: HVB-17 Date:12/17/2015 9. MIRU a -line and pressure control equipment. PT lubricator to 250 psi low/3,500 psi high. Note that the well is pressurized with nitrogen. a. If necessary, bleed pressure down as requested by the RE to establish a drawdown on the formation. 10. Perforate the Tyonek sands with 3-3/8" 6 SPF 60 deg phased perf guns. All intervals are planned for 12 SPF so each may be shot twice. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. Proposed Perforated Intervals 11. POOH. 12. Individually flow each zone through test separator and record water and gas rates. 13. If any of the sands are not commercial or wet, the zone will be permanently plugged back. 14. RD a -line. 15. Turn well over to production. 16. Within 5 days of stable production on well, notify AOGCC to witness testing of SSV. Attachments: 1. Actual and Proposed Schematic 2. Coil BOPE Schematic 3. CT Flow Diagrams (Forward and Reverse Jetting) 4. Wellhead Diagram Sands Top (MD) Btm (MD) FT ±9,417 ±9,430 ±13 Tyonek T-100 ±9,442 ±9,478 ±36 Tyonek T-130 ±9,866 ±9,892 ±26 ±9,915 ±10,045 ±130 Tyonek T-140 ±10,216 I ±10,240 ±24 11. POOH. 12. Individually flow each zone through test separator and record water and gas rates. 13. If any of the sands are not commercial or wet, the zone will be permanently plugged back. 14. RD a -line. 15. Turn well over to production. 16. Within 5 days of stable production on well, notify AOGCC to witness testing of SSV. Attachments: 1. Actual and Proposed Schematic 2. Coil BOPE Schematic 3. CT Flow Diagrams (Forward and Reverse Jetting) 4. Wellhead Diagram Deep Creek Unit CURRENT SCHEMATIC Well: Happy Valley B-17 PTD: 215-189 API: 50-231-20049-00 Hilwrp Alaska, LLC RKB = 18' 16" + 1 9-5/8" ' 5-1/2"_� PBTD = ±10,592'/ PBTVD = ±10,017' TD= 10,695'/TVD = 10,118' CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" Conductor — Driven to Set Depth 84 J-55 Weld 15.01" Surf 120' 9-5/8" Surf Csg 40 L-80 BTC 8.835" Surf 2,970' 5-1/2" Prod Csg 17 P-110 GeoConn 4.892" Surf 10,678' LA JEWELRY DETAIL No. Depth ID OD Item 1 1,811' 4.85" 8.835" Baker Swell Packer Updated by TWN 12/16/15 Deep Creek Unit PROPOSED SCHEMATIC Well: Happy Valley B-17 PTD: 215-189 API: 50-231-20049-00 Hilcuxp Alaska, I,LC RKB = 18' 16" 9-5/8" 1 --; T-100 I 1.4 r -13o }} T-140 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" Conductor—Driven to Set Depth 84 1-55 Weld 15.01" Surf 120' 9-5/8" Surf Csg 40 L-80 BTC 8.835" Surf 2,970' 5-1/2" Prod Csg 17 P-110 GeoConn 4.892' Surf 10,678' JEWELRY DETAIL No. Depth ID OD Item 1 1,811' 4.85" 8.835" Baker Swell Packer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Size Status T-100 ±9,417' ±9,430' ±8,889' ±8,902' TBD 3-3/8" Proposed T-100 ±9,442' ±9,478' ±8,913' ±8,948' TBD 3-3/8" Proposed T-130 ±9,866' ±9,892' ±9,320' ±9,345' TBD 3-3/8" Proposed T-140 ±9,915' ±10,045' ±9,367' ±9,491' TBD 3-3/8" Proposed T-140 ±10,216' ±10,240' ±9,654' ±9,677' TBD 3-3/8" Proposed 5-1/2" lit. y,A -60 PBTD = ±10,592'/ PBTVD = ±10,017' TD = 10,695' / TVD = 10,118' Updated by TWN 12/16/15 Open—Top Tank w/ Diffuser s up Annulus) COILED TUBING UNIT N2 JETTING FLOW SCHEMATIC Open—Top Tank w/ Diffuser Coiled Tubing) COILED TUBING UNIT N2 JETTING FLOW SCHEMATIC Happy Valley HV #17 Proposed isl4.14. 12/16/2015 Happy Valley HV #17 16 x95/8x51/2 Tree cap, Otis, 5 1/8 5M FE X 9 % Otis Quick Union Valve, Swab, WKM-M, 5 1/8 5M FE, HWO, DD trim Valve, Wing, WKM-M, 3 1/8 5M FE, HWO, DD trim raj Valve, Upper Master, WKM-M, 5 1/8 SM FE, HWO, DD trim Valve, Master, WKM-M, 5 1/8 SM FE, HWO, EE trim Tubing head, Seaboard -S8, 16 3/4 3M X 11 5M, w/ 2- 2 1/16 5M S50, 9 5/8 P seal bottom Starting head, Seaboard, 16 % 3M X 16" SOW BTM, w/ 2- 2 1/16 5M SSO 16" 9 5/8" 5 %" Tubing hanger, SMB -22 ported, 11 X 5 Y-17# DWC/C csg btm x5.875-4 stub acme LH box top, 5" type H BPV prep, 17-4PH material asaJaLos �y Q 3 ,b Adapter, Seaboard -EN, 115M stdd x 5 1/8 5M top, w/ 7" PP bottom Crossover spool 4 1/16 10M X 5 1/8 5M Valve, Swab, WKM-M, 5 1/8 5M FE, HWO, DD trim Valve, Upper Master WKM-M, 5 1/8 5M, HWO, DD trim Valve, Lower Master, WKM-M, 5 1/8 5M,HWO, EE trim Ninilchik Unit -17 COIL COIL BOPE 12/16/2015 Happy Valley HV #17 16 x95/8x 51/2 Lubricator to injection head Grade Level Mud Cross 4 1/16 10M X 4 1/16 10M Outlet W/ 2- 2 1/16 10M full opening FMC valves Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Monday, December 21, 2015 10:18 AM To: Taylor Nasse (tnasse@hilcorp.com) Cc: Schwartz, Guy L (DOA); Roby, David S (DOA) Subject: Sundry Application for initial perforation of Happy Valley B-17 (PTD #215-189, Sundry No. 315-761) Taylor, I'm reviewing Hilcorp's Sundry Application No. 315-761 for initial perforation of the Happy Valley B-17 well (PTD #215- 189). Could Hilcorp please provide me with an electronic copy of the directional survey data from the Happy Valley B-17 well in either ASCII text file or Excel spreadsheet format? A copy of the digital well log data for B-17 would also be appreciated as I review this application. If any of Hilcorp's planned perforations in the B-17 well fall within the SW % SW % of Section 15, T2S-R13W, a spacing exception will be required. This portion of Section 15 lies outside of the Happy Valley Beluga/Tyonek Gas Pool as defined in Conservation Order No. 553. So, opening of any Beluga/Tyonek sands in the SW % SW of Section 15 will require a spacing exception under statewide spacing rules. The approval letter for Hilcorp's Permit to Drill application for Happy Valley B-17 clearly states: "The permit is approved subject to full compliance with Conservation Order 553 and 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. Hilcorp Alaska, LLC assumes the liability of any protest to the spacing exception that may occur." Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 CONFIDENTIALITYNOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.Qov. Davies, Stephen F (DOA) From: Jeremy Mardambek <jmardambek@hilcorp.com> Sent: Tuesday, December 22, 2015 9:01 AM To: Davies, Stephen F (DOA) Subject: Happy Valley T-140 Structure Map Attachments: HV T-140 Structure Map.pdf Steve, Also see attached for the Happy Valley T-140 structure map post drilling. We ended up in the HVB-17 as the highest well in the field at this depth by 47' from the HVA -03. Let me know if you would like to discuss further. Regards, Jeremy Mardambek Reservoir Engineer Hilcorp Alaska Office - (907) 777-8388 Cell — (561) 512-8690 kt. C7 AC '-7-A'�1:r- Davies, Stephen F (DOA) From: David Buthman <dbuthman@hilcorp.com> Sent: Wednesday, October 28, 2015 9:54 AM To: Davies, Stephen F (DOA) Cc: David Duffy; Jeremy Mardambek Subject: Happy Valley B-17 Hi Steve, Following up on your comments for the permit application for the Happy Valley B-17 well, while it is true that at total depth it will be outside the pool boundary, the deepest targeted reservoir formation is the Tyonek-155, which is identified for the pool as the base of the sandstone at 10,046' MD in the Happy Valley #31-22 exploration well. Below the base of the T-155 sandstone we do not anticipate any reservoirs and concur that it is outside the pool, rather we relegate it to un -prospective rat -hole. Cross section and Pool Defining well—Happy Valley 31-22: SLse* OepCn n) ta44 - hr�a- -00G7- AM - MOO- .spa - -SNO - .3+00 - .95M - ,300 - .W010 - SWO- DEE91 RXU1 KAJ-1 P Y;�3l-7' +va I FIVA102 F'':t-1 .S� •., ,� Pool Identification: The proposed Happy Valley Beluga/Tyonek Gas Pool is an accumulation of hydrocarbons common to, and correlating with, the interval between the measured depths ("MD") of 2,997 feet and 10,046 feet in the Superior Happy Valley #31-22 Exploration Well. If you need anything else, please don't hesitate to contact me or Mr. Duffy. Rgds, Dave David B. Buthman Sr. Geologist 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 (907) 854-4543 (mobile) ra Area of Review Happy Valley B-17 (PTD #215-189) — Proposed Perforations Planned perfs outside of CO 553 Affected Area require spacing exception under statewide rules B-17 HAPPY VALLEY U 31122 T' r A-3 CO 553 Affected A-10 Area Boundary 0 B-16 A.- �� -11 t F -14 A-5 n, B-12 a A-4 A-7XX B-13 KEY B-15��'' =1 Well Path j' Perforations 0 0.5 mi AU(j(( Dec. 22, 2015 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 09, 2016 2:35 PM To: 'Taylor Nasse' Cc: Chad Helgeson Subject: RE: HVB-17 CT Jetting Procedure (PTD 215-189) Taylor, You have verbal approval to move forward with the CT N2 jetting as proposed in your original sundry application and as outlined in your attachment. Perforations must wait until the sundry is approved. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guy.schwartz@alaska.aov). From: Taylor Nasse [mailto:tnasseCaihilcorp.com] Sent: Wednesday, March 09, 2016 2:26 PM To: Schwartz, Guy L (DOA) Cc: Chad Helgeson Subject: HVB-17 CT Jetting Procedure (PTD 215-189) Hi Guy - Chad mentioned he spoke to you about the possibility of getting approval to move forward with CT jetting the HVB-17 well. I've attached the coiled tubing portion of the procedure for your review (this was part of the 10-403 sundry that we submitted on 12/17/15). If we could, we'd like to get approval to begin this work in order to get ahead of the road restrictions that are going into effect starting next week. Let me know if you need any additional information or have any questions. Thanks, Taylor W. Nasse, PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907) 777-8354 office (907) 903-0341 cell Ililcorp Alaska, LL Well Prognosis Well: HVB-17 Date: 03/09/2016 Well Name: HVB-17 API Number: 50-231-20049-00 Current Status: New Grassroots Well Leg: N/A Estimated Start Date: March 10` , 2016 Rig: Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-189 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341(C) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (C) AFE Number: 1512577C Maximum Expected BHP: — 4,307 psi @ 10,017' TVD (Assumed 0.43 psi/ft gradient) Max. Potential Surface Pressure: — 3,305 psi (Based on expected BHP and gas gradient to surface (0.10psi/ft) Brief Well Summary Happy Valley B-17 is a grass roots development well targeting gas sands in the Beluga and Tyonek formations. This new well reached TD on 12/13/15. The purpose of this work/sundry is to jet the well dry with CT. Notes Regarding Wellbore Condition • Well will be filled with filtered 6% KCI. • Slickline tag and make gauge ring run prior to starting work. Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Consider tank placement based on wind direction and current weather forecast (venting methane and Nitrogen during this job) • Ensure all crews are aware of stop job authority Coiled Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. Notify AOGCC 24 hrs. in advance of BOP test. 2. RIH w/ 1-3/4" coiled tubing and 2-1/4" jet nozzle BHA to ±10,592' MD and tag PBTD. 3. PU 10ft and displace well fluids with Nitrogen. a. Estimated volume of displaced 6% KCI is 246 bbl. 4. Leave well with ± 2,500 psi Nitrogen SITP. 5. POOH w/ coil. LD 2-1/4" jet nozzle BHA. 6. RD Coiled Tubing. Attachments: 1. Actual and Proposed Schematic 2. Coil BOPE Schematic 3. CT Flow Diagrams (Forward and Reverse Jetting) 4. Wellhead Diagram Seth Nolan Hilcorp Alaska, LLC 26 883 GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 14 Tele: 907 777-8308 irilciai, �i.�x� ,,. i.t:r Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGEL 3i9 /201fp M.K.BENDEP DATE 03/07/16 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II MAR 0 8 2fli 333 W 7th Ave Ste 100 Anchorage, AK I_\ 0C 99501 CBL prints and digital data Prints: Cement Bond Log CD1: CBL Data ® HVB-17_CBL_30DEC15 1/29/20161:15 PM PDF Dccument 13,035 KB HVB-17_CBL_30DEC15_FREE PIPE 1/29./20161:15 PM LAS File 133 KB HV13-17_CBL_30DEC15_irng 1,29/20161:15 PM TIFF File 41550 KB u HVB-17_CBL_30DEC15 MAIN 1:/29,20161:15 PIA LAS File 13.502 KB HVB-17 CBL 30DEC15 REPEAT 1/29/2016 1:15 PM LAS File 223 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 Received ✓��%� Date: v DATE 01/18/2016 Seth Nolan Hilcorp Alaska, LLC GeoTech II 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 13 boxes: Dry Cuttings Transmitted herewith are cuttings from HVB 17 WELL BOX SAMPLE INTERVAL HVB 17 BOX 1 OF 13 138'- 1200' HVB 17 BOX 2 OF 13 1200' - 2190' HVB 17 BOX 3 OF 13 2190' - 3330' HVB 17 BOX 4 OF 13 3330' - 4350' HVB 17 BOX 5 OF 13 4350'- 5340' HVB 17 BOX 6 OF 13 5340' - 6150' HVB 17 BOX 7 OF 13 6150'- 6850' HVB 17 BOX 8 OF 13 6850' - 7510' HVB 17 BOX 9 OF 13 7510' - 8170' HVB 17 BOX 10 OF 13 8170' - 8830' HVB 17 BOX 11 OF 13 8830' - 9490' HVB 17 BOX 12 OF 13 9490'- 10130' HVB 17 BOX 13 OF 13 10130' - 10695' Please include current contact information if different from above. R I V E D JAN 2 9 2016 1541 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 ,AOGCC DATE 01/18/16 Seth Nolan GeoTech RECEIVED JAN 2 2 Z0 I'� 215189 Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED 2/q 12014 M K.BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 Elog and Mudlog prints and digital data Prints: 2"/5" ROP-DGR-EWR-ALD-CTN MD 2-/5" DGR-EWR-ALD-CTN TVD 5" ALD Borehole Image Dip Interpretation 5" Formation Log MD/TVD 2" Formation Log MD/TVD 2" LWD Combo Log MD/TVD CD1: digital Elog Data 26 6 6 0 CGM Definitive Survey D LIS -1- LAS EMF H'f B-17 ALD Image and Dip Delheerables PDF TIFF CD2: digital Mudlog Data Daily Reports DML Data Final',Vell Report LAS Files Log PDFs Log TIFFS Show Reports 16661 2" Gas Ratio Log MD/TVD 2" Drilling Dynamics Log MD/TVD 2-/5" ROP-DGR-EWR-ALD-CTN MD 2"/5" DGR-EWR-ALD-CTN TVD END OF WELL REPORT 1;'�B/20161:39 P1',fl File folder 1;'8/70161:39 PM File folder 1,,,'8/20161:39 PM File folder 1'8/20161:39Ph,,,l File folder 1/8/20161:32 M1 Filefclder 1.18120161:42 PM Filefolder 1,18/20161:42 PM File folder 1/791201612:57 PM Filefclder 1119/201617:57 PPA Filefclder 11'19,.'201612:57 PM Filefclder 1+'19/201612:57 PM Filefclder 1;'19.,20161757 PM Filefclder 1;'19/20161.7:57 PM File folder 1;`19.1201612:57 PM Filefolder 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG[-] WDSPL ❑ No. of Completions: 0 1b. Well Class: Development Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Aband.: 12/20/2015 14. Permit to Drill Number / Sundry: 215-189 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: November 28, 2015 15. API Number: 50-231-20049-00-00 4a. Location of Well (Governmental Section): Surface: 2947' FSL, 406' FEL, Sec 21, T2S, R13W, SM, AK Top of Productive Interval: To Be Determined Total Depth: 243' FSL, 402' FWL, Sec 15, T2S, R13W, SM, AK 8. Date TD Reached: December 13, 2015 16. Well Name and Number: HV B-17 9. Ref Elevations: KB: 611.5' GL:593.5' BF:593.5' 17. Field / Pool(s): Happy Valley Field HV Beluga/Tyonek Gas Pool 10. Plug Back Depth MD/TVD: 10,544' MD / 9,971' TVD 18. Property Designation: C061589(SHL), C061590, C061588(BHL) 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 223621 y- 2190946 Zone- 4 TPI: x- TBD y- TBD Zone- Total Depth: x- 224493 y- 2194118 Zone- 4 11. Total Depth MD/TVD: 10,695' MD / 10,117' TVD ' 19. Land Use Permit: N/A 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes ❑✓ (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 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 2"/5" ROP-DGR-EWR-ALD-CTN MD, 2"/5" DGR-EWR-ALD-CTN TVD, 5" ALD Borehole Image Dip Interpretation, 5" Formation Log MD/TVD, 2" Formation Log MD/TVD, 2" LWD Combo Log MD/TVD, 2" Gas Ratio Log MD/TVD, 2" Drilling Dynamics Log MD/TVD, 2"/5" ROP-DGR-EWR-ALD-CTN MD, 2"/5" DGR- EWR-ALD-CTN TVD, END OF WELL REPORT 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD HOLE SIZE CEMENTING RECORD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16" 84# X-52 Surface 120' Surface 120' Driven Driven 9-5/8" 40# L-80 Surface 2,970' Surface 2,845' 12-1/4" 305.4 bbls 103 bbls 5-1/2" 17# Pilo Surface 10,631' Surface 10,055' 8-1/2" 490 bbls 0 bbls 24. Open to production or injection? Yes ❑ No Q If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): -110l '3 1 Ste_ %, tv GV 5`` 0 5 e i 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Q Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: N/A Hours Tested: N/A Production for Test Period Oil -Bbl: N/A Gas -MCF: N/A Water -Bbl: N/A Choke Size: N/A Gas -Oil Ratio: N/A Flow Tubing Press. N/A Casing Press: N/A Calculated 24 -Hour Rate _.Jo� Oil -Bbl: N/A Gas -MCF: N/A Water -Bbl: N/A Oil Gravity - API (corr): N/A 2<� Z Form 10-407 Revised 11/2015 `� CONTINUED ON PAGE 2 RBDMS �• `' JAN 5 2016 Submit ORIGINIAL o y 28. CORE DATA Conventional C. (s): Yes ❑ No ❑✓ Sidewall Cores. fes ❑ No ❑✓ If 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 Q If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top N/A N/A Permafrost - Base N/A N/A Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval TBD TBD information, including reports, per 20 AAC 25.071. BLG-29 3,090' 2,957' BLG-36 3,342' 3,192' BLG-45 3,937' 3,750' BLG 120 5,614' 5,319' BLG 135 5,982' 5,664' Tyonek 6,089' 5,763' T8 6,538' 6,183' T25 7,391' 6,980' T80 8,946' 8,437' T100 9,422' 8,894' T140 9,957' 9,407' T150 10,377' 9,809' T155 10,434' 9,864' Formation at total depth: 1Tyonek 31. List of Attachments: Wellbore Schematic, Daily Drilling and Completion Composite Reports, Definitive Directional Surveys, Casing and Cement Reports, Days vs Depth, MW vs Depth 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. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Monty Myers Email: mm erS hllcor .com Printed Name: Monty Myers Title: Drilling Engineer Signature: Phone: 777-8431 Date: 1 Z O 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 1 a: 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, Ground Level, and Base Flange 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 11/2015 Submit ORIGINAL Only 16' 9-5/I RA Mkr 3,933' RA Mkr 4.635' RA Mkr 6,205' RA Mkr. 9,407' 5-11 Deep Creek Unit CUr%RENT SCHEMATIC Well: Happy Valley B-17 PTD: 215-189 API: 50-231-20049-00 Hilcorp Alaska, LLC. RKB = 18' PBTD = 10,544'/ PBTVD = 9,971' TD = 10,695'/ TVD = 10,117' CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" Conductor — Driven to Set Depth 84 X-52 Weld 15.00" Surf 120' 9-5/8" Surf Csg 40 L-80 BTC 8.835" Surf 2,970' 5-1/2" Prod Csg 17 P-110 GeoConn 4.892" Surf 10,631' JEWELRY DETAIL No. Depth ID OD Item 1 2,025' 4.85" 8.835" Baker Swell Packer Updated by CJD 1/13/16 nHilcorp Energy Company Composite Report Well Name: DCU HVB-17 Field: Happy Valley County/State: , AK i (LAT/LONG): ;vation (RKB): 18 API #: 50-231-20049-00 Spud Date: 11/28/2015 Job Name: 1512577D HVB-17 DRILLING Contractor AFE #: 1512577D AFE $: Activity Date Ops Summary 11/24/2015 Lay derrick over and prep for removal. Spot cranes and pick derrick off carrier, pick carrier off sub, lower doghouse and move water tank, pick sub off pony walls. Load mats and pony walls,; transport derrick, carrier, sub, pony walls and cranes to Ninilchik. Cont pick up mat boards from around CLU -05, clean up liner and felt. Rig crew traveled to Ninilchik to prep for rig assembly. ;RU at Happy Valley. Set felt liner and mats. Set pony subs, Sub, Drwks skid, Derrick, Water tank doghouse, and Comb building. Put windwalls up on board. Lower walkways on combo building and water tank;Set iron roughneck. Put up light stands, windsock, and flag poles. String hoses & electric lines from combo building to sub. Start drwks motor and raise doghouse. Lower doghouse landings. Start main can set and get lights on. Prep derrick for raising. Rig is 90 % moved and 20% rigged up. 11/25/2015 Cont prep derrick for raising, spot pit modules 1 and 2, spot mud pump skids, spot boiler skids, install derrick board shack with crane, spot pit module 3, install windwalls on pits, set centrifuge,roof top, spot service shacks, raise derrick, Total Safety RU gas detection equipment, install Handy Berm around rig foot print, level sub base, spot catwalk. Prepped office trailers for move off,CLU pad. Transport assorted rig equipment from CLU pad.;Cont RU gas detection equipment, cont install Handy Berm, receive office trailers and spot same. Power up office trailers and change shack. Put up windwalls around rig floor.;RU mud pump lines and mud pits. Put tarps on drk raising rams. Prep to scope up derrick. Got derrick up with lights on at 0300 hrs. Start filling water tank at 23:30 hrs. Secure To drive rail to derrick and prep to PU To drive. Rig is 80 % rigged up and 98% moved. 11/26/2015 Cont RU torque tube in derrick, fill rig water tanks from water well on pad, PU and RU topdrive, install Kelly hose and service loop. Install shaker screens and load pits 1-2-3 with rain water;from pad (offload vac truck over shakers). Halliburton Rep inspected and serviced centrifuge. Powered up service shacks. RU steam lines and get steam running throughout rig. Cont to organize location,;stage diverter equipment. Function test topdrive, replace valves in mud pump #2, install saver sub. Install DSA and diverter "T" on well head. Sent diverter test notification to AOGCC.;Cont NU diverter system, Nipple up 21 1/4" bag. Install knife valve put together diverter line. Had truck go get one assorted load off CL pad. Brought Atigun tank to B pad and filled from water well.;Built docks for the pallets of mud products.; Continue nippling up diverter system. Started hauling mud from A pad to B pad. Finish bolting together diverter line and install clamps on anchors. RU flow line, trip tank line , and bleed llne.,RU accumulator hoses to bag and knife valve. Install two 4" valves on the conductor and cap the angled 4" for a top job. PU jt of DP and function test bag and knife valve. Mix spud mud. Ri is 99% rigged up and 99% moved off CL pad. 1 112 7/2 01 5 Started mixing spud mud, installed tarps on sub -base, received two truckloads drilling tools, reset catwalk alignment, C/O diverter tube elbow, C/O equalizer tube between pits, offloaded 6% KCL mud in;pits 4-5-6 (from G&I), strung new electric cord in MCC for test pump outlet, replaced valve on equalizer between boilers, function tested rig pumps and ESD's. Cont working on rig accept checklist.;AOGCC Rep Bob Noble on location at noon and signed in at Pushers shack. Inspected diverter/bag in cellar, measured vent line and nearest ignition source. Function tested diverter with 4 112",joint DP and 870 psi on annular. Knife valve open time = 12 seconds, annular closure time = 43 seconds. Total Safety calibrated all sensors and verified proper operation of gas detection equipment.; Performed drawdown test, functioned TPV and flow show alarms. Had no failures.;Welder cont misc. projects, racked and tallied HWDP, cont checking off rig acceptance checklist, pressure test Kelly hose connections, installed wear ring, function tested rig pumps and ESD's.;Remove gun line charge pump for packing replacement, cont offload 6% KCL mud into pit's 4-5-6, cont move mud products from "A" pad to "B" pad. Pull top off #2 mud pump pulsation dampener;& remove bladder. Clean up and prep to install new rubber. Put new seals in centrifugal and put pump back in. PU HWDP and stand back in the derrick. Continue PU DP.;Didn't have the right bladder for the pulsation dampener at the rig. Sent tour pusher in to warehouse for parts. Finish weighting up spud mud and picking up DP and racking back DP.; Working on getting new bladder for K-10 or changing it out to a K-20 pulsation dampener. Rig Accepted @ 06:00 11-28-15. 11128/2015 Cont to PU rack back a total of 100 jnts 4 1/2" DP, jars, 8" NMDC's and 6 3/4" NMDC's. Tool Pusher on location with new pulsation dampener and installing same.;PU 8" Sperry motor with 1.5 degree bend, MU 12 1/4" HDBS milltooth bitjetted with 3x16's and 1x14, motor bend at 1.5 deg, MU 12 1/8" stab, 8" NMDC, XO's and 1 stnd HWDP.;Ease down and tag bottom at 128' RKB. PU 10' and flood conductor. Inspected cellar, stack and vent line. Had no Ieaks.;Held pre -spud meeting with rig team covering muster areas, wiper trips, cuttings handling, water use.;Spud well at 12:30, WOB 5 to 7K, 456 gpm-665 psi, 45 rpm -4900 ft/lbs on bott torque, MW 9.3 ppgtvis 300. 5 to 100 ft/hr ROP. Drilled from 128' to 221'.;Circ hole clean, pulled up hole from 221' to 43', up wt 22K No issues.;lnstall short mousehole, PU DM collar, HWRGB collar and ALD collar, scribe same. RFO = 183.74 degrees. MU CTN and TM collars, MU XO's and pump through tools to warm up. Download MWD.; Install RA sources. MU 1 std of 8" flex collars and 1 std of HWDP.; Wash to bottom. PU and take a survey. Drill 12 1/4 hole f/ 221' U 493'. Survey every connection. Running 472 GPM, 1210 Psi, 50 RPM, 6,200 Tq, 18k WOB, MW 9.3+, ECD 9.7;POH to 8" flex collar. Run two 6" flex collars, 3 stds of HWDP, and jars with sng of HWDP on top. Centrifuge packed off when we kicked it on so we got a service hand headed this way. Drill 12 1/4" hole U 493 0749'. Up wt 42, Din wt 44, Rt wt 43, GPM 500, Psi 1400, 70 RPM. 8,100 Tq.,Class II hauled to G&1=56 BELS Total Class II hauled=140 BBLS Cuttings hauled to G&1=64 BBLS Total Cuttings hauled= 64 BBLS;Distance to plan 1.01' .82 High &.59 Right Sliding hrs= .28 Rotating hrs=5.50 11/29/2015 Cont directional drilling 121/." hole from 749' to 1497'. Rotating wob 10 to 15K, 554 gpm-1811 psi, 70 rpm -7000 ft/lbs on bott torque, 50 to 150 ft/hr ROP. Sliding wob 16K, 554 gpm-1825 psi, 156 psi;diff, 21 ft/hr ROP. MW 9.3 ppg/vis 121, ECD's at 9.93 ppg, BGG 0 units. Drifted and strapped 80 jnts 9 5/8" casing, received 646 sx lead cement in silo.,CBU at 504 gpm-1371 psi, 70 rpm - 5000 ft/lbs off bott torque. Up wt 60K, dwn wt 58K, rot wt 58K. Obtain survey. Flow check (static).,Pull up hole from 1497' to 469' with no issues. Disp was 1.2 bbls over. TIH from 469', Had 10' of fill. Washed to bottom to clean out fill. Disp was 2.2 bbls under on trip in the hole.; Directional drill 12 1/4" hole f/ 1497't/ 1825'. 556 GPM, 1875 Psi, 20k WOB, 70 RPM, 7100 Tq, MW 9.4, ECD 9.8.; Directional drill 12 1/4" hole f/ 1825't/2244'. 554 GPM, 2095 Psi, 25k WOB, 80 RPM, 8500 Tq, 9.4 MW, 9.8 ECD.;Circ bottoms up. Take survey. Blow do TD. Start to short trip f/2244' 02026 with no issues.,Class II hauled to G&1=185 BBLS Total Class II hauled=325 BBLS Cuttings hauled to G&1=257 BBLS Total Cuttings hauled= 321 BBLS;Distance to plan 2.55' 2.49 Low &.56 Right Sliding hrs= 2.57 Rotating hrs= 11.59 11/30/2015 Cont pulling wiper trip from 2026' to 1454' with no problems. TIH from 1454' to 2212', fill pipe and ease down tagging fill 9' off bottom. Wash stand down to 2244' and make connection.;Cont drilling 12 '/." hole from 2244' to 2746'. Rotating wob 26K, 554 gpm-2101 psi, 80 rpm -8700 ft/lbs on bott torque, 34 to 100 ft/hr ROP, MW 9.3 ppg/vis 121, ECD's at 9.67 ppg, BGG 41 units.;Cont drilling 121/." hole from 2746' U 2877'. Couldn't get broke out of TD.;Had to remove saver sub clamp and break saver sub out of TD. Then we broke the savers sub out of the pipe with the iron roughneck. Stood one std back. MU new saver sub on TD.,Screwed into pipe and cir while we installed the clamp on the saver sub. PU std and wash to bottom.;Directional drill 12 1/4 hole f/ 2877', U 2980'. 572 GPM, 2070 Psi, 85 RPM, 9000 Tq, WOB 26, MW 9.3+, ECD 9.7, 42 to 98 ROP. BGG 8 units.;Circ hole clean and get survey.;Short trip f/ 2980' t/1756' and encountered a tight spot. Also tight at 2805, 2513, 2502, 2496, 2124, & 2025,Attempted to work through tight spot at 1756on elevators and ended up getting hung up. MU TD and had full circ. Attempted to jar down with no luck. Tried putting torque in pipe and working;it down to free pipe but still had no pipe movement. Couldn't get a good lick jarring down so finally ended up jarring with 45k over twice and it came free.;Continue POH and encountered tight spots at 1720, 1525, 1450, 1392, & 1358. with 15 to 20k overpull. Called town and decision was made to POH and LD smart iron. POH to 480'.;Class II hauled to G&1=252 BBLS Total Class II hauled=577 BBLS Cuttings hauled to G&1=288 BBLS Total Cuttings hauled= 609 BBLS;Distance to plan 4.18' 4.13 High &.62 Right Sliding hrs= .34 Rotatin hrs=13.09 12/1/2015 Cont to pull up hole from 480' to 189', PJSM and removed RA sources, pulled up hole to 145', plugged in and uploaded MWD data. LD smart tools, cleaned stabilizer, motor and bit.;Graded the bit at 3 -3 -CT -A -E -1 -BU -TD. Cleaned rig floor.;TIH with cleanout assembly: re -run 12 1/4" HDBS milltooth, re -run 8" motor, re -run 12.125' stab, 8" flex DC's, 6 %" flex DC's HWDP and jars. TIH on elevators with no problem to 2343', (no issues at the previous tight spot 1750'). At 2343' string took 20K, tried twice to work through on elevators. MU topdrive and washed down to 2383' with no problem. PU, stopped rotary and pump, SO;and hole was clean. Cont TIH on elevators from 2383' to bottom with no problems and no fill.;Circulate nut plug sweep around at 607 gpm-1784 psi, 80 rpm -7300 ft/lbs torque, BGG 33 units. Hole pretty much unloading clay balls entire circ. 75% increase in cuttings/clay with sweep to surface.;Built and pumped a second nut plug sweep around at same parameters although torque reduced from 7300 to 6500 ft/lbs at 80 rpm. No increase in cuttings. Blew down topdrive, flow check static.;POOH on elevators from 2980' to BHA with no hole issues. Up wt75K coming off bottom. Racked back 8" and 6 3/4" flex DC's, LD XO"s, stabilizer, motor and bit. SLB loggers on location at 19:00 hrs.,Had moderate amount of clay balled up on top side of stabilizer and bit from trip out (est 20 gallons). Clean same. Flush and drain mtr. Bit grade = In: 3 -3 -CT -A -E -1 -BU -TD Out: 3-3-CT-A-E-1-WT-TD,Clean and clear rig floor. Prep for logging operations..R/U SLB loggers. M/U 3 5/8" RFT tool string (31' length) on .46" wire. 8k rope socket disconnect. Set a 5 min max for test intervals due to potential sticking issues.;31 attempts 110 good/ 13 -timed out/ 8 tight. Pullout of hole and R/D SLB. Rig service. Grease drawworks, top drive, blocks and crown. ;Makeup cleanout assy BHA. Same cleanout assy as Sperry run #200. Bit grade in - 3 -3 -CT -A -E -1 -WT 12/2/2015 Cont MU cleanout BHA, TIH from 107' to 2980' with no issues and no fill.;Swept hole clean with hi -vis nutplug sweep, had very little increase in clay or cuttings to surface. Pumped at 587 gpm- 1602 psi, 80 rpm -6300 ft/lbs torque.;POOH from 2980' to 202'. Up wt 78K. Had no issues tripping in open hole. Halliburton Rep on location servicing centrifuge (hydraulic hose swap, troubleshoot startup issue).;At 202', LD 8" flex DC's, stabilizer, motor and bit. Bit graded at 3-3 (went in at a 3-3). Weatherford casing Rep on location at 15:00 hrs.;Clean and clear rig floor, drain stack and cleanout cellar box, RU and remove wear ring.,RU Weatherford casing equipment, fill up line, stage centralizers, and stage casing on racks.,PJSM, Make up 9 5/8" shoe track w/ Bakerlok (Inspect and flashlight float equipment) . Check floats individually (good). Run 9 5/8" BTC, L-80, 40# casing to 1450' MD.,Install straight blade centralizers as per detail. Centralizer O.D = 12.00".;Circulate and condition mud @ 1450' MD. Stage pumps up to 294 gpm, 139 psi, 35% flow. 52k up, 50k dn. Circulated 1 1/4 casing capacity. 'Continue running 9 5/8" casing from 1450' to 2944' MD with no issues. MU circ swedge.;Circ casing at 297 gpm-230 psi. R/D Weatherford casing equipment. C/O to long bails. SLB cementers staging trucks and equipment. Circulated a total of 6969 stks (486 bbls).,P/U and M/U hanger w/ landing jt. Had to dress threads on pup jnt. S/O 90k, 120k up. Landed out on depth as per wellhead hand (James Craycroft - Northern Oil Solutions) w/ 78k string wt.;State notification sent via email for upcoming BOP test.;Hauled 63 bbis cutting to KGF G&I for total of = 717 bbls Hauled 207 bbls class II junk fluid to KGF G&I for total = 989 bbis Hauled 0 bbis cement to KGF G&I for total = 0 bbis 12/3/2015 MU plug launcher and cont circ 9 5/8" casing at 5 bpm while RU SLB cementers manifold and hardline. Reciprocate string at 11 OK up, 95K down with no issues.;Held PJSM with rig team and SLB cement crew.;MU plug launcher and hardline, SLB loaded lines with 2 bbis water and checked for leaks. SLB pressure tested lines at 1200 low 2800 high, good tests. Rig pumped 40.2 bbls 10ppg MudPush II at 5.5 bpm;and shut down. SLB dropped bottom plug and pumped 254.7 bbls (618 sx) 12ppg Class A lead cement at 4.5 bpm followed by 50.7 bbis (253 sx) 15.4ppg Class A tail / cement at 2 bpm. SLB dropped top plug,,SLB displaced with 222 bbis 9.4 ppg Spud Mud at 4 bpm, slowing to 2 bpm with 10 bbl to go. Bumped plug and held 1720 psi (FCP of 1200 psi) for 3 l minutes, bled off and floats did not hold (bled back Rbb1s). _Pumped 9 bbls and re -bumped plug holding for 5 minutes and bled back 2.5 bbis, floats not holding. Shut in at plug launcher with 1000 4k psi on casing. Had 40.2 bbis MudPush 11 returns to surface:and 103 bbis 12.0ppg lead cement to surface. Took all cement returns to cellar box. Mix water temp 85 deg. Pumped 75% excess on both lead and tail. Had full returns throughout the job.; Reciprocated string 2 x per minute throughout the job. Up wt 110K, dwn wt 70K at time of landing hanger. RD and released Schlumberger. CIP at 12:35 hrs, 12-3-15. RU psi gauge on plug launcher and,and monitor pressure while RD SLB and cleanup of cellar.;Fiush diverter with black water from pill pit, flush SLB hardline into cellar �i box and blow down, thoroughly clean cellar box of all cement, nipple down diverter vent line, MU choke hose to calwalk,while waiting on cement to set up. 50 psi on plug launcher gauge with no build after 1 hour. Bled off to 0 psi and monitor 1 hour with very little flow (size of a pencil lead).;Cont ND diverter vent line and knife valve, update AOGCC Rep Jeff Jones for BOP lest, update Total Safety for BOP test. Function and flush diverter stack. N/D flow line, bleeder line & koomey lines;4 bolt flanges on stack and clean cellar area.;Remove drop plug cement head and xo swedge. Flush and laydown same.;Remove landing jt and dress w/ packoff running tool. Install packoff. Continue N/D bell nipple, annular, knife valve, diverter "T' and DSA. Install flange covers.;Stage and N/U wellhead. Test wellhead void 300 psi low / 3000 psi high. Stage BOP stack and spacer spool in cellar via crane. Clean area and prep for nipple up. Set and raise gas buster.; Hauled 223 bbis cuttings to KGF G&I for total = 940 bbis Hauled 265 bbls class II junk fluid to KGF G&I for total = 1254 bbis Hauled 103 bbls cement to KGF G&I for total = 103 bbls 12/4/2015 Install 2' spacer spool on wellhead, install 16" spacer spool. Pull studs from bottom of single gate in order to clear top of spacer spools. MU BOP stack, install kill line on mezzanine level, install,kill HCR, inside choke and choke HCR, torque BOP bolts, install drip pan, flow riser and flow line, secure stack with 4 way chains, MU choke shock hose from catwalk, RU 2" bleeder line to flow line,; install koomey lines. Cont transporting spud mud to G&I, vac trucks pulling 6% KCL mud from frac tank at Cannery Loop and offloading in to pits. Centrifuge 11.3 ppg mud back to 9.3 ppg.;Clean up cellar area, install whip checks, PU test jnt, lay down Weatherford elevators and lay down long bails. Total Safety on location at 18:00 hrs calibrating gas detection equipment, AOGCC Rep;Jeff Jones on location at 18:30 to witness BOP test. Test gas detectors 10/20 H2S, 20/40 LEL. Bump test all. Flood stack. Shell test.; Test BOPE 250/4500 (2500 annular) -1) Upr pipe, CM #1,#3,#4,#5,#7, Mez kill, dart, hyd IBOP. 2) Upr pipe, CM #2,#4,#5,#6,#8,kill hcr,TIW,Lwr IBOP. 3) Upr pipe, Inside kill,dart,CM #7,#9,#11,#13;4) Upr pipe, inside kill,choke hcr,TIW. 5) Upr pipe,TlW,inside kill,inside choke. 6) Annular,TIW,inside kill,inside choke. 7) Lwr pipe,TIW. 8) Blind rams,CM #7#10,#12, inside kill.;9) Elect choke. 10) Manual choke,CM #10. Drawdown - 3100 start psi. 1500 drawdown psi. 21 sec annular closure psi. 20 sec for 200 psi increase. 93 sec for full charge. 2675psi 4 bottle avg.;lssues noted during test - Leaking flange her kill and manual kill (tighten, retest good), Hydraulic leak HCR kill (tighten fitting -good), Relocate and Recalibrate sensor 5 due to temp fault(good).,R/D test equipment. Blow down choke, kill line and test equipment. Lineup choke for drilling operations. Set 10" ID wear bushing (RILDS). R/U short bails and 4 1/2" dp elevators.;M/U johnny whacker, std flex DC, xo and prep to single in. Drift dp w/ 12/5/2015 PU single in hole 90 jnts of 4 1/2" DP. Tagged upon hard cement/wiper plug at 2842' (42' high, float shoe is at 2884'. This coincides with the 2.5 bbis bled off during cement job).;Turn elevators, POOH racking back in derrick, to the flex DC's.;Tally up another 64 joints 4 1/2" DP, turn elevators for PU singles.; PU single in hole 64 joints 4 1/2" DP. ;Turn elevators, POOH racking back in derrick, to the flex DC's. Break off stack wash tool and rack back flex DC's.;PJSM, M/U 8.5" production BHA. Varel V513GH (.76 TFA)(14K tq), 7"7/8 lobe-6slg mtr w/ 1.5' bend. MWD tools to TM. RFO = 126.66° (360/ 702 x 247),Circulate and warm up tools. Download. Shallow pulse test (good). PJSM, load sources. Blow down top drive. TIH w/ remaining BHA out of derrick (BHA length= 790.83');Single in picking up 4.5", 16.6# S-135 (NEW) drill pipe F/790' -TI 2630'. Drift 2.56" while picking up. Make and Break new connections.;Hauled 99 bbis cuttings to KGF G&I for total = 1191 bbis Hauled 81 bbis class 11 junk fluid to KGF G&I for total = 1947 bbis Hauled 0 bbis cement to KGF G&I for total = 103 bbis 12/6/2015 Cont to PU single in hole with new 4 1/2" DP, from 2630' to 2812'. Made up, broke out and make up new connections.;At 2812' MU topdrive, filled pipe then CBU one time to clear air from circ lines and casing. 264 gpm-914psi.;Shut down pump, blew down topdrive, RU test equipment, circulated through kill line and test hose. Closed upper rams, pumped 41 strokes to achieve 3300 psi and held 30 min on chart. ood test. RD.,Cut and slipped 90' drill line, calibrate block height, check crown saver.;MU topdrive, SO washing down and engage good hard cement at 2850'. Drill cement and shoe track from 2850' to 2970', wob 5K, 355 gpm-1139 psi, 30 rpm -6900 f albs torque.;At 2970' displace well to 6% KCL mud, cont drilling 10' rat hole cement to 2980' then 20' new formation from 2980' to 3000'. CBU one time and pull up park string inside casing. Blow down topdrive.; RU test equipment, pumped through kill line and test hose to purge air, pumped 17.5 gallons to achieve 414 psi. (399 psi w/9.3 MW = EMW 12.0 ppg at 2845' tvd) PSI bled back to 315 psi over 10 min;and held steady for an EMW of 11.43 ppg. Bled back 10 gallons. Notified Drilling Engineer. RD test equipment and made connection.; Resumed drilling 8 1/2" hole from 3000' to 3201', rotating wob 6 to 8K, 479 gpm-1288 psi, 30 rpm 6500 ft/lbs on bolt torque, 30 to 120 ft/hr ROP, MW 9.3 ppg/vis 42, BGG 22 units. Increased rpm a1;3121', from 30 to 65 rpm -7600 ft/lbs torque once smart tools cleared casing shoe.;Cont drilling 81 /2" hole from 3201' to 3613' MD. 515 �` gpm, 1670 spp, 140 diff psi, 45% flow, 70 rpm, 7.5k tq on, 6.3k tq off, 40 bgg, 8k wob, 86k rot, 92k up, 82k dn. Max gas 457 units;Cont drilling 8 1/2" hole from 3613' to 3997' MD. 503 gpm, 1750 spp, 228 diff psi, 45% flow, 70 rpm, 8.2k tq on, 6.7k tq off, 40 bgg, 8k wob, 86k rot, 92k up, 82k dn;Circulate btm's up @ 3997' MD. 500 gpm, 1515 spp, 45% flow, 75 rpm, 6.6k tq, Max gas @ btms up 405 units.;Monitor well (static). Start wiper trip out of hole F/ 3997' - T/ 3418' MD. 92k up, 85k dn. Hole took proper displacement thus far.;Hauled 97 bbis cutting to KGF G&I for total = 1288 bbls Hauled 318 bbis class 11 junk fluid to KGF G&I for total = 2265 bbis Hauled 0 bbis cement to KGF G&I for total = 103 bbis Last survey 3962' MD / 3773' TVD = 1.5' high and 2' left / 2' ctr to Or 1217/2015 Cont pulling wiper trip from 3797' (up wt 92K) to 3234' on elevators. Worked through tight spots at 3300' and 3285'. At 3234' could not clean up on elevators. MU topdrive.;Backream from 3234' to surface casing shoe at 2970'. 359 gpm-930 psi, 40 rpm -6400 ft/lbs torque. This section is all claystone and sand., Inside casing blew down topdrive. C/O grabber dies and saver sub. Greased blocks, topdrive and drawworks.;TIH from 2967' to 3937', on elevators with no issues. MU topdrive and wash last stand to bottom at 3997'. Down wt 75K. Received 1 19joints 51/2" casing and 6 pup joints.;Cont drilling 8 1/2" hole from 3997' to 4571', rot wob 9K, 500 gpm-1879 psi, 75 rpm -8600 fVibs on bott torque, 80 to 180 ft/hr ROP, MW 9.3 ppglvis 60, ECO's 10.0 ppg, BGG 46 units. Drilling clay/sand;Cont drilling 81/2" hole from 4571' to 4992', 500 gpm, 1985 spp, 275 diff, 75 rpm, 8.6k tq on, 6.2k tq off, MW 9.3 ppg/vis 60, ECD's 10.0 ppg, BGG 31 units. 115k up, 92k dn, 102k rot.;Circulate and condition mud @ 4992' MD. 500 gpm, 1720 spp, 45% flow, 50 rpm, 7600 lq, 31 units BGG.;Blowdown TDS, Monitor well (static). Pull out of hole F/ 4992' - T/ 2944' MD. Pulled clean for the first 400 It then saw 10-60k overpull for remaining trip to last trip depth @ 3997' MD.;Overpull decreased past last hip depth (3997') to 5.20k consistently to 9 5/8" shoe @ 2970' MD. Most significant overpull were 75k @ 4085', 80k @ 4002', 75k @ 3894'.;Hole wiped clean in all tight spots w/ no sticking issues slacking off while working through tight spots. 4.75 bbl loss for trip out.;Cleaned rig floor from wet trip. Svc rig and cleaned sensors for RPM and depth tracking. Calibrate block height and depth tracker. Trip in hole F/ 2944' - T/ 4931' MD. Wash do last std to 4992' MD14.75 bbl loss for trip in. Cont drilling 8 1/2" hole from 4992' to 5056', 500 gpm, 2055 spp, 238 diff, 75 rpm, 9.4k tq on, 7.2k tq off, MW 9.3 ppg/vis 48, ECD's 10.0 ppg, 115k up, 92k dn, 102k rot.;Max gas @ btms up after trip 548 units.; Hauled 198 bbis cuttings to KGF G&I for total = 1486 bbis Hauled 162 bbis class 11 junk fluid to KGF G&I for total = 2427 bbis Hauled 0 bbis cement to KGF G&I for total = 103 bbls;Last svy @ 5019' MD, 21.3' Inc, 11.51 Az. Slow, 3' left. 6' ctr / ctr to plan. 12/8/2015 Cont drilling 81/2" hole from 5056' to 5490' up/dn/rot 120/98/108k TO @ 9-10k w/ SPP @ 2047psi @ 500 gpm w/ 11-14k wob.;Cont drilling 8 1/2" hole from 5490' to 5801' up/dn/rot 128/100/112k TO @ 9-10k w/ SPP @ 1878 psi @ 500 gpm w/ 11-14k wob.;Circ clean pump up survey Pull one std flow chk (ok) & blow do TDS and Iines.;Short trip f/ 5801' U 5315' (ok) had numerous tight spots f/ 5315' U 4123' w/ brake backs @ 40-50k over and work through all on elevators. pull clean f/ 412T U 3898'. 2.6 bbl loss for trip.;TIH on elevators F/ 3898' - T/ 5790' MD with no issues. Tagged upon 10' fill. Washed down F/5790'- T/ 5801' MD. Proper displacement for trip in.;Cont drilling 8 1/2" hole from 5801' to 6065' up/dn/rot 132/l02/l l2k TQ @ 10-12k w/ SPP @ 2090 psi @ 501 gpm, 45 % flow, w/ l l-14k wob. ECD's 10.01, 1031 units gas @ btm's up.;Cont drilling 8 1/2" hole from 6065' to 6545' up/dn/rot 135/l02/115k TQ @ 10-12k w/ SPP @ 2040 psi @ 500 gpm, 44 % flow, w/ 11-14k wob. ECD's 10.11, 160 units bgg.;15 bph seepage to hole while drilling starting +/- 6400' MD. Increase bg Ian from 7 ppb to 10 ppb. Maintain .5% lube to minimize stick slip.; Hauled 161 bbls cuttings to KGF G&I for total= 1647 bbls Hauled 364 bbls class II junk fluid to KGF G&I for total = 2791 bbls Hauled 0 bbls cement to KGF G&I for total = 103 bbls�6323' MD / 5982' TVD 21.0° Inc 9.93° Az = V high, 4.3' right 7.3' ctr to ctr). 12/9/2015 Continue drig 8-1/2" dir hole f/ 6545' t/ 6606'.;Pump 20 bbl high vis sweep around and circ clean back on time w/ 50% increase in cuttings and fist sized coal pieces and coal caving's. Flow chk w/ just slight seepage Iosses.,Blow do TDS & lines. Short trip pooh f/ 6606' U 5046' first +- 500' good, Tight spots w/ brk backs 50-60 over @ 5627-5607', 5305' 5237, & 5225' & Clean pull f/ 5225' U 5046' w/ 3.52 bbls over cal.; Flow chk slight seepage short trip rih w/ no hole problems and proper hole displacement U set do @ 6527' (coal) unable to pass, kelly up. ;Wash and ream f/ 6527' t/ 6606'.;Resume drig 8-1/2" dir hole f/ 6606' w/ 883 units trip gas U 7412'. Increase lubet/ 1.0% do too stick slip. Pump 20 bbl hi vis sweep @ 7102'w/50% inc in cuttings.;Circulate hole clean rot and reciprocating pipe @ 7412' MD. 505 gpm, 1980 spp, 44% flow, 55 rpm, 9.4k tq, 60 units bgg, 9.8 ECD.,Pump 20 bbl hi vis sweep @ 7412' w/ 30% inc in cuttings. Sweep came back on time.;Pull 1 std. Monitor well (slight seepage). B/D TDS. 160k up, 125k dn. Pull out of hole F/ 7412'- T/ 7073' (clean), Pull F/ 7073'- T/ 6266' working through numerous tight spots w/ 20k-60k over. Pull F/ 6266' - T/ 5801' (clean). 2.5 bbl loss over calculated displacement for trip out..; Service rig. Grease crown, drawworks, top drive. Tighten bolts on drawworks driveline.;TIH on elevators F/ 5801' - T/ 7333' MD. Worked past obstruction @ 7060' MD w/ little effort. Unable to work past 7333' MD. 2 bbl loss for trip in.;Wash and Ream F/ 7333' - T/ 7412' MD.;Resume drig 1/2" dir hole f/ 7412'w/ 842 units trip gas U 7533'. 472 gpm, 1950 spp, 85 diff, 43% flow, 52 rpm, 9.3k tq off, Ilk tq on, 70 units bgg, 9.90 ECD's. Saw 842 btms up gas. 1211012015 Continue drig 8-1/2" dir hole f/ 7533' U 7908' up/dn/rot = 1681124/140k @ 475 gpm, 2256 spp, 50 rpm @ 11-12k tq and 15k wob.;Pump around 20 bbls high vis sweep while drilling @ 7800' on time w/ 60% increase.;Continue drig 8-1/2" dir hole f/7908' t/8034' (had troubles brking out TDS last two conn).; Pull rack back std Chg/out saver sub., Continue drig 8-1/2" dir hole f/ 8034' U 8221'.,Circ hole clean @ 8221' (Rot & Recip pipe). 500 gpm, 2240 psi, 44% flow, 55 rpm, 9.7k tq, 119 bgg, 9.92 ECD's. 174k up, 128k do (pumps on). Pump 20 bbl hi vis sweep (60% inc, on time).;Attempt to std back 1 std but unable to break out of saver sub and std connection. R/U headpin and C/O saver sub. Inspect save sub and found threads to be slightly gaulled. Reason (inconclusive).; Monitor well (static). 180k up, 130k do (pumps off). Trip out of hole on elevators F/ 8221'- T/ 7162' (clean).,Overpull 20-60k @ 7162' - T/ 7155' MD. Unable to work past. Backream F/ 7156- T/ 7103' through numerous laminated coal seams as per log. Trip through clean post backream.;Continue pulling out on elevators F/ 7103' - T/6772' (clean). 20-60k overpull w/ break backs F/ 6772' - T/ 6749' MD. Pulled clean F/6749'- T/ 6545' MD. 3.8 bbl loss for trip out.;Grease top drive, drawworks, Iron roughneck, Inspect floor equip and brakes. ;Trip in hole F/ 6545' - T/ 8104' MD. Tagged up 20k. Attempt to work past staging up to 60k do (no go). Hole took proper displacement.; Wash and Ream F/8104'-T/ 8221' MD. 400 gpm, 1900 spp, 40 rpm, 8k tq.; Continue drilling 8 1/2" hole F/ 8221' - T/ 8531'. 476 gpm, 2240 spp, 245 diff, 43% flow, 75 rpm, l l k tq on, 9.3k tq off. 1009 units gas @ btm's up. Hole unloaded sand/coal @ btms up.; Hauled 72 bbls cuttings to KGF G&I for total = 1845 bbls Hauled 288 bbls class II junk fluid to KGF G&I for total = 3403 bbls Hauled 0 bbls cement to KGF G&I for total = 103 bbls;Last svy @ 8308' MD / 7835' TVD, 19.90° Inc, 12.43° Az = 1.86' low, 1.44' right of plan 12/11/2015 Continue drig 8-1/2" dir hole f/ 8532' U 9028' up/dn/rot = 188/1361156k @ 475 gpm, 2268 spp, 50 rpm @ 12-13k tq and 16k wob.,Pump around 20 bbls high vis sweep while drilling @ 8600' w/ 30% increase.; Circulate hole clean (rot & recip pipe) @ 9028' MD. 475 gpm, 2122 spp. Pump 20 bbls hi vis sweep W/ 150% inc in cuttings (sand/coal). Pull 1 std and monitor well (slight seepage). B/D TDS. Trip out from 9028' to 7464' with no notable tight spots. 3.9 bbls loss for trip out.;Trip in hole from 7464' to 8977'. Tagged up 8977', P/U and pulled 25k over. Washed do from 8977' to 9028' w/ no issues. Hole took proper displacement for trip in.;Drill from 9028' to 9484' MD. 486 gpm, 2670 spp, 320 diff, 44% flow, 60 rpm, 13k tq on, 11 k tq off, 9.94 ECD's, 49 units BGG. Saw 834 units @ btms up after lrip.;Adjust drilling tq to 18k due to stalling issues and cont drilling ahead. Pump 20 bbl hi vis sweep @ 9405' w/ 75% increase in cuttings (coal/sand/clay). Maintain 1% lubes for stick/slip and sliding.;C/0 swab #2 MP (#2 pod). Rack back std and work pipe w/ minimal flow rate while changing swab.; Drill from 9484' to 9548' MD. 486 gpm, 2700 spp, 310 diff, 43% flow, 60 rpm, 13k tq on, l l k tq off, 10.11 ECD's, 49 units BGG.;Hauled 97 bbls cuttings to KGF G&I for total= 1942 bbls Hauled 523 bbls class II junk fluid to KGF G&I for total = 3926 bbls Hauled 0 bbls cement to KGF G&I for total = 103 bbls;Currently 1/2' high and 1' right of plan 12/12/2015 Continue drig 8-1/2" dir hole f/ 9536't/ 9851' up/dn/rot = 212/144/170k @ 475 gpm, 2616 spp, 70 rpm @ 12-14k tq and 17k wob.;Pump around 20 bbl high vis sweep on time wl 200% increase pull std chk flow w/just slight seepage.,Short trip OOH f/ 9851' t/ 8275' w/ no brk backs and 4.4 bbls over cal.;Short trip RIH and set do @ 9513' unable to work past w/ proper hole fill kelly up ream U 9525' continue rih on elevators set do again @ 9826' kelly up ream U btm @ 9851'.; Resume drig f/ 9851' U 10,295' MD. 485 gpm, 2660 spp, 240 diff, 44% flow, 55 rpm, l l k tq off, 13.6k tq on, 10.07 ECD's, 90 bgg. Pump 20 bbl hi vis sweep @ 10,175'(150% inc).;Continue drilling 8 1/2" hole F/ 10,295'-T/ 10,550' MD. 479 gpm, 2490 spp, 43% flow, 55 rpm, 11.2k tq off, 14k tq on, 10.13 ECD's, 50 bgg. Pump 20 bbl hi vis /nut plug sweep @ 10395'(50% inc).,Hauled 149 bbls cuttings to KGF G&I for total= 2091 bbls Hauled 582 bbls class II junk fluid to KGF G&I for total = 4508 bbls Hauled 0 bbls cement to KGF G&I for total = 103 bb1s;4.3' high / 2.2' left (4.8' ctr to ctr). 12/13/2015 Continue drilling 8-1/2" dir hole f/ 10550't/ 10695' and TD hole section.;Circ btm up for TO sample. Pump 18 bbls high vis sweep around on time w/ 75% increase and circ clean.;Pooh 5 std flow chk w/ just slight seepage continue pooh on elevators U 9115' work thru one tight spot @ 9950-9900'. Rump dry job and blow on Ids and lines.; Continue pooh on elevators and work thru 9 tight spots t/ 4809'. 10 bbl loss for trip. UD btm jt on std #46 (galled box). Std back stand w/ bad pin and wrkn single.; Unable to pass 4809' kelly up and back ream f/ 4809' t/ 3091' MD. 462 gpm, 1640 spp, 42% flow, 40-50 rpm, 6.2k tq. Saw moderate amount of coal/sand/clay back across shakers while backreaming.;Numerous tight spots while backreaming out. Kept RPM's low to not destabilize coals. Found most tight spots did not correlate w/ coals but rather claystone and areas w/ higher gas counts.;Circulate bottoms up @ 3091' MD (rot and recip). 462 gpm, 1535 spp, 42% flow, 55 rpm, 5.8k tq, 10.31 ECD's, 4 units bgg. Pumped 20 bbls hi vis sweep w/ 100% increase in cuttings / on time.;Sweep brought back moderate amounts of 114"-3/8" coal cuttings mixed w/ a fair amount of sand and clay. Shakers cleaned up after est 1 1/2 btms up. Trip out 2 stds to 2941' MD (inside shoe).;Monitor static well and cut slip drig line and service rig (cut 142' line). Trip tank showed static loss rate of 1 BPH.;Service rig. Grease blocks, TDS, IR, Drawworks and Crown section.;B/O and laydown remaining std #46 w/ galled pin and working single. New pipe count = 318 jts total (in derrick + In hole).;Rih F/ 2941' to 6606' MD. Tag @ 6045'. Wash/Ream past, trip thru no issues. Cont trip in hole, work past few tight spots on elevators. fill pipe 20 stds.;Hauled 58 bbls cuttings to KGF G&I for total = 2158 bbls Hauled 203 bbls class II junk fluid to KGF G&I for total = 4710 bbis Hauled 0 bbls cement to KGF G&I for total = 103 bbls;Projected to bit @ TO (10,695' MD / 10,117' TVD) we are 9' low / 5.1' right (10.3' ctr to ctr) from plan. 12/14/2015 Continue Rih f/ 6606' U 8472'.;Circ. while cooling do rigs cooling system had failure of high temp alarm and boiled over radiator <15 gal to secondary containment. See SO-1.;Continue rih w/ 5 set do and worked thru all on elevators t/ tag @ 10649' (coal) kelly up reamed f/ 10649't/ TO @ 10695'w/ +- 28' fill.;Pump 20 bbl high vis sweep around @ reduced rate (170 gpm) due to hole unloading 300+ increase in cuttings for first 418 bbls then able to stage rate to 500 gpm. Sweep late +41 bbls w/ 100% increase.,Pump 2nd 20 bbls sweep around @ 500 gpm and 80 rpm. Weighted up to 9.7 ppg.;Trip out of hole F/ 10,695'- T/ 2,994' MD. Work thru tight spot @ 7090' 60k over (3x then clean) and 6520' 40k over (Ix then clean). No other notable overpulls or obstructions for trip out.;Check tq values of TDS, Iron roughneck and rig tongs. All tq values are within 230 f 1lbs on analog gauges w/ 22,281 ft/lbs applied (TDS). Equipment good.;Continue trip out of hole F/ 2,994' - T/ BHA @ 790'. Hole took 27 bbls over calculated for trip out.; BHA -Rack back HWDP w/ jars. Std back Monel Flex DC. PJSM, Remove sources from string, Download MWD and UD same. Drain mtr, B/O bit and UD same. Bit grade= 3,2,BT,A,X,2,CT,TD;Hauled 18 bbls cuttings to KGF G&I for total= 2176 bbls Hauled 162 bbls class II junk fluid to KGF G&I for total = 4872 bbls Hauled 0 bbls cement to KGF G&I for total = 103 bbls 12/15/2015 Clear clean floor & chg out air boot rubber on flow nipple.;PJSM w/ SLB E-line and drig crew.;R/up E-line and p/up tools.;Rih w/ RFT taking impressions f/ 3096' t/ 7910' wlm could not pass 7910' (coal) also pull +- 1000# over 7560' tt 7570' (coal) but work thru and cleanup. Obtained total of 45 impressions w/ 32 good.;Pooh and r/dn E-line monitored well on trip tank during logging w/ 1/4 bph loss rate.;P/up m/up dumb iron clean out assy BHA #5 & RIH to DP.,Continue RIH to just inside shoe. Shoe at 29001.,Fill pipe and circ one full circ.,RIH filling pipe again at 6000' and 8570'. Sat down up to 30k at 6929, 7920', 8295', and 8427'. Worked through these spot on elevators and cleaned them up.;Continue RIH but had to wash and ream through tight spots at 9035', 9166', and 9294'. RIH on elevators to 9859'.;Hauled 0 bbls cuttings to KGF G&I for total = 2176 bbls Hauled 90 bbls class II junk fluid to KGF G&I for total = 4962 bbls Hauled 0 bbls cement to KGF G&1 for total = 103 bbls 12116/2015 Wash and ream in hole and work through tight spots f/ 9555't/ TD @ 10695' (did exercise jars a few limes).;Pump 20 bbls high vis sweep around while rotating and reciprocating pipe @ 85 RPM w/ 11200 TQ and 505 gpm @ 2090 psi w/ 70% increase throughout reaming w/ sweep bring back 100% increase (coal chips).;Short trip on elevators racking back f/ 10695' U 8990' w/ tight spots @ 9952' (hung pipe w/ jar fire at high over pull torque and slump to free pipe, ream std clean up area) 9940, 9885' and 9683'.;Short trip RIH on elevators w/ no set do f/ 8990' U Tag @ 10,670' kelly up ream clean out 25' fill t/ TO @ 10695'.;Circ and pump high vis sweep w/ nut plug while reciprocating and rotating the pipe. Complete circ =10,150 stks. At 4,500 stks we had a 50% increase cuttings [coal] and it continued to 8,000 stks;where it died down. Started seeing nut plug back at 11,140 stks and sweep came back at 11,590 stks w/ another 50% increase of cuttings. 103 bbls late. Circ hole clean. High gas 228 units., Pull 2 stds. Monitor well and change elevators. Pump dry job with corrosion inhibitor. Also added corrosion inhibitor to trip tank to attempt to pickle pipe.,POH laying do DP f/ 10,582' t/ 8741', taking extra care to clean any mud off threads and having vac unit suck nerf ball through DP on rack to clean out any extra fluid. Continue POH laying do DP f/ 8741' t/ 4500'. Had 3 tight spots that pulled 15k over but cleaned up after working back through. 6450', 6098', & 5920'. So far hole has taken 7 bbls over displacement.,Hauled 45 bbls cuttings to KGF G&I for total = 2221 bbls Hauled 135 bbls class II junk fluid to KGF G&I for total = 5097 bbls Hauled 0 bbls cement to KGF G&I for total = 103 bbls 12/17/2015 Continue Pooh laying do DP f/ 4352' t/ 2860'.;Monitor well @ 114 bph loss while slip and cut drlg line (110').; Continue Pooh laying do DP and bha f/2860' t/ Bit w/ 10.4 bbis over cal for complete trip out.;Wash out stack, pull wear ring and install test plug.;Chg upper rams U 5-1/2" and test same 250-4500 psi. Good on chart and chg to long bails.;Dummy run hanger (ok) and mark landing jt. landed out at 20.79.,Finish r/up to run csg and hold PJSM w/ everyone involved.;MU shoe track and check floats. [Reamer shoe OD 7 3/4"] Run 5 1/2 csg to 1750' filling pipe on the run, but topping off every 10 jts.;Run 51/2 csg N 1750 t/ shoe at 2973'.;MU XO and TD. Circ bottoms up staging pump up to 5 BPM 147 psi. Get rotating torque values at 10 rpm=4000 tq, 20 rpm=4250 tq, 30 rpm= 4500 Tq. Adjust TO torque do to 11,900.; Blow do TO and mud Iine.,Run 1 jt and brake band broke on the power tongs. Repair brake band on Weatherford tongs.; Run 5 1/2" csg f/ 3017' V 3194'. Tong operators changed out. Operator pumped up tong sensor and we believe he tightened do dampener to much and over torqued connection.; Break out and lay do jt #74 and 73 due to swelled connections. Checked other connections and they were good. Replace jts with 2 spare jts. Pictures in O-drive.; Continue RIH f/ 3239' U 4522'. [mixed our 300 bbis of 3% KCL while running csg]-Hauled 13 bbis cuttings to KGF G&I for total = 2234 bbis Hauled 167 bbis class II junk fluid to KGF G&I for total = 5264 bbis Hauled 0 bbis cement to KGF G&I for total = 103 bbls 12/18/2015 Continue rih phrp 5-1/2" 17# Geo-Conn csg W/ 20# collars f/ 4522' V 5956' filling on the fly topping off every 10 w/ no problems.;Circ and stage rate V 5 bpm while reciprocating pipe and warm mud w/ total of 324.5 bbis pumped and high gas of 111 units. Blow do TDS and Iines.;Continue rih p/up 5-1/2" 17# Geo-Conn csg W/ 20# collars f/ 5956' ti 8586' filling on the fly topping off every 10 w/ one 20-25k bobble @ 6047'.;Circ and stage rate U 5 bpm while reciprocating pipe and warm mud w/ total of 449 bbis pumped and high gas of 318 units. P/up swell prk and Blow do TDS and Iines.;Continue rih p/up 5-12" 17# Geo-Conn csg W/20# collars f/ 8586' t/ 10606' filling on the fly topping off every 10 jts.;MU hanger and landing jt. Land hanger w/ shoe at 10631'. RU xo and mu TD. PU w/ 185 up and 120 dn. Break circ.;Start circ at 3 BPM staging pumps up to 5 BPM at 325 psi while reciprocating pipe. Circ 1 1/2 bottoms up getting back sand and a few coal slivers on bottoms up. High gas was 441 units.,RU cementers while circ and bring cmt head and manifold to rig floor. Load plugs in cmt head.;Shut do pump and land hanger. Break out and blow do TD. Break out xo sub. MU cmt head and tie lines into manifold.; PU of hanger w/ 20k overpull to get csg free. Continue circ while we are waiting to mix 2nd batch of mud push. Hold PJSM.;Pump 10 bbis water w/ Schlumberger to cuttings box. Test line to 4600 psi. pump 31 bbis 12.6 ppg mudpush w/ rig pump. Drop top plug. Pump 490 bbis 15.3 ppg cmt. Drop top plug.;Flush cmt lines to cuttings tank. Displace with 245 bbis 3% KCL at 6 BPM. Plug bumped .5 bbis over displacement. (At 160 bbls away we had to land out hanger due to hole getting sticky).;Final circ pressure was 3300 psi. Pressured up to 3800 psi and held it for 5 min. Bled back 3 bbis and floats held. Cement in place at 3:53.,Rig down cmt head and lines after everything was blown down. Clear floor of cmt equip.,Pull landing jt. Mu packoff running tool and set packoff as per wellhead hand. Prep to nipple do BOPs.; Hauled 0 bbis cuttings to KGF G&I for total = 2234 bbis Hauled 90 bbis class II junk fluid to KGF G&I for total = 5354 bbls Hauled 0 bbis cement to KGF G&I for total = 103 bbis 12/19/2015 Set BPV Blow do TDS and lines. Remove 5-1/2" ram f/ upper rams & replace w/ 2-7/8" X 5" VBRs. Continue haul mud/clean pits. r/dn gas detection equipment.;Nip/dn stack and set in transport. Remove spacer spool. Remove csg elevators & long bails. Chk end play & back lash in top drive. remove quill Chg wash pipe. chg oil in gear box & swivel chg out.,Grabber box dies & die block. lay/dn rig tongs. Clean and I/dn subs. Install shipping pins in iron roughneck. Continue haul mud clean pits. R/dn 3 party shacks.; Nip/up dry hole tree Packoff "P" seals to tbg head adapter t/6000 psi and tested same U 5000 psi for 5min good. Test tbg head adapter viod t/ 500 psi for 5min low ok and 5000 psi for 15 min high;Ok . Pulled BPV and set TWC and test tree 250 low & 5000 high for 10 min each. ok, Pull TWC. Continue r/dn IR. continue haul mud/clean pits & strip shakers remove wind walls on rig floor R/dn TDS.;Continue hauling mud to G&I. Blow do lines in mud pits. Clean mud pits. LD topdrive. Scope do top section of derrick. Go through fluid ends of mud pumps.;Continue hauling mud and cleaning pits. Run vac hose down csg 40' and suck out KCL. Fill 51/2 csg w/ 39 gal. of diesel for freeze protection. Lay do derrick.; Rig released f/ HV B-17 at 0600 hrs.;Hauled 0 bbis cuttings to KGF G&I for total = 2234 bbls Hauled 1080 bbis class II junk fluid to KGF G&I for total = 6434 bbls Hauled 0 bbls cement to KGF G&I for total = 103 bbls 12/202015 Rig was released at 0600 hrs to Warm stack AFE. Tested 5 1/2 csg to 4650 psi for 30 min on a chart w/ ann open and on a vac, Good test. put 3 3/4 bbls diesel down back side in 5 ann. This did not fill the ann up but it should have covered 80+ feet. L alt Hilc_ . p Energy Company Composit, Aeport Well Name: DCU HVB-17 Field: Happy Valley County/State: , AK i (LAT/LONG): ovation (RKB): API #: 50-231-20049-00 Spud Date: Job Name: 1512577C HVB-17 COMPLETION Contractor AFE #: 1512577C AFE $: Activity Date Ops Summary 12/29/2015 Weather delay due to high winds, rain on ice., Began permits and rig up. Logged CBL from tag depth of 10,542'-1,750'. RDMO. Hilcorp Energy Company Deep Creek Unit Happy Valley B Pad HVB-17 502312004900 502312004900 Sperry Drilling Definitive Survey Report 22 December, 2015 HALLIBURTON Sperry Drilling Company: Hilcorp Energy Company Project: Deep Creek Unit Site: Happy Valley B Pad Well: Happy Valley B-17 Wellbore: HVB-17 Design: HVB-17 Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Happy Valley B-17 HV B-17 @ 611.50usft (Saxon 169 (18+593.5)) HV B-17 @ 611.50usft (Saxon 169 (18+593.5)) True Minimum Curvature Sperry EDM - NORTH US + CANADA Project Deep Creek Unit 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 Well Happy Valley B-17 Well Position +N/ -S 0.00 usft Northing: 2,190,946.64 usft Latitude: 59° 59'19.319 N +E/ -W 0.00 usft Easting: 223,621.86 usft Longitude: 151 ° 30' 33.646 W Position Uncertainty 0.00 usft Wellhead Elevation: 593.50 usft Ground Level: 593.50 usft Wellbore HVB-17 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGG M2015 11/2712015 16.09 73.03 55,135 Design HVB-17 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 14.06 Survey Program Date 12/22/2015 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 175.21 2,931.99 MWD+SC+sag (1) (HVB-17) MWD+SC+sag Fixed:v2:standard dec & axial correction + sag 12/22/2015 3,032.16 10,658.77 MWD+SC+sag (2) (HVB-17) MWD+SC+sag Fixed:v2:standard dec & axial correction + sag 12/22/2015 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 18.00 0.00 0.00 18.00 -593.50 0.00 0.00 2,190,946.64 223,621.86 0.00 0.00 UNDEFINED 175.21 0.12 347.48 175.21 -436.29 0.16 -0.04 2,190,946.81 223,621.82 0.08 0.15 MWD+SC+sag (1) 206.09 0.14 32.63 206.09 -405.41 0.22 -0.02 2,190,946.87 223,621.84 0.33 0.21 MWD+SC+sag (1) 267.16 0.17 44.93 267.16 -344.34 0.35 0.08 2,190,946.99 223,621.95 0.07 0.36 MWD+SC+sag (1) 328.22 0.26 344.11 328.22 -283.28 0.55 0.11 2,190,947.19 223,621.98 0.38 0.56 MWD+SC+sag (1) 389.66 0.14 321.90 389.66 -221.84 0.74 0.02 2,190,947.38 223,621.90 0.23 0.73 MWD+SC+sag (1) 448.76 0.14 326.09 448.76 -162.74 0.86 -0.06 2,190,947.50 223,621.82 0.02 0.82 MWD+SC+sag(1) 521.05 0.14 314.07 521.05 -90.45 0.99 -0.17 2,190,947.64 223,621.71 0.04 0.92 MWD+SC+sag (1) 582.74 1.50 14.54 582.73 -28.77 1.83 -0.03 2,190,948.47 223,621.87 2.33 1.77 MWD+SC+sag (1) 643.43 3.45 15.95 643.36 31.86 4.35 0.68 2,190,950.98 223,622.63 3.21 4.39 MWD+SC+sag (1) 704.70 5.35 13.20 704.45 92.95 8.91 1.83 2,190,955.51 223,623.89 3.12 9.08 MWD+SC+sag (1) 768.22 7.11 10.67 767.59 156.09 15.65 3.24 2,190,962.22 223,625.45 2.80 15.97 MWD+SC+sag (1) 829.72 8.79 9.31 828.50 217.00 24.03 4.70 2,190,970.56 223,627.11 2.75 24.45 MWD+SC+sag (1) 12/22/2015 3:41:39PM Page 2 COMPASS 5000.1 Build 73 Company: Project: Site: Well: Wellbore: Design: Survey Hilcorp Energy Company Deep Creek Unit Happy Valley B Pad Happy Valley B-17 HVB-17 HVB-17 Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Happy Valley B-17 HV B-17 @ 611.50usft (Saxon 169 (18+593.5)) HV B-17 @ 611.50usft (Saxon 169 (18+593.5)) True Minimum Curvature Sperry EDM - NORTH US + CANADA 12/22/2015 3:41:39PM Page 3 COMPASS 5000.1 Build 73 Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/•W Northing Easting DLS Section (usft) 111 V) (usft) (usft) (usft) (usft) (ft) (ft) (.1100.) (ft) Survey Tool Name 892.02 10.76 9.38 889.89 278.39 34.47 6.42 2,190,980.96 223,629.06 3.16 34.99 MWD+SC+sag (1) 952.99 11.24 10.80 949.74 338.24 45.92 8.46 2,190,992.36 223,631.37 0.90 46.60 MWD+SC+sag (1) 1,015.41 11.28 10.49 1,010.96 399.46 57.90 10.71 2,191,004.28 223,633.89 0.12 58.77 MWD+SC+sag (1) 1,077.41 12.58 10.33 1,071.62 460.12 70.50 13.03 2,191,016.83 223,636.49 2.10 71.56 MWD+SC+sag (1) 1,140.34 14.90 10.96 1,132.74 521.24 85.19 15.80 2,191,031.45 223,639.59 3.69 86.48 MWD+SC+sag (1) 1,203.53 16.28 11.42 1,193.61 582.11 101.85 19.10 2,191,048.03 223,643.27 2.19 103.44 MWD+SC+sag (1) 1,264.08 17.60 11.34 1,251.53 640.03 119.14 22.58 2,191,065.24 223,647.14 2.18 121.06 MWD+SC+sag (1) 1,328.68 19.22 10.56 1,312.82 701.32 139.17 26.45 2,191,085.18 223,651.47 2.54 141.43 MWD+SC+sag(1) 1,390.13 19.68 10.77 1,370.76 759.26 159.28 30.23 2,191,105.20 223,655.71 0.76 161.86 .MWD+SC+sag (1) 1,451.04 19.53 10.43 1,428.14 816.64 179.37 33.99 2,191,125.19 223,659.93 0.31 18226 MWD+SC+sag (1) 1,514.95 19.51 10.53 1,488.38 876.88 200.37 37.88 2,191,146.10 223,664.29 0.06 203.57 MWD+SC+sag(1) 1,576.45 19.67 10.12 1,546.32 934.82 220.66 41.57 2,191,166.29 223,668.45 0.34 224.14 MWD+SC+sag (1) 1,639.34 20.44 11.11 1,605.40 993.90 241.85 45.55 2,191,187.39 223,672.91 1.34 245.67 MWD+SC+sag (1) 1,700.60 20.97 10.93 1,662.70 1,051.20 263.11 49.69 2,191,208.55 223,677.53 0.87 267.30 MWD+SC+sag (1) 1,761.85 20.92 10.61 1,719.90 1,108.40 284.62 53.78 2,191,229.96 223,682.11 0.20 289.16 MWD+SC+sag (1) 1,824.94 20.85 10.62 1,778.85 1,167.35 306.73 57.92 2,191,251.97 223,686.76 0.11 311.61 MWD+SC+sag (1) 1,887.64 21.06 10.30 1,837.40 1,225.90 328.78 61.99 2,191,273.92 223,691.33 0.38 333.99 MWD+SC+sag(1) 1,949.06 21.12 10.20 1,894.71 1,283.21 350.53 65.93 2,191,295.57 223,695.76 0.11 356.04 MWD+SC+sag (1) 2,012.43 21.12 9.87 1,953.82 1,342.32 373.01 69.90 2,191,317.96 223,700.25 0.19 378.82 MWD+SC+sag(1) 2,074.88 20.93 10.12 2,012.11 1,400.61 395.08 73.79 2,191,339.93 223,704.64 0.34 401.17 MWD+SC+sag(1) 2,136.98 20.87 10.84 2,070.12 1,458.62 416.86 77.82 2,191,361.62 223,709.17 0.42 423.28 MWD+SC+sag (1) 2,196.08 20.83 11.53 2,125.35 1,513.85 437.49 81.90 2,191,382.16 223,713.72 0.42 444.28 MWD+SC+sag(1) 2,262.14 20.99 11.87 2,187.06 1,575.56 460.58 86.68 2,191,405.13 223,719.02 0.30 467.84 MWD+SC+sag (1) 2,323.26 21.20 11.77 2,244.09 1,632.59 482.11 91.19 2,191,426.55 223,724.02 0.35 489.82 MWD+SC+sag (1) 2,386.79 21.33 11.76 2,303.29 1,691.79 504.67 95.89 2,191,448.99 223,729.23 0.20 512.85 MWD+SC+sag (1) 2,450.97 21.58 11.37 2,363.03 1,751.53 527.67 100.59 2,191,471.88 223,734.46 0.45 536.30 MWD+SC+sag (1) 2,514.88 21.76 11.47 2,422.42 1,810.92 550.80 105.27 2,191,494.90 223,739.66 0.29 559.87 MWD+SC+sag (1) 2,578.09 21.93 11.43 2,481.09 1,869.59 573.85 109.93 2,191,517.84 223,744.85 0.27 583.37 MWD+SC+sag (1) 2,641.55 22.07 11.23 2,539.93 1,928.43 597.16 114.61 2,191,541.04 223,750.05 0.25 607.11 MWD+SC+sag (1) 2,704.82 21.54 10.05 2,598.67 1,987.17 620.26 118.95 2,191,564.03 223,754.92 1.09 630.57 MWD+SC+sag (1) 2,768.45 20.97 9.24 2,657.97 2,046.47 643.00 122.81 2,191,586.67 223,759.31 1.01 653.57 MWD+SC+sag (1) 2,831.65 21.12 9.36 2,716.96 2,105.46 665.39 126.48 2,191,608.98 223,763.48 0.25 676.19 MWD+SC+sag(1) 2,894.12 21.30 9.64 2,775.20 2,163.70 687.69 130.21 2,191,631.18 223,767.72 0.33 698.72 MWD+SC+sag (1) 2,931.99 21.45 9.49 2,810.46 2,198.96 701.30 132.51 2,191,644.73 223,770.33 0.42 712.48 MWD+SC+sag (1) 3,032.16 21.60 9.76 2,903.65 2,292.15 737.53 138.65 2,191,680.82 223,777.30 0.18 749.12 MWD+SC+sag (2) 3,094.18 21.62 8.29 2,961.31 2,349.81 760.09 142.23 2,191,703.29 223,781.39 0.87 771.87 MWD+SC+sag (2) 3,156.32 21.52 7.41 3,019.09 2,407.59 782.72 145.35 2,191,725.84 223,785.03 0.54 794.58 MWD+SC+sag (2) 3,217.97 21.54 6.09 3,076.44 2,464.94 805.18 148.01 2,191,748.24 223,788.20 0.79 817.02 MWD+SC+sag (2) 3,280.15 20.57 9.92 3,134.47 2,522.97 827.30 151.11 2,191,770.28 223,791.79 2.71 839.22 MWD+SC+sag (2) 3,341.43 20.90 9.95 3,191.79 2,580.29 848.67 154.85 2,191,791.56 223,796.02 0.54 860.86 MWD+SC+sag (2) 12/22/2015 3:41:39PM Page 3 COMPASS 5000.1 Build 73 Company: Hilcorp Energy Company Project: Deep Creek Unit Site: Happy Valley B Pad Well: Happy Valley B-17 Wellbore: HVB-17 Design: HVB-17 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: Well Happy Valley B-17 TVD Reference: HV B-17 @ 611.50usft (Saxon 169 (18+593.5)) MD Reference: HV B-17 @ 611.50usft (Saxon 169 (18+593.5)) North Reference: True Survey Calculation Method: Minimum Curvature Database: Sperry EDM - NORTH US + CANADA 12/22/2015 3:41:39PM Page 4 COMPASS 5000.1 Build 73 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Easting DLS Section (usft) 0 (1 (usft) (usft) (usft) (usft) (ft) (ft) (-/low) (ft) Survey Tool Name 3,403.53 20.35 12.54 3,249.91 2,638.41 870.12 159.11 2,191,812.91 223,800.77 1.72 882.70 MWD+SC+sag (2) 3,465.90 20.41 11.95 3,308.37 2,696.87 891.34 163.71 2,191,834.02 223,805.86 0.34 904.41 MWD+SC+sag (2) 3,528.23 20.35 10.86 3,366.80 2,755.30 912.62 168.01 2,191,855.19 223,810.64 0.62 926.10 MWD+SC+sag (2) 3,590.35 20.51 9.81 3,425.01 2,813.51 933.95 171.90 2,191,876.43 223,815.01 0.64 947.73 MWD+SC+sag (2) 3,652.16 19.89 12.86 3,483.02 2,871.52 954.87 176.08 2,191,897.25 223,819.67 1.98 969.04 MWD+SC+sag (2) 3,713.77 20.01 12.54 3,540.94 2,929.44 975.38 180.70 2,191,917.65 223,824.76 0.26 990.06 MWD+SC+sag (2) 3,776.59 20.20 12.58 3,599.93 2,988.43 996.46 185.40 2,191,938.61 223,829.94 0.30 1,011.65 MWD+SC+sag (2) 3,839.48 20.60 12.05 3,658.87 3,047.37 1,017.87 190.07 2,191,959.92 223,835.10 0.70 1,033.56 MWD+SC+sag (2) 3,900.60 20.52 11.11 3,716.10 3,104.60 1,038.90 194.38 2,191,980.84 223,839.89 0.56 1,055.00 MWD+SC+sag (2) 3,962.24 20.74 10.18 3,773.79 3,162.29 1,060.25 198.39 2,192,002.09 223,844.38 0.64 1,076.68 MWD+SC+sag (2) 4,025.55 21.28 10.27 3,832.89 3,221.39 1,082.58 202.42 2,192,024.33 223,848.92 0.85 1,099.33 MWD+SC+sag (2) 4,087.45 20.09 11.95 3,890.80 3,279.30 1,104.04 206.63 2,192,045.68 223,853.61 2.15 1,121.16 MWD+SC+sag (2) 4,149.62 20.11 11.71 3,949.18 3,337.68 1,124.95 211.01 2,192,066.49 223,858.47 0.14 1,142.51 MWD+SC+sag (2) 4,212.07 20.01 11.22 4,007.84 3,396.34 1,145.94 215.26 2,192,087.38 223,863.20 0.31 1,163.91 MWD+SC+sag (2) 4,274.39 19.85 9.94 4,066.43 3,454.93 1,166.82 219.16 2,192,108.16 223,867.58 0.75 1,185.11 MWD+SC+sag (2) 4,336.70 19.92 9.73 4,125.03 3,513.53 1,187.70 222.78 2,192,128.96 223,871.68 0.16 1,206.25 MWD+SC+sag (2) 4,398.58 19.92 9.58 4,183.20 3,571.70 1,208.49 226.32 2,192,149.66 223,875.69 0.08 1,227.27 MWD+SC+sag (2) 4,460.33 20.02 9.16 4,241.24 3,629.74 1,229.30 229.75 2,192,170.38 223,879.59 0.28 1,248.29 MWD+SC+sag (2) 4,522.55 20.03 7.87 4,299.70 3,688.20 1,250.37 232.91 2,192,191.37 223,883.23 0.71 1,269.49 MWD+SC+sag (2) 4,583.57 20.81 10.63 4,356.89 3,745.39 1,271.37 236.34 2,192,212.29 223,887.14 2.03 1,290.70 MWD+SC+sag (2) 4,645.87 20.60 9.75 4,415.16 3,803.66 1,293.05 240.24 2,192,233.88 223,891.53 0.60 1,312.68 MWD+SC+sag (2) 4,709.49 21.41 11.86 4,474.55 3,863.05 1,315.45 244.52 2,192,256.17 223,896.32 1.74 1,335.44 MWD+SC+sag (2) 4,771.11 21.43 11.03 4,531.92 3,920.42 1,337.50 248.98 2,192,278.12 223,901.29 0.49 1,357.92 MWD+SC+sag (2) 4,833.32 21.17 10.23 4,589.88 3,978.38 1,359.71 253.15 2,192,300.23 223,905.96 0.63 1,380.48 MWD+SC+sag (2) 4,895.49 20.69 10.04 4,647.95 4,036.45 1,381.57 257.06 2,192,321.99 223,910.37 0.78 1,402.63 MWD+SC+sag (2) 4,958.51 20.48 9.74 4,706.94 4,095.44 1,403.40 260.87 2,192,343.73 223,914.67 0.37 1,424.73 MWD+SC+sag (2) 5,019.83 21.15 11.47 4,764.26 4,152.76 1,424.82 264.88 2,192,365.05 223,919.17 1.48 1,446.48 MWD+SC+sag (2) 5,081.49 20.57 10.52 4,821.88 4,210.38 1,446.37 269.07 2,192,386.50 223,923.85 1.09 1,468.41 MWD+SC+sag (2) 5,143.65 21.69 11.87 4,879.86 4,268.36 1,468.35 273.43 2,192,408.37 223,928.71 1.96 1,490.78 MWD+SC+sag (2) 5,206.25 21.78 11.46 4,938.01 4,326.51 1,491.05 278.12 2,192,430.96 223,933.91 0.28 1,513.94 MWD+SC+sag (2) 5,268.25 21.78 10.58 4,995.58 4,384.08 1,513.63 282.51 2,192,453.43 223,938.82 0.53 1,536.92 MWD+SC+sag(2) 5,331.14 21.49 9.34 5,054.04 4,442.54 1,536.47 286.52 2,192,476.17 223,943.36 0.86 1,560.04 MWD+SC+sag (2) 5,392.45 20.94 8.83 5,111.20 4,499.70 1,558.37 290.03 2,192,498.00 223,947.36 0.95 1,582.15 MWD+SC+sag (2) 5,454.77 20.95 12.57 5,169.40 4,557.90 1,580.25 294.16 2,192,519.77 223,951.99 2.15 1,604.37 MWD+SC+sag (2) 5,516.17 20.68 12.58 5,226.80 4,615.30 1,601.55 298.91 2,192,540.96 223,957.23 0.44 1,626.19 MWD+SC+sag (2) 5,578.96 20.16 12.03 5,285.64 4,674.14 1,622.95 303.58 2,192,562.25 223,962.38 0.88 1,648.08 MWD+SC+sag (2) 5,641.43 19.72 11.12 5,344.36 4,732.86 1,643.82 307.86 2,192,583.01 223,967.13 0.86 1,669.37 MWD+SC+sag (2) 5,703.23 21.47 14.18 5,402.21 4,790.71 1,665.02 312.64 2,192,604.10 223,972.40 3.32 1,691.09 MWD+SC+sag (2) 5,763.57 20.91 13.73 5,458.47 4,846.97 1,686.19 317.90 2,192,625.14 223,978.14 0.97 1,712.90 MWD+SC+sag (2) 5,827.15 20.66 13.09 5,517.92 4,906.42 1,708.13 323.14 2,192,646.96 223,983.87 0.53 1,735.46 MWD+SC+sag (2) 12/22/2015 3:41:39PM Page 4 COMPASS 5000.1 Build 73 Company Project: Site: Well: Wellbore: Design: Survey Hilcorp Energy Company Deep Creek Unit Happy Valley B Pad Happy Valley B-17 HVB-17 HVB-17 Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Happy Valley B-17 HV B-17 @ 611.50usft (Saxon 169 (18+593.5)) HV B-17 @ 611.50usft (Saxon 169 (18+593.5)) True Minimum Curvature Sperry EDM - NORTH US + CANADA Vertical Section (ft) Survey Tool Name 1,757.23 MWD+SC+sag (2) 1,778.27 MWD+SC+sag (2) 1,799.60 MWD+SC+sag (2) 1,821.63 MWD+SC+sag (2) 1,843.85 MWD+SC+sag (2) 1,866.14 MWD+SC+sag (2) 1,888.58 MWD+SC+sag (2) 1,910.47 MWD+SC+sag (2) 1,932.54 MWD+SC+sag (2) 1,954.46 MWD+SC+sag (2) 1,976.73 MWD+SC+sag (2) 1,999.55 MWD+SC+sag (2) 2,021.28 MWD+SC+sag (2) 2,043.56 MWD+SC+sag (2) 2,065.76 MWD+SC+sag (2) 2,088.07 MWD+SC+sag (2) 2,109.37 MWD+SC+sag (2) 2,131.19 MWD+SC+sag (2) 2,153.30 MWD+SC+sag (2) 2,175.33 MWD+SC+sag (2) 2,198.64 MWD+SC+sag (2) 2,221.46 MWD+SC+sag (2) 2,243.24 MWD+SC+sag (2) 2,264.85 MWD+SC+sag (2) 2,286.23 MWD+SC+sag (2) 2,306.90 MWD+SC+sag (2) 2,329.86 MWD+SC+sag (2) 2,352.98 MWD+SC+sag (2) 2,375.66 MWD+SC+sag (2) 2,398.97 MWD+SC+sag (2) 2,421.96 MWD+SC+sag (2) 2,444.37 MWD+SC+sag (2) 2,466.68 MWD+SC+sag (2) 2,489.47 MWD+SC+sag (2) 2,511.15 MWD+SC+sag (2) 2,533.74 MWD+SC+sag (2) 2,555.96 MWD+SC+sag (2) 2,577.13 MWD+SC+sag (2) 2,599.02 MWD+SC+sag (2) 2,620.31 MWD+SC+sag (2) 1212212015 3:41:39PM Page 5 COMPASS 5000.1 Build 73 Map Map MD Inc Azi TVD TVDSS +N1S +E1 -W Northing Easting DLS (usft) 0 0 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') 5,889.76 20.04 12.49 5,576.62 4,965.12 1,729.36 327.96 2,192,668.08 223,989.18 1.04 5,951.72 19.68 12.13 5,634.89 5,023.39 1,749.93 332.45 2,192,688.53 223,994.13 0.61 6,013.92 20.47 10.83 5,693.31 5,081.81 1,770.85 336.69 2,192,709.35 223,998.85 1.46 6,075.59 21.45 11.90 5,750.90 5,139.40 1,792.48 341.04 2,192,730.88 224,003.70 1.71 6,136.75 21.20 11.78 5,807.88 5,196.38 1,814.25 345.61 2,192,752.53 224,008.76 0.41 6,199.36 20.56 10.76 5,866.37 5,254.87 1,836.13 349.97 2,192,774.31 224,013.62 1.18 6,262.60 21.08 10.79 5,925.48 5,313.98 1,858.21 354.17 2,192,796.29 224,018.32 0.82 6,323.69 21.00 9.93 5,982.50 5,371.00 1,879.78 358.12 2,192,817.77 224,022.76 0.52 6,386.39 20.34 9.67 6,041.16 5,429.66 1,901.59 361.88 2,192,839.49 224,027.02 1.06 6,447.32 21.95 9.80 6,097.99 5,486.49 1,923.25 365.60 2,192,861.06 224,03123 2.64 6,507.98 21.26 9.94 6,154.39 5,542.89 1,945.26 369.43 2,192,882.97 224,035.56 1.14 6,571.60 20.91 9.35 6,213.75 5,602.25 1,967.82 373.26 2,192,905.44 224,039.91 0.64 6,633.15 20.56 9.81 6,271.31 5,659.81 1,989.31 376.89 2,192,926.84 224,044.03 0.63 6,695.73 21.26 10.79 6,329.77 5,718.27 2,011.28 380.89 2,192,948.72 224,048.52 1.25 6,757.16 21.18 10.53 6,387.04 5,775.54 2,033.14 385.00 2,192,970.47 224,053.13 0.20 6,819.47 20.87 10.47 6,445.20 5,833.70 2,055.12 389.07 2,192,992.35 224,057.71 0.50 6,880.79 19.87 10.47 6,502.68 5,891.18 2,076.10 392.95 2,193,013.24 224,062.07 1.63 6,943.02 21.25 11.61 6,560.95 5,949.45 2,097.55 397.14 2,193,034.59 224,066.75 2.31 7,004.94 20.64 11.00 6,618.78 6,007.28 2,119.26 401.48 2,193,056.19 224,071.58 1.05 7,065.89 21.80 10.56 6,675.59 6,064.09 2,140.93 405.61 2,193,077.76 224,076.20 1.92 7,128.45 22.04 10.52 6,733.63 6,122.13 2,163.89 409.88 2,193,100.62 224,080.99 0.38 7,190.30 21.38 9.63 6,791.09 6,179.59 2,186.41 413.89 2,193,123.05 224,085.51 1.19 7,252.34 19.89 8.54 6,849.15 6,237.65 2,208.00 417.34 2,193,144.55 224,089.46 2.48 7,314.83 20.67 12.28 6,907.77 6,296.27 2,229.29 421.27 2,193,165.74 224,093.87 2.42 7,377.10 19.51 12.42 6,966.25 6,354.75 2,250.18 425.84 2,193,186.53 224,098.92 1.86 7,437.52 20.52 12.17 7,023.02 6,411.52 2,270.39 430.25 2,193,206.63 224,103.78 1.68 7,500.80 22.10 10.16 7,081.97 6,470.47 2,292.95 434.68 2,193,229.08 224,108.73 2.75 7,562.44 22.08 9.83 7,139.09 6,527.59 2,315.78 438.71 2,193,251.81 224,113.28 0.20 7,624.22 21.16 8.36 7,196.52 6,585.02 2,338.25 442.31 2,193,274.20 224,117.39 1.73 7,687.71 22.11 9.24 7,255.54 6,644.04 2,361.38 445.90 2,193,297.24 224,121.50 1.58 7,749.60 21.71 8.45 7,312.96 6,701.46 2,384.20 449.45 2,193,319.97 224,125.57 0.80 7,811.76 20.76 8.28 7,370.89 6,759.39 2,406.48 452.72 2,193,342.17 224,129.36 1.53 7,873.68 21.68 9.32 7,428.62 6,817.12 2,428.62 456.16 2,193,364.23 224,133.29 1.61 7,936.30 21.17 8.85 7,486.91 6,875.41 2,451.21 459.77 2,193,386.73 224,137.42 0.86 7,997.87 20.26 8.29 7,544.50 6,933.00 2,472.74 463.02 2,193,408.18 224,141.16 1.51 8,061.78 21.28 10.58 7,604.25 6,992.75 2,495.09 466.74 2,193,430.44 224,145.39 2.04 8,123.84 20.76 10.79 7,662.18 7,050.68 2,516.97 470.87 2,193,452.22 224,150.02 0.85 6,184.63 20.09 10.51 7,719.15 7,107.65 2,537.82 474.79 2,193,472.97 224,154.41 1.11 8,247.25 20.87 12.97 7,777.82 7,166.32 2,559.26 479.26 2.193.494.31 224,159.37 1.85 8,308.38 19.90 12.43 7,835.12 7,223.62 2,580.03 483.94 2,193,514.97 224,164.52 1.62 Vertical Section (ft) Survey Tool Name 1,757.23 MWD+SC+sag (2) 1,778.27 MWD+SC+sag (2) 1,799.60 MWD+SC+sag (2) 1,821.63 MWD+SC+sag (2) 1,843.85 MWD+SC+sag (2) 1,866.14 MWD+SC+sag (2) 1,888.58 MWD+SC+sag (2) 1,910.47 MWD+SC+sag (2) 1,932.54 MWD+SC+sag (2) 1,954.46 MWD+SC+sag (2) 1,976.73 MWD+SC+sag (2) 1,999.55 MWD+SC+sag (2) 2,021.28 MWD+SC+sag (2) 2,043.56 MWD+SC+sag (2) 2,065.76 MWD+SC+sag (2) 2,088.07 MWD+SC+sag (2) 2,109.37 MWD+SC+sag (2) 2,131.19 MWD+SC+sag (2) 2,153.30 MWD+SC+sag (2) 2,175.33 MWD+SC+sag (2) 2,198.64 MWD+SC+sag (2) 2,221.46 MWD+SC+sag (2) 2,243.24 MWD+SC+sag (2) 2,264.85 MWD+SC+sag (2) 2,286.23 MWD+SC+sag (2) 2,306.90 MWD+SC+sag (2) 2,329.86 MWD+SC+sag (2) 2,352.98 MWD+SC+sag (2) 2,375.66 MWD+SC+sag (2) 2,398.97 MWD+SC+sag (2) 2,421.96 MWD+SC+sag (2) 2,444.37 MWD+SC+sag (2) 2,466.68 MWD+SC+sag (2) 2,489.47 MWD+SC+sag (2) 2,511.15 MWD+SC+sag (2) 2,533.74 MWD+SC+sag (2) 2,555.96 MWD+SC+sag (2) 2,577.13 MWD+SC+sag (2) 2,599.02 MWD+SC+sag (2) 2,620.31 MWD+SC+sag (2) 1212212015 3:41:39PM Page 5 COMPASS 5000.1 Build 73 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Happy Valley B-17 Project: Deep Creek Unit TVD Reference: HV B-17 @ 611.50usft (Saxon 169 (18+593.5)) Site: Happy Valley B Pad MD Reference: HV B-17 @ 611.50usft (Saxon 169 (18+593.5)) Well: Happy Valley B-17 North Reference: True Wellbore: HVB-17 Survey Calculation Method: Minimum Curvature Design: HVB-17 Database: Sperry EDM - NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/.W Northing Easting DLS Section (usft) V) 0 (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,371.39 20.59 11.70 7,894.23 7,282.73 2,601.36 488.49 2,193,536.18 224,169.56 1.17 2,642.10 MWD+SC+sag (2) 8,434.66 21.90 11.80 7,953.20 7,341.70 2,623.80 493.16 2,193,558.51 224,174.74 2.07 2,665.01 MWD+SC+sag (2) 8,496.29 21.61 11.61 8,010.44 7,398.94 2,646.17 497.80 2,193,580.77 224,179.89 0.48 2,687.83 MWD+SC+sag (2) 8,559.26 21.24 17.06 8,069.07 7,457.57 2,668.43 503.48 2,193,602.90 224,186.07 3.21 2,710.81 MWD+SC+sag (2) 8,620.48 19.53 23.01 8,126.46 7,514.96 2,688.46 510.73 2,193,622.75 224,193.78 4.39 2,731.99 MWD+SC+sag (2) 8,683.35 18.82 28.38 8,185.84 7,574.34 2,707.05 519.66 2,193,641.14 224,203.13 3.02 2,752.20 MWD+SC+sag (2) 8,745.08 18.72 28.07 8,244.29 7,632.79 2,724.55 529.05 2,193,658.42 224,212.92 0.23 2,771.46 MWD+SC+sag (2) 8,807.63 16.89 29.19 8,303.84 7,692.34 2,741.35 538.21 2,193,675.00 224,222.46 2.98 2,789.97 MWD+SC+sag (2) 8,870.88 16.60 28.58 8,364.41 7,752.91 2,757.30 547.01 2,193,690.75 224,231.63 0.54 2,807.59 MWD+SC+sag (2) 8,932.07 16.27 28.17 8,423.10 7,811.60 2,772.53 555.24 2,193,705.79 224,240.20 0.57 2,824.36 MWD+SC+sag (2) 8,992.96 16.07 28.82 8,481.58 7,870.08 2,787.44 563.33 2,193,720.50 224,248.63 0.44 2,840.78 MWD+SC+sag (2) 9,055.82 14.90 29.52 8,542.16 7,930.66 2,802.09 571.51 2,193,734.97 224,257.13 1.88 2,856.99 MWD+SC+sag (2) 9,118.70 15.71 27.52 8,602.81 7,991.31 2,816.68 579.42 2,193,749.37 224,265.38 1.54 2,873.06 MWD+SC+sag (2) 9,182.10 16.78 24.89 8,663.68 8,052.18 2,832.59 587.24 2,193,765.10 224,273.56 2.05 2,890.40 MWD+SC+sag (2) 9,246.52 16.22 24.12 8,725.44 8,113.94 2,849.24 594.83 2,193,781.57 224,281.53 0.93 2,908.39 MWD+SC+sag (2) 9,308.15 16.82 29.68 8,784.53 8,173.03 2,864.84 602.77 2,193,796.99 224,289.82 2.74 2,925.45 MWD+SC+sag (2) 9,373.57 15.85 30.59 8,847.31 8,235.81 2,880.76 612.00 2,193,812.69 224,299.41 1.53 2,943.13 MWD+SC+sag (2) 9,436.40 15.04 30.65 8,907.87 8,296.37 2,895.16 620.52 2,193,826.89 224,308.26 1.29 2,959.17 MWD+SC+sag (2) 9,499.49 16.36 29.71 8,968.61 8,357.11 2,909.92 629.10 2,193,841.45 224,317.17 2.13 2,975.57 MWD+SC+sag (2) 9,563.79 15.79 29.70 9,030.39 8,418.89 2,925.38 637.92 2,193,856.71 224,326.34 0.89 2,992.72 MWD+SC+sag (2) 9,626.73 16.95 30.19 9,090.78 8,479.28 2,940.75 646.78 2,193,871.87 224,335.55 1.86 3,009.78 MWD+SC+sag (2) 9,690.42 15.78 31.06 9,151.89 8,540.39 2,956.19 655.92 2,193,887.11 224,345.04 1.88 3,026.98 MWD+SC+sag (2) 9,753.37 16.52 29.71 9,212.35 8,600.85 2,971.30 664.77 2,193,902.01 224,354.23 1.32 3,043.78 MWD+SC+sag (2) 9,815.98 16.14 29.37 9,272.44 8,660.94 2,986.61 673.45 2,193,917.12 224,363.26 0.63 3,060.75 MWD+SC+sag (2) 9,880.91 17.54 27.81 9,334.58 8,723.08 3,003.13 682.44 2,193,933.43 224,372.62 2.27 3,078.96 MWD+SC+sag (2) 9,944.11 17.88 27.58 9,394.79 8,783.29 3,020.16 691.37 2,193,950.24 224,381.94 0.55 3,097.64 MWD+SC+sag (2) 10,005.84 18.01 27.63 9,453.51 8,842.01 3,037.01 700.19 2,193,966.89 224,391.14 0.21 3,116.13 MWD+SC+sag (2) 10,070.61 18.11 27.90 9,515.09 8,903.59 3,054.78 709.54 2,193,984.44 224,400.90 0.20 3,135.64 MWD+SC+sag (2) 10,133.49 16.61 33.11 9,575.11 8,963.61 3,070.95 719.02 2,194,000.39 224,410.75 3.43 3,153.62 MWD+SC+sag (2) 10,197.27 15.93 33.51 9,636.34 9,024.84 3,085.88 728.84 2,194,015.09 224,420.90 1.08 3,170.49 MWD+SC+sag (2) 10,259.89 16.62 30.70 9,696.45 9,084.95 3,100.75 738.15 2,194,029.74 224,430.55 1.67 3,187.18 MWD+SC+sag (2) 10,323.43 15.74 32.10 9,757.47 9,145.97 3,115.86 747.37 2,194,044.64 224,440.11 1.51 3,204.08 MWD+SC+sag (2) 10,387.44 15.38 32.49 9,819.13 9,207.63 3,130.37 756.54 2,194,058.95 224,449.61 0.59 3,220.39 MWD+SC+sag (2) 10,450.74 15.14 33.13 9,880.20 9,268.70 3,144.38 765.57 2,194,072.74 224,458.96 0.46 3,236.16 MWD+SC+sag (2) 10,513.67 14.48 34.17 9,941.04 9,329.54 3,157.77 774.48 2,194,085.92 224,468.17 1.13 3,251.32 MWD+SC+sag (2) 10,577.70 13.54 35.54 10,003.17 9,391.67 3,170.49 783.34 2,194,098.44 224,477.31 1.56 3,265.81 MWD+SC+sag (2) 10,641.17 12.58 38.25 10,065.00 9,453.50 3,181.97 791.93 2,194,109.72 224,486.17 1.79 3,279.03 MWD+SC+sag (2) 10,658.77 12.38 38.51 10,082.18 9,470.68 3,184.95 794.29 2,194,112.64 224,488.60 1.18 3,282.50 MWD+SC+sag (2) 10,695.00 12.38 38.51 10,117.57 9,506.07 3,191.03 799.13 2,194,118.61 224,493.57 0.00 3,289.57 PROJECTED to TD 1212212015 3:41:39PM Page 6 COMPASS 5000.1 Build 73 Company: Hilcorp Energy Company Project: Deep Creek Unit Site: Happy Valley B Pad Well: Happy Valley B-17 Wellbore: HVB-17 Design: HVB-17 Halliburton Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Happy Valley B-17 HV B-17 @ 611.50usft (Saxon 169 (18+593.5)) HV B-17 @ 611.50usft (Saxon 169 (18+593.5)) True Minimum Curvature Sperry EDM - NORTH US + CANADA brian.whmier@halliburton. cary.taylor@halliburton.c Checked B com Approved B " °" """"'" ° ° " Date: Y� PP Y� om �:�,��.:�� 12122/2015 3:41:39PM Page 7 COMPASS 5000.1 Build 73 HV B-17 FINAL Days vs Depth 0 HV B-17 Actual 1000 HV B-17 Plan 2000 3000 4000 5000 t CL a 6000 d N fp d 7000 8000 9000 10000 11000 12000 0 5 10 15 20 25 30 35 40 45 Days 1/21/2016 1:26 PM HV B-17 MW vs Depth 0 HV B-17 Plan 1000 HV B-17 Actual 2000 3000 4000 5000 a 6000 w 0 -a a �v 7000 a 8000 9000 10000 11000 12000 13000 8.0 9.0 10.0 11.0 12.0 13.0 14.0 Mud Density (ppg) Lease 8, Well No. Hilcorp Energy Company CASING & CEMENTING REPORT DCU HVB-17 Date Run 2 -Dec -1E County State AK Supv. R Pederson / S Barber Casing (Or Liner) Detail CASING RECORD Setting Depths Surface V Component TO 2,980.00 Shoe Depth: 2,970.00 PBTD: 2,884.00 No. Jts. Delivered 80 No. As. Run 72 No. As. Returned Ftg. Delivered Ftg. Run Ftg. Returned _ Length Measurements W/O Threads Ftg. Cut A. Ftg. Balance RKB 18.00 RKB to BHF RKB to CHF 22.14 RKB to THF 0 Csg W. On Hook: 110,000 Type Float Collar: 402 No. Hrs to Run: 10 Csg VW On Slips: Type of Shoe: Eccentric Casing Crew: Weatherford Rotate Csg Yes X No Recip Csg X Yes No Ft. Min. 9.4 PPG Fluid Description: Spud Mud Liner hanger Info (Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Floats Held _ Yes X No Centralizer Placement: Every other joint up to 234' CEMENTING REPORT Casing (Or Liner) Detail Shoe @ 2970.76 FC @ 2,884.11 Top of Liner Setting Depths Jts. Component Size W. Grade THD Make Length Bottom Top 1 Float Shoe 103/4 BTC Ray Oil Tools 2.22 2,970.76 2,968.54 2 Casing 95/8 40.0 L-80 BTC Tenaris 82.91 2,968.54 2,885.59 1 Float Collar 103/4 Type: Spud Mud Density (ppg) 9.4 Rate (bpm): 4 Volume (actual / calculated): 222/222 BTC Weatherford 1.48 2,885.59 2,884.11 70 Casing 95/8 40.0 L-80 BTC Tenaris 2,857.30 2,884.11 26.81 1 Casing Pup Joint 95/8 40.0 L-80 BTC Tenaris 3.54 26.81 23.27 1 Hanger 95/8 BTC I Seaboard 1 1.13 23.27 22.14 Csg W. On Hook: 110,000 Type Float Collar: 402 No. Hrs to Run: 10 Csg VW On Slips: Type of Shoe: Eccentric Casing Crew: Weatherford Rotate Csg Yes X No Recip Csg X Yes No Ft. Min. 9.4 PPG Fluid Description: Spud Mud Liner hanger Info (Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Floats Held _ Yes X No Centralizer Placement: Every other joint up to 234' VPD LL' LL +`l� Post Job Calculations: A� f Calculated Cmt Vol @ 0% excess: 181.5 Total Volume cmt Pumped: _ 1,! r. ✓ Cmt returned to surface: 103 Calculated cement left in wellbore: 202.4 OH volume Calculated: 160 OH volume actual: Actual % Washout: WELLHEAD Make Type Serial No. Size W. P. Test head to PSIG MIN OK Remarks: 305.4 www.wellez.net WellEz Information Management LLC ver 111815bf CEMENTING REPORT Shoe @ 2970.76 FC @ 2,884.11 Top of Liner Preflush (Spacer) Type: MudPush II Density (ppg) 10 Volume pumped (BBLs) 40.2 Lead Slurry Type: Class A Density (ppg) 12 Volume pumped (BBLs) 254.7 Mixing / Pumping Rate (bpm): 4.5 Tail Slurry w Type: Class A ¢ Density (ppg) 15.4 Volume pumped (BBLs) 50.7 Mixing /Pumping Rate (bpm): 2 F Post Flush (Spacer) z Type: Density (ppg) Rate (bpm): Volume: LL Displacement: Type: Spud Mud Density (ppg) 9.4 Rate (bpm): 4 Volume (actual / calculated): 222/222 FCP (psi): 1200 Pump used for disp: SLB Bump Plug? X Yes No Bump press 1720 Casing Rotated? Yes X No Reciprocated? X Yes No % Returns during job 100 1 0 _ Cement returns to surface? X Yes _ No Spacer returns? X Yes No Vol to Surf: 103 V Cement In Place At: 12:35 Date: 12/3/2015 Estimated TOC: 25 Method Used To Determine TOC: Returns at 4" Conductor Valves VPD LL' LL +`l� Post Job Calculations: A� f Calculated Cmt Vol @ 0% excess: 181.5 Total Volume cmt Pumped: _ 1,! r. ✓ Cmt returned to surface: 103 Calculated cement left in wellbore: 202.4 OH volume Calculated: 160 OH volume actual: Actual % Washout: WELLHEAD Make Type Serial No. Size W. P. Test head to PSIG MIN OK Remarks: 305.4 www.wellez.net WellEz Information Management LLC ver 111815bf Lease & Well No. Hilcorp Energy Company CASING & CEMENTING REPORT DCU HVB-17 Date Run 17 -Dec -15 County State AK Supv. S Hauck / M Rogers CASING RECORD Jts. Component Size Production V Grade THD TO 10,695.00 Shoe Depth: 10,631.58 PBTD: 10,544.00 No. Jts. Delivered No. Jts. Run 242 No. Jts. Returned Ftg. Delivered Ftg. Run 10,606.84 Ftg. Returned Length Measurements W/0 Threads Fig. Cut Jt. Ftg. Balance 2 5.5 csg RKB 18.00 RKB to BHF RKB to CHF 22.14 RKB to THF w Csg M. On Hook: 163,655 Type Float Collar: Float Collar No. Hrs to Run: 22 Csg Wt. On Slips: 65 Type of Shoe: Reamer shoe Casing Crew: WOT Rotate Csg Yes X No Recip Csg X Yes No 8 Ft. Min. 9.7 PPG Fluid Description: KCL polymer Liner hanger Info (Make/Model): NA Liner top Packer?: _Yes X No Liner hanger test pressure: Floats Held X Yes _ No Centralizer Placement: Run 2 on shoe track and every other jt to 3014'. 88 total. CEMENTING REPORT Casing (Or Liner) Detail Setting Depths Jts. Component Size W. Grade THD Make Length Bottom Top Shoe 73/4 17.0 P110 Geo Conn WOT 3.10 10,631.58 10,628.48 2 5.5 csg 51/2 17.0 P110 Geo Conn w 82.72 10,628.48 10,545.76 FDensity Float Collar 6 17.0 P110 Geo Conn WOT 1.31 10,545.76 10,544.45 194 5.5 csg 51/2 17.0 P110 Geo Conn 8,499.82 10,544.45 2,046.63 1 Swell packer 73/4 P110 Geo Conn BOT 20.84 2,046.63 1 2,025.79 46 5.5 csg 1 51/2 1 17.0 P110 Geo Conn Method Used To Determine TOC: 2,005.65 2,025.79 24.74 1 Hanger & pup C- TCC 17.0 P110 Geo Conn 4.60 24.74 20.14 1 RKB 51/2 17.0 P110 20.14 20.14 Csg M. On Hook: 163,655 Type Float Collar: Float Collar No. Hrs to Run: 22 Csg Wt. On Slips: 65 Type of Shoe: Reamer shoe Casing Crew: WOT Rotate Csg Yes X No Recip Csg X Yes No 8 Ft. Min. 9.7 PPG Fluid Description: KCL polymer Liner hanger Info (Make/Model): NA Liner top Packer?: _Yes X No Liner hanger test pressure: Floats Held X Yes _ No Centralizer Placement: Run 2 on shoe track and every other jt to 3014'. 88 total. Calculated Cmt Vol @ 0% excess: 422 Total Volume cmt Pumped: 490 Cmt returned to surface: 0 Calculated cement left in wellbore: 490 OH volume Calculated: 312 OH volume actual: 421 Actual % Washout: 35 Make Seaboard Size 11 Test head to Remarks: 5000 WELLHEAD Type multi W. P. 5000 PSIG 5 www.wellez.net WellEz Information Serial No. 214755 MIN yes OK LLC ver 111815bf CEMENTING REPORT Shoe @ 10631 FC @ 10,544.00 Top of Liner Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type: EZ Bloc Density (ppg) 15.3 Volume pumped (BBLs) 490 Mixing / Pumping Rate (bpm): 5 Tail Slurry w Type: FDensity (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): y 'OSE, lush (Spacer) f Type: Density (ppg) Rate (bpm): Volume: LL Displacement: Type: 3% KCL Density (ppg) 8.4 Rate (bpm): 6 Volume (actual / calculated): 245/245.6 FCP (psi): 3300 Pump used for disp: Cement unit Bump Plug? X Yes No Bump press 3800 Casing Rotated? Yes X No Reciprocated? X Yes _ No % Returns during job 98 Cement returns to surface? Yes X No Spacer returns? _ Yes X No Vol to Surf: 0 Cement In Place At: 3:53 Date: 12/19/2015 Estimated TOC: 2,000 Method Used To Determine TOC: lift pressure C- TCC Post Job Calculations: Calculated Cmt Vol @ 0% excess: 422 Total Volume cmt Pumped: 490 Cmt returned to surface: 0 Calculated cement left in wellbore: 490 OH volume Calculated: 312 OH volume actual: 421 Actual % Washout: 35 Make Seaboard Size 11 Test head to Remarks: 5000 WELLHEAD Type multi W. P. 5000 PSIG 5 www.wellez.net WellEz Information Serial No. 214755 MIN yes OK LLC ver 111815bf THE STATE of ALASKA GOVERNOR BILL WALKER Monty Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Happy Valley Field, HV Beluga/Tyonek Gas Pool, HV B-17 Hilcorp Alaska, LLC Permit No: 215-189 Surface Location: 2947' FNL, 406' FEL, SEC. 21, T2S, R13W, SM, AK Bottomhole Location: 251' FSL, 403' FWL, SEC. 15, T2S, R1 3W, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with Conservation Order 553 and 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. Hilcorp Alaska, LLC assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Phi Cathy P. oerster Chair DATED this ZCL day of October, 2015. STATE OF ALASKA A, A OIL AND GAS CONSERVATION COMMIL PERMIT TO DRILL 20 AAC 25.005 RECEI'v=L OCT I r 2015 1 a. Type of Work: Drill • ❑✓ Lateral ❑ 1b. Proposed Well Class: Development -Oil ❑ Service - Winj ❑ Single Zone 0 • Stratigraphic Test ❑ Development - Gas. Q ° Service - Supply ❑ Multiple Zone ❑ 1 c. Specify if well is oroposed for: 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. 022035244 • HV B-17 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 10,694' • TVD: 10,111' Happy Valley Field HV Beluga/Tyonek Gas Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: ' 2947' FNL, 406' FEL, Sec 21, T2S, R13W, SM, AK • C061589, C061590, C061588 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 1192' FNL, 33' FEL, Sec 21, T2S, R13W, SM, AK N/A 11/10/2015 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 251' FSL, 403' FWL, Sec 15, T2S, R13W, SM, AK 8,354.48 Total Acres 5,346' to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 611.5 feet • 15. Distance to Nearest Well Open Surface: x- 223621.8 . y- 2190946.6 • Zone -4 GL Elevation above MSL: 593.5 feet • to Same Pool: 900' from HV B-12 16. Deviated wells: Kickoff depth: 600 feet Maximum Hole Angle: 20.89 degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2 psi Ps" Surface: >7 psi 3:;s 7 �. 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) Cond 16" 109# X-56 Weld 120' Surf Surf 120' 120' Driven 12-1/4" 9-5/8" 40# L-80 BTC 3,000' Surf Surf 3,000' 2,873' L -1205.4 ft3 / T - 269 ft3 8-1/2" 5-1/2" 17# P-110 GeoConn 10,694' Surf Surf 10,694' 10,111' 2532.4 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): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner 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 Q 20 AAC 25.050 requirementss0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and correct. Contact Monty Myers Email mm ers hilcor .com Printed Name Monty Myers Title Drilling Engineer Signature Phone 907-777-8431 Date 10/16/2015 Commission Use Only Permit to Drill / -- ,�?%� Number: API Number: 50- Permit Approval Date: 1O I I I �5 irequirements. See cover letter for other Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Q Other: 15�� St ©p Samples req'd: Yes ❑ Nn[J' Mud log req'd: Yes❑ NoQ `� C(/ �;e ss HzS measures: Yes ❑ Nn� Directional svy req'd: Yes® Nn❑ aso o �S� A, 1 .:, F Spacing exception req'd: Yes: ❑ M:) V)J Inclination -only svy req'd: Yes❑ ND 1M �x�eP.f�©v� Ke -e -4e -a j* c 131- 4: M tT- (A tel o� d---4 'Qj P -:e>('. Approved by: APPROVED BY �_ COMMISSIONER THE COMMISSION Date: ( J 0 Rhl- uNA�Submit Form and Form 10-401 (Revised 10/2012) t 1 r nths from the date of approval (20 AAC 25.005(8)) Attachments in Duplicate �,-- .�(� 2- J Monty Myers Drilling Engineer Hilcorp Energy Company 10/16/2015 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Happy Valley B-17 Permit to Drill Dear Commissioner, Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com �J C � 16 2015 HV B-17 is a build and hold directional grassroots development well to be drilled off of the Happy Valley B pad. Reservoir analysis and subsurface mapping has identified an optimal location for infill development of the Middle Tyonek sands. Primary undepleted reservoir objectives are Lower Beluga, Upper Tyonek, T-40, T-80 and T-155 sands. The base plan is a directional wellbore with a kick off point at 600' MD. Maximum hole angle will be 21 deg. and TD of the well will be 10,694' TMD/ 10,111' TVD, ending with 16 deg inclination left in the hole. Vertical section will be 3279 ft. Drilling operations are expected to commence approximately November 10th 2015. The Saxon Rig # 169 will be used to drill the wellbore then run casing and cement. 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 Hilcorp Alaska, LLC Happy Valley B-17 Drilling Program Deep Creek Unit Rev 0 October 16th, 2015 ff Hi1mTEnergy Company Contents HV B-17 Drilling Procedure 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" Conductor Riser..............................................................................................................11 11.0 Drill 12-1/4" Hole Section.............................................................................................................13 12.0 Run 9-5/8" Surface Casing...........................................................................................................17 13.0 Cement 9-5/8" Surface Casing.....................................................................................................20 14.0 BOP NIU and Test.........................................................................................................................23 15.0 Drill 8-1/2" Hole Section...............................................................................................................24 16.0 Run 5-1/2" Production Casing.....................................................................................................29 17.0 Cement 5-1/2" Production Casing...............................................................................................32 18.0 RDMO............................................................................................................................................35 19.0 BOP Schematic..............................................................................................................................36 20.0 Wellhead Schematic......................................................................................................................37 21.0 Days Vs Depth................................................................................................................................38 22.0 Geo-Prog.........................................................................................................................................39 23.0 Anticipated Drilling Hazards.......................................................................................................40 24.0 Saxon Rig 169 Layout...................................................................................................................42 25.0 FIT Procedure................................................................................................................................43 26.0 Choke Manifold Schematic...........................................................................................................44 27.0 Casing Design Information...........................................................................................................45 28.0 8-1/2" Hole Section MASP............................................................................................................46 29.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................47 30.0 Surface Plat (NAD 27)...................................................................................................................48 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 1.0 Well Summary Well Happy Valle B-17 Pad & Old Well Designation HV B-17 is a rass roots well on Happy Valley B Pad . Planned Completion Type 5-1/2" Production tubing Target Reservoir(s) Belu a/T onek Planned Well TD, MD / TVD 10,694 MD / 10,111' TVD PBTD, MD / TVD 10,500' MD / 9,926' TVD Surface Location (Governmental) 2947' FNL, 406' FEL, Sec 21, T2S, R13W, SM, AK Surface Location (NAD 27) X=223621.857, Y=2190946.644• Surface Location (NAD 83) Top of Productive Horizon (Governmental) 1192' FNL, 33' FEL, Sec 21, T2S, R13W, SM, AK TPH Location (NAD 27) X=224027.43 Y=2192693.66 TPH Location (NAD 83) BHL (Governmental) 251' FSL, 403' FWL, Sec 15, T2S, R13W, SM, AK BHL (NAD 27) X=224494.47, Y=2194126.88 BHL (NAD 83) AFE Number 1512577D AFE Drilling Das 4 MOB, 17 DRLG AFE Completion Days AFE Drilling Amount $3,608,172 AFE Completion Amount $400,000 Maximum Anticipated Pressure (Surface) 1742 psi Maximum Anticipated Pressure (Downhole/Reservoir) 2500 psi Work String 4-1/2" 16.6# S-135 CDS-40 Saxon Owned String) RKB — GL 611.5'(593.5 + 18) Ground Elevation 593.5' BOP Equipment 11" 5M T3 -Energy Annular BOP 11" 5M T3 -Energy Double Ram 11" 5M T3 -Energy Single Ram Page 2 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Changes to Approved Permit to Drill Date: 10-12-2015 Subject: Changes to Approved Permit to Drill for Happy Valley B-17 File #: HV B-17 Drilling Program Any modifications to HV B-17 Drilling Program will be documented and approved below. Changes to an approved APD will be communicated to and approved in advance by the AOGCC. Approval: Prepared: re Drilling Manager Date Drilling Engineer Date Page 3 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 3.0 Tubular Program: Hole Section OD (in) ID (in) Drift (in) Conn OD (in)(#/ft) Wt Grade Conn Burst (psi) Collapse (psi) Tension k -lbs) Cond 16" 15" - - 109 X-56 Weld - - - 12-1/4" 9-5/8" 8.835" 8.679" 10.625" 40 L-80 BTC 5750 3090 916 8-1/2" 5-1/2" 4.892" 4.767" 6.050" 17 P-110 GeoConn 10640 7470 568 4.0 Drill Pipe Information: Hole OD (in) Section ID (in) TJ ID in TJ OD in(#/ft) Wt Grade Conn Burst (psi) Collapse (psi) Tension (k -lbs) All 4-1/2" 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). M Page 4 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hi1COIp Energy Company 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 RmazzoliniAhilcorp.com , lkellerghilcorp.com , mm ersghilcorp.com and cdingerghilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by lam 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. This could be one of (3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. John Coston: O: (907) 777-6726 C: (907) 227-3189 b. Mark Tornai: O: (907) 283-1372 C: (907) 748-3299 c. Thad Eby: O: (907) 777-8317 C: (907) 602-5178 2. Spills: Julieanna Orczewska: 0:907-777-8444 C:907-715-7060 • Notify Drlg Manager 1. Paul Mazzolini: O: 907-777-8369 C: 907-317-1275 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As -Run" Casing tally to mmyers@hilcorp.com and cdingerghilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to mmyers@hilcorp.com and cdingerAhilcorp.com Page 5 Version 0 October, 2015 U Hilcorp Energy Company 6.0 Planned Wellbore Schematic n PROPOSED 16" 12-1/4" Hole CASING DETAIL HV B-17 Drilling Procedure Rev 0 Deep Creek Unft We!3 Happy VaRey B-17 PTD: 000-000 API: 50-000-00000-00 Drilling Info Hole Section Casing MIA, Work -string 12-1/4" 9-5/8-- 8.8 PPg 4-1/2" 8-1/2" 5-1/2" 9.0-10.5 ppg 4-1/2" JEWELRY DETAIL No. [�Depth —f' Belun 135 Item I 2,000' 4.992" Mud Size Type Wt Grade Conn- ID Top I Btm Weight Conductor Hole 161, — Driven 84 J-55 Weld 15.01" Surf 120' N/A to Set Depth T-90 i:2 9-5" Surf Csg 0 L-80 BTC 8.835" Surf U00' . 8.8 Ppg �1/2"" Prod Csg 107] P-110 GeoConn 4.892" Surf 10,694' . 9.5 ppg Drilling Info Hole Section Casing MIA, Work -string 12-1/4" 9-5/8-- 8.8 PPg 4-1/2" 8-1/2" 5-1/2" 9.0-10.5 ppg 4-1/2" JEWELRY DETAIL No. [�Depth —f' Belun 135 Item I 2,000' 4.992" 8.681" Baker Swell Packer Tvonel Hole T-90 i:2 T-120 - i�t T-155 54/2" Al PHTD =10,549' PBT% -D = 9,9276' TD=10,ff4'1-n7D=10j11' Drilling Info Hole Section Casing MIA, Work -string 12-1/4" 9-5/8-- 8.8 PPg 4-1/2" 8-1/2" 5-1/2" 9.0-10.5 ppg 4-1/2" JEWELRY DETAIL No. [�Depth ID OD Item I 2,000' 4.992" 8.681" Baker Swell Packer Page 6 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 7.0 Drilling / Completion Summary HV B-17 is a build and hold directional grassroots development well to be drilled off of the Happy Valley B pad. Reservoir analysis and subsurface mapping has identified an optimal location for infill development of the Middle Tyonek sands. Primary undepleted reservoir objectives are Lower Beluga, Upper Tyonek, T-40, T-80 and T-155 sands. The base plan is a directional wellbore with a kick off point at 600' MD. Maximum hole angle will be 21 deg. and TD of the well will be 10,694' TMD/ 10,111' TVD, ending with 16 deg inclination left in the hole. Vertical section will be 3279 ft. Drilling operations are expected to commence approximately November 10th 2015. The Saxon Rig # 169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 3,000 MD / 2,873' TVD and cemented to surface to ensure protection of any shallow freshwater 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 the AOGCC. 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. General sequence of operations: 1. MOB Saxon Rig # 169 to well site 2. N/U conductor riser. (No diverter, diverter waiver requested) f 3. Drill 12-1/4" hole to 3000' MD. Run and cmt 9-5/8" surface casing. 4. ND conductor riser, N/U & test 11" x 5M T3 -Energy BOP. 5. Drill 8-1/2" hole section to 10,694' MD. Perform Wiper trip. 6. Perform RFT logging 7. POOH laying down drill pipe. 8. Run and cmt 5-1/2" production casing. 9. N/D BOP, N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: GR + Res LWD. 2. Production Hole: GR + Res + Den/Neu LWD. 3. Mud loggers from surface casing point to TD. Page 7 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 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 of HV B-17. Ensure to provide AOGCC 24 hrs notice prior to testing BOPS. • The initial test of BOP equipment will be to 250/4500 psi & subsequent tests of the BOP equipment will be to 250/4500 psi for 10/10 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 both AOGCC approved drilling permit and BLM sundry are posted on the rig floor and in Co Man office. Regulation Variance Requests: Diverter waiver requested due to the recent drilling of Happy Valley B 16 nearby (-115' away). No issues were experienced while drilling the surface hole. Surface casing for HV B-16 was set at 1052' TMD and Intermediate was set at 4507'TMD.The surface section was TD'd with a 9.2 ppg and no gas shows and the intermediate section was drilled to 3000' TMD with no gas shows and between a 9.2 and 9.6 ppg mud. Surface casing for HV B-17 is requested to be set at 3,000' TMD (2,873' TVD). No shallow hydrocarbon zones will be penetrated. Page 8 Version 0 October, 2015 HiICOIp EneW Company Summary of BOP Equipment and Test Requirements HV B-17 Drilling Procedure Rev 0 Hole Section Equipment Test Pressure(psi) 12-1/4" • No diverter utilized n/a • 11" x 5M T3 -Energy (Model 7082) Annular BOP • 11" x 5M T3 -Energy Double Ram Initial Test: 250/4500 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 8-1/2" 11" x 5M T-3 Energy Single Ram • 3-1/8" 5M Choke Line Subsequent Tests: • 2-1/16" x 5M Kill line 250/4500 • 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. Additional requirements may be stipulated on APD and Sundry. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: jimxe,gg(a alaska.gov Guy Schwartz / Petroleum Engineer/ (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotifhtml Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Enema Company 9.0 R/U and Preparatory Work 9.1 Set 16" conductor at +/-120' below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 18-1/2" 3M "A" section. 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 Mud loggers not required on surface hole section. 9.8 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 12-1/4" hole section. 9.10 Install 5-1/2" liners in mud pumps. • HHF 1000 mud pumps are rated at 3572 psi (100%) / 339 gpm (100%) at 110 spm with 5-1/2" liners. Page 10 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 10.0 N/U 16" Conductor Riser 10.1 NIU 16" 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 wearbushing in wellhead. V' Page 11 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 10.3 Rig Orientation on Happy Valley B pad: Page 12 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp EneW Company 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" 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. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 4.5" 16.6# S-135 CDS40 11.2 12-1/4" BHA (GR and Res are included in below BHA): COMPONENT Kern DATA Description .� Number ID Gauge Weight ,.Length Top Length Cumutatt" 1 Trioone 8.000 3.000 12.250 147.22 P 6-518" REG 1.00 1.00 2 8" Sper yDrill Lobe 415 - 5.3 stg 8.000 5.000 121.08 B 6-518" REG 32.00 33.00 Stabilizer 12.125 3 8" Integral Blade Stabilizer 8.000 2.830 12.125 149.87 B 6-5/8" REG 4.00 37.00 4 8" DM (Directional) 8,000 3.500 147.40 B 6-518" REG 9.20 46.20 5 8" DGR (Gamma Ray) 8.000 1.920 142.70 B 6-518" REG 4.55 5075 6 8" EWR-P4 (Resistivity) 8.000 2.000 151.00 B 6-518" REG 12.19 62.94 7 8" HUM (Processor) 8.000 1.920 149.90 B 6-518" REG 4.97 67.91 8 1 8"TM HOC (Pulses) 8.000 4.000 145.20 B 6-518" REG 9.44 77.35 9 8" NonMag Flex Collar 8.000 2.813 150.12 B 6-518" REG 30.00 107.35 10 8` NonMag Flex Collar 8.000 2.813 150.12 8 6-518" REG 30.00 137.35 11 X-0 6-518" Reg P X 4-112" IF B 7.375 2.875 123.46 B 4-112" IF 3.00 140.35 12 7-314" Jar 7.750 3.000 136.68 B 4-112" IF 30.00 170.35 13 2 As 5" X 3' HWDP #49.3 - 4.5"IF 5.000 3.000 49.30 60.00 230.35 14 X -O 4-1F2' IF P X CDS40 B 6.500 2.750 92.85 B 4. " DS 3.00 233.35 1 15 6 As 4-1d7 HWDP CDS-40 4.500 2.813 39.86 360.00 593.35 593.35 Page 13 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 11.3 Primary Bit: Engineered Cutting Structure PRODUCT SPECIFICATIONS Gage Teeth: 32 Total Teeth: 66 Back Row: SRT Gage Row: Full Cap Inner Row: Full Cap Bearing Type: Sealed Journal Seal Type: HSN O -Ring Hydraulic Design: Standard nozzles and center jet Nozzle Part No.: 6703 Center Jet Part No.: 12400 Pin Connection: 6 518" API Regular Make-up Torque: 28000 - 32000 ft -lbs. (37963 - 43386 Nm) Approx. Weight: 222 lbs. (101 kg) RECOMMENDED OPERATING PARAMETERS Rotary Speed: 50 - 3(30 RPM Weight On Bit: 18,375 - 61,254 lbs (8,174 - 27,245 daN) Flowrate. Min:Max 490 - 1041.25 Gpm (1.85 - 3.54 ml/min) High extension bailing resistant cutting structure with milled teeth and full cap premium tooth hardmetat for high penetration rates and long life in soft. abrasive formations. Carbide inserts provide enhanced gage holding. Premium Bearing Package High performance journal bearing with silver plated floating elements, advanced lubricant, and HSN O-ring seal provides a robust bearing package for both motor and standard rotary applications. Shirttail Protection Special shirttail edge contouring around the seal area prevents shale packing and prolongs bearing life. A very generous application of hardmetal applied to the shirttail edge and leading edge of the bit leg. Hardmetal and ovoid shaped tungsten carbide inserts up the leg and below the reservoir provide near gage stabilization and enhanced performance in directional applications or where hole swelling is a factor. Page 14 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 11.4 4-1/2" Workstring & HWDP will come from Saxon. Jars will come from Weatherford. 11.5 Begin drilling out from 16" conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 12-1/4" hole section to 3,000' MD/ 2,873' TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 - 550 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. • 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. • TD the hole section in a good shale between 2800' MD and 3000' MD. . • Take MWD surveys every stand drilled (60' intervals). Page 15 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcoitp Energy Company 11.7 12-1/4" 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 — 9.5 ppg Pre -Hydrated Aquagel/freshwater spud mud Properties: De the Densit Viscosit Plastic Viscosity Yield Point AN FL H 120-3000' 8.8-9.5-1;/85-150 0.1 ppb (9 pH) 1 20-40 25-45 1 <10 8.5-9.0 System Formulation: Aquagel + FW spud mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 12-15 ppb caustic soda 0.1 ppb (9 pH) BARAZAN D+ as needed BAROID 41 as required for weight PAC -L /DEXTRID LT if required for <12 FL ALDACIDE G 0.1 ppb X -TEND 11 0.02 ppb 11.8 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. 11.9 TOH with the drilling assy, handle BHA as appropriate. 11.10 No open hole logs are planned for the 12-1/4" hole section. Page 16 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 9-5/8" casing running equipment. • Ensure 9-5/8" 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 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) £(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 9-5/8" 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. • 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. 9-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 9-5/8" 9,630 ft -lbs Page 17 Version 0 October, 2015 0 Hilcorp Energy Company HV B-17 Drilling Procedure Rev 0 Tenaris Casing and Tubing Performance Data Choose pipe size, wall thickness and steed grade to view API connection options and performance data. Pipe Body Data GEOMETRY Nominal OD 9.625 in Nominal Weight 40.00 lbstft Plain End Weight 38.97 lbstft PERFORMANCE Wall Thickness 0.395 in API Drift Diameter Nominal ID 8.835 in Alternate Drift Diameter Nominal Cross Section 11.454 sq in 8.679 in 8.75 in Steel Grade L80 Body Yield Strength 916,000 lbs Minimum Yield 80,000 psi Minimum Ultimate Internal Yield Pressure 5,750 psi Collapse Pressure 95,000 psi 3,080 psi Connection Data GEOMETRY Regular OD 10.625 in PERFORMANCE Threads Per Inch 5 Make -Up Thread Tums 1 Steel Grade LBO Joint Strength 947,000 lbs Minimum Yield 80,000 psi Minimum Ultimate Internal Pressure 5,750 psi Resistance 95,000 psi Print enansHvdril Premium erections Ver 8.6 Contact Us 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 18 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 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. Page 19 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp EneW Company 13.0 Cement 9-5/8" 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. • Pump 20 bbls of freshwater through all of Schlumberger's equipment, taking returns to cuttings bin, prior to pumping any fluid downhole • How to handle cmt returns at surface. • 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. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.5 Pump remaining 30 bbls of 10 ppg spacer. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 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 BLS Vol ft3 12.0 ppg LEAD: 120' x .129 bpf = 15.5 87 16" Conductor x 9-5/8" casing annulus: 12.0 ppg LEAD: (2500' — 120') x.0558 bpf x 199.2 1118.4 12-1/4" OH x 9-5/8" 1.5— .5—Casing Casingannulus: Total LEAD: 214.7 1205.4 ft3 15.4 ppg TAIL: (2500'-3000') x.0558 bpf x 41.9 235 12-1/4" OH x 9-5/8" 1.5— .5—Casing Casingannulus: 15.4 ppg TAIL: 80 x.0758 bpf = 6.1 34.5 9-5/8" Shoe track: Total TAIL: 48 bbl 269 ft3 Page 20 Version 0 October, 2015 Z Z'c, sR Cement Slurry Design: HV B-17 Drilling Procedure Rev 0 13.8 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. 13.9 After pumping cement, drop top plug and displace cement with spud mud. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 3000'- 80' = 2920' x.0758 bpf = 221 bbls t` 13.12 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. Page 21 Version 0 October, 2015 Lead Slurry (2500' MD to surface) Tail Slurry (2500' to 3000' MD) System Extended Conventional Density 12 Ib/gal 15.4 Ib/gal Yield 2.46 ft3/sk v 1.22 ft3/sk Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk Code Description Concentration Code Description Concentration G Cement 94#/sk A Cement 94#/sk D110 Retarder 0.15 gal/sk BWOC D046 Anti Foam 0.2 % BWOC Additives D046 Anti Foam 0.2 % BWOC D065 Dispersant 0.4 % BWOC D079 Extender 2.0 % BWOC 5002 CaC12 0.35 % BWOC D020 Extender 3.0 % BWOC D177 CaC12 0.1 % BWOC 13.8 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. 13.9 After pumping cement, drop top plug and displace cement with spud mud. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 3000'- 80' = 2920' x.0758 bpf = 221 bbls t` 13.12 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. Page 21 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 13.13 Do not overdisplace by more than'/2 shoe track volume. Total volume in shoe track is 3.7 bbls. Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 12 — 18 hours after CIP. Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5". 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 cdingerkhilcorp.com and mmyerskhilcorp. com. This will be included with the EOW documentation that goes to the AOGCC. Page 22 Version 0 October, 2015 in Hilcorp Energy Company 14.0 BOP N/U and Test HV B-17 EDrilling Procedure Rev 0 14.1 N/U Seaboard multi -bowl wellhead assy. Install 9-5/8" packoff P -seals. Test to 3000 psi. 14.2 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 601 li 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 (2) manual valves & a check valve on kill side of mud cross. • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. �L t;�"J ��✓ , 2-ct k .may 14.3 Run 4-1/2" BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/4500 psi for 10/10 min. Test annular to 250/2500 psi for 10/10 min. • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.4 R/D BOP test assy. 14.5 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.6 Mix 9.0 ppg 6% KCL PHPA mud system. 14.7 R/U mud loggers for production hole section. 14.8 Rack back as much 4-1/2" DP in derrick as possible to be used while drilling the hole section. r` Page 23 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 15.0 Drill 8-1/2" Hole Section 15.1 Pull test plug, run and set wear bushing 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TIH, Conduct shallow hole test of MWD and confirm Gamma Ray and Resistivity LWD functioning properly. 15.5 Ensure TF offset is measured accurately and entered correctly into the MWD software. 15.6 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.7 Workstring will be 4.5" 16.6# S-135 CDS40. Ensure to have enough 4-1/2" DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. Page 24 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp En"" Company 15.8 8-1/2" BHA: COMPONENT 1 DATA 8.5" PDC .D 6.000 tD 3.000 Gauge weight (tbpf) 8.500 72.27 TOP Connection P 4-112" REG Length (ft) 0.80 Cofto* Length (ft) A� 0.80 2 7" SperryDrill Lobe 718 - 7.5 stg 7.000 4.952 95.69 B 4-112" IF 31.53 32.33 3 Float Sub 6.750 2.500 105.23 B 4-112" IF 2.75 35.08 4 6 3/4" DM (Directional) 6.750 3.125 103.40 B 4-112" IF 9.20 44.28 5 6 314" DGR (Gamma) 6.750 1.920 1 97.80 1 B 4-112" IF 6.40 50.68 6 6 314" EWR-P4 (Resistivity) 6.750 2.000 104.30 B 4-112" IF 12.10 62.78 7 6 314" HUM (Processor) 6.750 1.920 101.70 B 4-112" IF 6,80 69.58 8 6 314" TM (Telemetry) 6.900 3.250 103.60 B 4-112" IF 10.00 79.58 9 6-314" Flex Collar 6.750 2.875 99.83 B 4-112" IF 30.00 109.58 10 6-314" Flex Collar 2.875 99.83 B 4-112" IF 30.00 139.58 11 6-314" Flex Collar 6.750 2.875 99.83 B 4-112" IF 30.00 169.58 12 6-314" Flex Collar 6.750 2.875 99.83 B 4-112" IF 30.00 199.58 13 4-112" IF P x CDS-40 Box 6.350 2.625 89.48 B 4.5" CDS40 2.75 202.33 14 2jts 4-112" CDS-40 HWDP 4.500 2.813 36.86 60.00 262.33 15 CDS-40 P x 4-1/2" IF Bax 6.550 2.685 95.54 B 4-112" IF 2.75 265.08 16 6.25" Weatherford Jar 6.237 2.250 90.57 B 4-112" IF 32.00 297.08 17 4-112" IF P x CDS-40 Box 6.190 2.685 8326 B 4.5" CDS40 2.75 299.83 18 15its 4-1f2" CDS-4O HWDP 4.500 2.813 36.86 1 450.00 749.83 .. 749.83 Page 25 Version 0 October, 2015 Hilcorp Energy Company 15.9 Primary Bit: Assembly: AM90 Tool#: T10998 IADC Code: M232 PRODUCT SPECIFICATIONS Cutter Size: Cutter Back Up: Total Cutter Count: Face Cutter Count: Connection: Nozzle 1 Qty/Type: Nozzle 2 QtylType: Junk Slot Area: Gage Pad Length: Make Up Length: Shank Diameter: OPERATING PARAMETERS" HV B-17 Drilling Procedure Rev 0 voyager 13 mm 33 28 4 112" API Regular 7 - Series 65 16.1 in= (103.9cm2) 2" (51 mm) 9.7" (247.1 mm) 5.9" (149.9mm) Rotary Speed: For all rotary and motor applications Flowrate Min -Max: 250 - 750GPM (0.95 - 2.84mllmin) Max Weight On Bit: 29,000lbs (12900daN) Makeup Torque: 12,000 - 16,000Ft-Lbs. (16270 - 21693Nm) -OPcra1t0 Wrame?er. sf— are tyr—g fa thx 6d[ Frire .Cti":laeo Fu nn yc- sr—Ac a�y^ErGa: xi_ ccrnac} yras +arc? �.n1—.Wa-,a# rcF*e.cf attve. Voyager Series faits - Voyager series bits utilize Varei's proprietary design.. modeling, and programming software coupled with specialized manufacturing techniques to create the optimal drill bit for your fit -for -purpose applications Engineered though Varel Simulator Suite for specific directional applications, Voyager bits incorporate the latest design features to maximize cuttings removal, enhance ROP potential, improve directional response, and create a more durable bit frame to aid in accomplishing your aggressive directional drilling objectives. Bit Features G - The premium gage consists of thermally stable polycrystalline diamond, and is designed to insure that correct hole diameter is maintained. H - Increased number of nozzles for improved bit cleaning V'AR EL inr i rrvn r rnra n. Page 26 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilco p En -V Company 15.10 8-1/2" hole section mud program summary: Weighting material to be used for the hole section will be salt and calcium carbonate. Additional calcium carbonate 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 ppg 6% KCL PHPA fresh water based drilling fluid. Properties: MD 1Viud-\\\ Weight Viscosity Plastic Viscosity yield Point pH HPHT 3,000'- 10,694 1. 9.0-10.0 , 40-53 15-25 15-25 8.5-9.5 < 11.0 System Formulation: 6% KCL EZ Mud DP 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) EZ MUD DP 0.75 ppb (initially 0.25 ppb) DEXTRID LT 1-2 ppb PAC -L I ppb BARACARB 5/25/50 15 - 20 ppb (5 ppb of each) BAROID 41 as required for a 9.0 — 10.0 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb maintain per dilution rate 15.11 TIH w/ 8-1/2" directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.12 R/U and test casing to 3000 psi430 min. Ensure to record volume / pressure and plot on FIT graph. AOGCC requirement is 50% of burst. 9-5/8" burst is 5750 psi / 2 = 2875 psi. 15.13 Drill out shoe track and 20' of new formation. 15.14 CBU and condition mud for FIT. Page 27 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 15.15 Conduct FIT to 12.0 ppg EMW. Note: Offset field test data predicts frac gradient at the 9-5/8 " shoe to be between 11 - 13 ppg EMW. An 12.5 ppg FIT results in a 3 ppg kick margin while drilling with the planned MW of 9.5 ppg. J- 15.16 15.16 Drill 8-1/2" hole section to 10,694' MD / 10,111' TVD • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 225 - 300 gpm. Ensure shaker screens are set up to handle this flowrate. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' 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 HTHP fluid loss < 10. • Take MWD surveys every other stand drilled. Surveys can be taken more frequently if deemed necessary. • Take (3) sets of formation samples every 20'. Mud loggers should compile Pixler plots and QFT 2 analysis for Lower Tyonek to total depth. 15.17 At TD; pump sweeps, CBU, and pull a wiper trip back to the 9-5/8" shoe. 15.18 TOH with the drilling assy, standing back drill pipe. 15.19 LD BHA, RU E -line to perform RFT logging run and log well. . 15.20 RD loggers, PU 8-1/2"clean out BHA, and TIH to TD. 15.21 Pump sweep, CBU and condition mud for casing run. 15.22 POOH LDDP and BHA 15.23 Install 4-1/2" pipe rams in BOP stack and RU and test. Page 28 Version 0 October, 2015 16.0 Run 5-1/2" Production Casing HV B-17 Drilling Procedure Rev 0 16.1. R/U Weatherford 5-1/2" casing running equipment. • Ensure 5-1/2" GeoConn x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted prior to running. • Be sure to count the total # of joints 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. 16.2. P/U shoe joint, visually verify no debris inside joint. 16.3. 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). • Solid body centralizers will be pre-installed on shoe joint an FC joint. • Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe and float collar. • Utilize a collar clamp until weight is sufficient to keep slips set properly 16.4. Continue running 5-1/2" production 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 across zones of interest, TBD after LWD. Install solid body centralizers on every other joint to 9-5/8" shoe. Leave the centralizers free floating. Pick up swell packer and place in string at approximately 2000'. 16.5. Continue running 5-1/2" production casing 5-1/2" GeoConn M/U torques Casing OD Minimum Maximum Yield Torque 5-1/2" 10,800 ft -lbs 13,200 ft -lbs 18,400 ft -lbs Page 29 Version 0 October, 2015 Hilcorp Energy Company Page 30 HV B-17 Drilling Procedure Rev 0 ��icfcrl (3rt� GeOCOnn Date Connection Data Sheet Metal One Corp I I Rev. 1 3 Connection : GeoConn NL I Y V I Imperial S.I. Pioe Bodv Grade Pilo int Pilo mm2 Pipe OD D 5.500 in 139.7 mm Wei ht 17.0 Ib/ft 25.33 k /m wall thickness ( t j 0.304 in 7.72 mm Pipe ID d 4.892 in 124.26 mm Drift Dia. 4.767 1 in 1 121.08 1 mm Cnnneetinn Pipe Critical Aera 4.96 int 3,200 mm2 Box critical Aera 6.10 int 3.935 mm2 Coupling OD W 6.050 in 153.67 mm Coupling Length NL 8.350 in 212.09 mm Make u Loss 4.125 in 104.78 mm Thread Taper 1 116 X4" per ft Number of threads 5 TPI Performance Prooertfes S.M.Y.S. 545.8 kis 2,428 kN Connection Joint Strength 567.9 kips 2,526 kN M.I.P.Y. 10,640 psi 73.38 MPa Collapse strength 7,470 psi 51.52 MPa ,Pipe body Yield Torque 64,642 ft -Ib 67,600 N -m Note S.M.Y.S. = Specified Minimum YIELD Strength of Pipe body M.I.Y.P. = Minimum Internal Yield Pressure Taroue Racnmmended Min. 10,800 ft -Ib 14,600 N -m Opti. 12 000 ft -Ib 16,200 N -m Max. 13,200 ft -Ib 17,800 N -m Operational Max. 16,200 ft -Ib 21,900 N -m Connection Yield Torque 1 18,400 1 ft -Ib 1 24,9 N -m Note : Operational Max. torque can be applied for high torque application Legal Notice The use of the information is at the reader's risk and no warranty is implied or expressed by Metal0ne Corporation with respect to the use of information contained herein. Version 0 14 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 16.6. Run in hole w/ 5-1/2" casing to the 9-5/8" casing shoe. 16.7. Fill the casing with fill up line and break circulation every 1,000 feet to the shoe or as the hole dictates. 16.8. Obtain slack off weight, PU weight, rotating weight and torque of the casing. 16.9. Circulate 2X bottoms up at shoe, ease casing thru shoe. 16.10. Continue to RIH w/ casing no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set casing slowly in and out of slips. Uti 16.12. PU 5-1/2" X 8-1/2" swell packer to be placed at approximately X600'. Swell packer should have 10' handling pups installed on both ends with bow spring centralizers on pups. 16.13. Swedge up and wash last 2 joints to bottom. P/U 5' off bottom. Note slack -off and pick-up weights. 16.14. Stage pump rates up slowly to circulating rate. Circ and condition mud with casing on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low end rheology of the drilling fluid by adding water and thinners. 16.15. Reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. V/ Page 31 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 17.0 Cement 5-1/2" Production Casing 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. Ensure mud & water can be delivered to the cmt unit at acceptable rates. • Pump 20 bbls of freshwater through all of Schlumberger's equipment, taking returns to cuttings bin, prior to pumping any fluid downhole • 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. Attempt to reciprocate the casing during cmt operations until hole gets sticky 17.3. Pump 5 bbls of 12.5 ppg Mud Push spacer. 17.4. Test surface cmt lines to 4500 psi. 17.5. Pump remaining 30 bbls 10.5 ppg Mud Push spacer. 17.6. Mix and pump lead and tail cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 35% OH excess. Page 32 Version 0 October, 2015 Section: Calculation: BLS Vol (0) 9-5/8" x 5-1/2" Csg Overlap: 500' x 0.046 = 23 130 x5L"I"IelJ-�. 8-1/2" OH x 5-1/2" Casing: (10,694 — 3000) x 0.041 x 1.35 = 426 2392 Shoe Track: 80' x 0.023 = 1.9 10.4 Total Volume: 450.9 2532.4 Page 32 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 H11Corp Energy Company 17.7. Drop wiper plug and displace with 3% KCl. 17.8. If hole conditions allow — continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 17.9. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.10. Bump the plug and pressure up to 500 psi over final lift pressure. Hold pressure for 3 minutes. 17.11. Do not overdisplace by more than V2 shoe track. Shoe track volume is 1.9 bbls. 17.12. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 17.13. RD cementers and flush equipment. 17.14. WOC minimum of 12 hours, test casing to 4500 psi and chart for 30 minutes. Page 33 Version 0 October, 2015 EASYBLOK (10694' to 3000') System Conventional Density 15.3 Ib/gal Yield 1.36 ft3/sk Mixed Water 5.93 gal/sk Mixed Fluid 5.93 gal/sk Additives Code Description Concentration Class G Cement 94#/sk D046 Foam Preventer 0.2% BWOC D202 Dispersant 1.5% BWOC D400 EASYBLOK 0.8% BWOC D154 Extender 8.0% BWOC D174 Expanding Additive 1.5% BWOC D198 Retarder 0.3% BWOC 17.7. Drop wiper plug and displace with 3% KCl. 17.8. If hole conditions allow — continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 17.9. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.10. Bump the plug and pressure up to 500 psi over final lift pressure. Hold pressure for 3 minutes. 17.11. Do not overdisplace by more than V2 shoe track. Shoe track volume is 1.9 bbls. 17.12. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 17.13. RD cementers and flush equipment. 17.14. WOC minimum of 12 hours, test casing to 4500 psi and chart for 30 minutes. Page 33 Version 0 October, 2015 Hilcorp Energy Company HV B-17 Drilling Procedure Rev 0 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 ofjob. 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 mmyerskhilcorp. com. This will be included with the EOW documentation that goes to the AOGCC. Page 34 Version 0 October, 2015 HilwEneW Compaoy 18.0 RDMO 18.1. Install BPV in wellhead 18.2. N/D BOPE 18.3. N/U temp abandonment cap 18.4. RDMO Saxon Rig #169 lA HV B-17 Drilling Procedure Rev 0 Page 35 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 HilcOTp Energy Company 19.0 BOP Schematic Page 36 Version 0 October, 2015 Hilco p Energy Company 20.0 Wellhead Schematic Valve, 51/8 Valve, Wing, WKM-M, 3 1/8 SM FE, HWO, DD trim Valve, U', W KM -M, 5 1 Di Cro! 5 Ire SM Valve, Ma! 51/9101 EE Tubing head, Seaboa 163/43MX115 w/ 2- 2 1/16 SM S 9 5/8 P seal bcttc Starting head, ScaN 1610 3M X 16" SOW w/ 2- 2 1/16 5M 5 HV B-17 Drilling Procedure Rev 0 Tree cap, Otis, 51/8 SM FE X 4 % Otis Quick Union 5X ilve, Wing, WKM-M, 11/8 SM FE, HWO, DO trim Page 37 Version 0 October, 2015 Hilcorp Energy Company 21.0 Days Vs Depth Days Vs Depth 0 HVB 17 KBU 31-06X 2000 r 'M0 6000 e M 8000 12000 HV B-17 Drilling Procedure Rev 0 0 5 10 15 20 25 30 Days Page 38 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy company 22.0 Geo-Prog Drill a 10646' MD (-9500' TVDSS) Middle Tyonek gas development well to prove up reserves in a crestal postiion on the structure. Subsurface data indicates the highest part of the anticline lies beneath the HVA -10 well, located in the NW NW Sec 22-T2S- R13W. Primary undepleted reservoir objectives are Lower Beluga, Upper Tyonek, T-40, T80, and T-155. ANTICIPATED FORMATION TOPS• -. EXPECTED TOP NAME FLUID MD (FT) TVD (FT) TVDSS (FT) Est. Pressure Grad EMW Blg-135 GEOLOGICAL-. . 5,588 -4,978 2403 r 0.43 Happy Valley B-17 8.3 • Deep Creek Unit Ql� X = 223621.86 -5,062 Alaska Y= 2190946.64 -- 8.3 • • • X= 224494.47 • ' KB Y= 2194126.87 r 594 ° • • • ' NAD27; AK State 3.9 T-10 gas depletion Plane Zone 4 6,234 ' • 530 -�•-• . . r 10,694 MD r 1.6 Drill a 10646' MD (-9500' TVDSS) Middle Tyonek gas development well to prove up reserves in a crestal postiion on the structure. Subsurface data indicates the highest part of the anticline lies beneath the HVA -10 well, located in the NW NW Sec 22-T2S- R13W. Primary undepleted reservoir objectives are Lower Beluga, Upper Tyonek, T-40, T80, and T-155. ANTICIPATED FORMATION TOPS• -. EXPECTED TOP NAME FLUID MD (FT) TVD (FT) TVDSS (FT) Est. Pressure Grad EMW Blg-135 pos gas 5,867 5,588 -4,978 2403 r 0.43 r 8.3 Tyonek 5,956 5,672 -5,062 2439 r 0.43 r 8.3 T-6 gas 6,204 5,909 -5,299 1200 r 0.20 r 3.9 T-10 gas depletion 6,545 6,234 -5,624 530 r 0.09 r 1.6 T-17 gas depletion 6,908 6,580 -5,970 440 r 0.07 r 1.3 T-40 gas 7,794 7,424 -6,814 3192 r 0.43 r r 8.3 T-70 gas depletion 8,819 8,400 -7,790 1200 r 0.14 2.7 T-80 gas 8,871 8,449 -7,839 3633 0.43 r r 8.3 T-120 gas 9,668 9,214 -8,604 3962 r ► 0.43 r 8.3 T-155 gas 10,326 9,846 -9,236 4234 r 0.43 r 8.3 TD 10,694 10,111 -9,518 4348 0.43 8.3 100 FT LWD Triple Combo through production hole RFT or MDT pressure E line log at TD. Monobore 3 MMCFGPD Page 39 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 23.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ gel and gel extender. Sweep hole with gel or flowzan 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 25 — 30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 40 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 HilmTEnergy Company 8-1/2" Hole Section: Lost Circulation: Ensure 1000 lbs of each of the different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ viscosifier as necessary. 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 MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6% KCl 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. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 41 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 HiImTEnergy Company 24.0 Saxon Rig 169 Layout Page 42 Version 0 October, 2015 '!" K' ® . Page 42 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 25.0 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 43 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 HiImTEne`gy Compsay 26.0 Choke Manifold Schematic Page 44 Version 0 October, 2015 lit ''"!-�1'f�'1.��'�1 t 'hA .r .r 7 V t '� 7L r •� r` y�r r►w�' ��ti� _ 111 Nil A • 4"��: 1 ��iir i�� :.r AL •I r Page 44 Version 0 October, 2015 Hilcorp Energy Company HV B-17 Drilling Procedure Rev 0 27.0 Casing Design Information Calculation & Casing Design Factors Hole Size 12-1/4" Hole Size 8-1/2" Hole Size Drilling Mode MASP: 3337 MASP: Deep Creek Unit DATE: 10/16/2015 WELL: Happy Valley B 17 FIELD: Deep Creek Unit DESIGN BY: Monty M Myers Desian Criteria: Mud Density: 9.0 ppg Mud Density: 9.5 ppg Mud Density: ee attached MASP determination & calculation Production Mode MASP: 4348 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.435 psi/ft) and the casing evacuated for the internal stress Page 45 Version 0 October, 2015 Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-5/8" 5-1/2" Top (MD) 0 0 Top (TVD) 0 0 Bottom (MD) 3,000 10,694 Bottom (TVD) 2,873 10,111 Length 3,000 1 10,694 Weight (ppf) 40 17 Grade L-80 P-110 Connection BTC GeoConn Weight w/o Bouyancy Factor (lbs) 120,000 181,798. Tension at Top of Section (lbs) 120,000 181,798 Min strength Tension (1000 lbs) 916 568 Worst Case Safety Factor (Tension) 7.63 3.12 Collapse Pressure at bottom (Psi) 1,250 4,398 Collapse Resistance w/o tension (Psi) 3,090 7,470 Worst Case Safety Factor (Collapse) 2.47 1.70 MASP (psi) ES1 3,337 Minimum Yield (psi) 5,750 10,640 Worst case safety factor (Burst) 3.19 Page 45 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 28.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation Hilc1 8-1/2'" Hole Section HVB-17 Deep Creek Unit MD TVD Planned Top: 0 0 Planned TD: 10694 10111 Anticipated Formations and Pressures - Formation TVD Est Pressure Oil/Gas/Wet PPG Grad 9.0-9.7 0 3,821 2012 HVB-15 8.8-9.3 Big -135 5588 2403 Gas 8.3 0.430 Tyonek 5672 2439 Gas 8.3 0.430 T-6 5909 1200 Gas 3.9 0.203 T-10 6234 530 Gas 1.6 0.085 T-17 6580 440 Gas 1.3 0.067 T-40 7424 3192 Gas 8.3 0.430 T-70 8400 1200 Gas 2.7 0.143 T-80 8449 3633 Gas 8.3 0.430 T-120 9214 3962 Gas 8.3 0.430 T-155 9846 4234 Gas 8.3 0.430 TD 10111 4348 Gas 8.3 0.430 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date HVB-16 9.0-9.7 0 3,821 2012 HVB-15 8.8-9.3 0 2,393 2013 HVB-12 8.8-9.3 0 10,053 2008 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 8-1/2" hole section is 9.5 ppg. 3. Calculations assume "Unknown" reservoir contains 100.1 gas (worst case). 4. Calculations assume worst case event is 100% evacuation of wellbore to gas. Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: TVD Frac Grad 2873 ft X 0.936 psi/ft 2689 psi 2689(psi) - [0.1(psi/ft)*2873(ft)]= 2402 psi MASP from pore pressure during production mode (Complete evacuation to gas) 10111 ft X 0.430 psi/ft 4348 psi Downhole ,z 4348(psi) - [0.1(psi/ft)*10111(ft)]= 3337 psi Surface Summary: / 1. MASP while drilling 6-3/4" production hole is governed by frac pressure at 7-5/8" shoe with entire wellbore evacuated to gas Page 46 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 Hilcorp Energy Company 29.0 Spider Plot (NAD 27) (Governmental Sections) Legend i� HVB-17 SHL 11 HVB-17 TPH T C061588 HVB-17 BHL 0 Other Surface Well Locations Other Bottom Hole Locations --- Well Paths HVB- l7 BHLI Oil and Gas Unit Boundary IHVB-17 TPHi S002SO13W M C061589 HVB-13 HVB-17 SHL HVB• HVE�QB BHLt'---rl--r Deep Creel SK,r e HVB-161 Bt JW r- ley Pad B. Pad r r'� HVB-12 BHN HVB•15 BHLU HVA -09 BHL0---_—--_--_-- HVX01 BHLO---j e WA -03 BHLO, ADL384380 HVB-16ST, BI" t 11 I °0 w Page 47 Version 0 October, 2015 HV B-17 Drilling Procedure Rev 0 HilmEnergy Company 30.0 Surface Plat (NAD 27) NOTES i ¢aa:a.rw-a¢rnr.u. ccraGGnna�ra.xrc::.P4¢ E.) i 1:¢Y4AIEPIWL:,NSFJ_14 E'+ E ' »9Ci1'7'SH.rbM 5rRiE PthYE Iti�i �+.#E+ aN Nf FP.',CH M» fhSRi)IM1F5 rtH.Sa1FD'P ar.C»SAC.w.� AaICW, VU3Y_'R a ¢ ! ro•nwwe a b..ic.r,G EE':anra r i'.. E.P. ria 1' r' rl..46..nEP L- cFurm rrmu n c ay.1: xtr. JI b6:rr3a laE €.rc:414 CEa+,Ep rPrr aF.:rpr,,:rEp .<F f. P:4V. t.:':aRFa Gi16(i R'MF + 5.H•EVYNp fEarlFl.EU CV Nf! V!'+++'1_' HAPPY VALLEY B-17 AS -BUILT NAD27 ASP ZONE 4 N:2190946.644 . E:223621.857 LAT_ 59'59'19.319'N LONG: 151 `30'33.646"W ELEV. 593-5' NAVD88 O x,lioN?i wirrosc: SECTION 21 TOWNSHIP 2 SOUTH RANGE 13 WEST SEWARD MERIDIAN ALASKA /M o . o� rl'1 •KY 15 Q/p HV NO 1? wi 13 4W FEL ""0 14 iS�r'!! S,E' SfS 5ii 522 N IM1.111 @11I E ?24X!.19?5 p\ w 4\ ''11 R )lwwu m \o 'ho HV NSi.f5 o \ \ \;p HAPPY VALLEY B -PAD NI NIL:Hin NAf;VE ASSN. W_ iS�r'!! S,E' SfS 5ii 522 N IM1.111 @11I E ?24X!.19?5 p\ rF•. ''11 R )lwwu m \o 'ho 0 r ,r OF A4,1 Zrl *:4g� �. ..........�...,r.� .................. si` i %3a :,M. SCOTT ucLANE / i 03�'•, 4928—S ,< SCALE PEEr HAPPY VALLEY B-17 WELL AS -BUILT SURFACE LOCATION NINILCHIK, AK NAD27 ENGINEERING • TESTING Project: 157013 SURVEYING - MAPPING P.O. BOX 468 Ilileorp AIuska. 1 SOL E: NA.(907 AK" -4218 Revisions: VOICE: (907) 283-4218 3800 Centerpoint Drive FAX_ (907) 283-3265 Anchorage, AK 99503 MWAbV IM 4YNAN MCLANECG COM Dwg:157013 10/15/15 APPLICANT: Page 48 Version 0 October, 2015 Hilcorp Energy Company Deep Creek Unit Happy Valley B Pad Plan: Happy Valley B-17 HVB-17 Plan: HVB-17 wp2a Standard Proposal Report 16 October, 2015 HALLIBURTON ----- Sperry Drilling Services HALLIBURTON Project: Deep Creek Unit WEU. DETAILS: Plan: Happy Valley B-17 NAD 1927(NADCON CONUS) Alaska Zone 04 Site: Happy Valley B Pad Ground Level: 593.5 Well: Plan: Happy Valley B-17 +N/ -S +E/ -W Northing Fasting Latittude Longitude Slot Wellbore: HVB-17 0.0 0.0 2190946.64 223621.86 59° 59' 19.319 N 1510 30'33.646 W Plan: HVB-17 wp2a REFERENCE INFORMATION Co-ordinate (WE) Reference: Well Plan: Happy Valley B-17, True North Vertical (TVD) Reference: HV B-17 (dj 611.5usft (Saxon 169 (18+593.5)) -500 Measured Depth Reference: HV B-17 611.5usft (Saxon 169 (18+593.5)) Calculation Method: Minimum Curvature SECTION DETAILS 0 Sec MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLeg TFace VSec Target 1 18.0 0.00 0.00 18.0 -593.5 0.0 0.0 0.00 0.00 0.0 2 600.0 0.00 0.00 600.0 -11.5 0.0 0.0 0.00 0.00 0.0 3 1296.3 20.89 10.66 1281.0 669.5 123.4 23.2 3.00 10.66 125.3 500 500 Start Dir 3°/100' : 600' MD, 600'TVD 4 8552.1 20.89 10.66 8059.9 7448.4 2666.0 501.6 0.00 0.00 2707.7 - - - - 5 8811.2 16.38 30.70 8305.6 7694.1 2742.9 528.9 3.00 134.39 2788.9 6 8911.2 16.38 30.70 8401.5 7790.0 2767.1 543.3 0.00 0.00 2816.0 HVB17 wp2a T-70 7 10693.5 16.38 30.70 10111.5 9500.0 3199.3 799.8 0.00 0.00 3297.8 HVB17 wp2a TD 1000- -1000 End Dir : 1296.3' MD, 1281' TVD SURVEY PROGRAM 1500 1500 Date: 2015-08-26T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 2000 2p00 18.0 3500.0 HVB-17 wp2a MWD+SC+sag 3500.0 10693.5 HVB-17 wp2a MWD+SC+sag 25p0 2500 CASING DETAILS TVD TVDSS MD Size Name 9 5/8" x 12 1!4"- 3000 2872.7 2261.2 3000.0 9-5/8 9 5/8" x 12 1/4" 3000 10111.5 9500.0 10693.5 5-1/2 51/2"x81/2" 3500 FORMATION TOP DETAILS 3500 - TVDPath TVDssPath MDPath Formation 5588.0 4976.5 5906.4 Big -135 A0p0 5672.0 5060.5 5996.3 Tyonek 5909.0 5297.5 6249.9 T-6 c 4000-6234.0 5622.5 6597.8 T-10 6580.0 5968.5 6968.1 T-17 cn 4p0 7424.0 6812.5 7871.5 T-40 :3 8400.0 7788.5 8909.7 T-70 O 4500 8449.0 7837.5 8960.7 T-80 9214.0 8602.5 9758.1 T-120 500 9846.0 9234.5 10416.8 T-155 5000- Q 5500 Q v 5500 Big -135 � , p00 Tyonek 6000 T-6 6500 E -- T-10 6500- 500 X000 -T-17 7000 X500 7500 6000 T-40 8000 6500 - - - - Start Dir 3°1100' : 8552.1' MD, 8059.9'TVD T-70 - - - - - - - - End Dir : 8811.2' MD, 8305.6' TVD 8500 000 HVB17 Q. T-7 T-80 g500 9000 T-120 1p000 9500- A0500 10000 T-155 OQ HV617 wp2a T 5 1/2" x 8 1/2'' - Total Depth : 10693.5' MD, 10111.5' TVD wp2a 10500-HVB-17 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 Vertical Section at 14.16° (1250 usfUin) WELL DETAILS: Plan: Happy Valley B-17 Ground Level: 593.5 +N/ -S +E/ -W Northing Easting Latittude Longitude Slot 0.0 0.0 2190946.64 223621.86 59° 57 19.319 N 1510 30' 33.646 W REFERENCE INFORMATION Co-ordinate (N/Q Reference: Well Plan: Happy Valley B-17, True North Vertical (TVD) Reference: HV B-17 611.5usfl (Saxon 169 (18+593.5)) Measured Depth Reference: HV B-17 611.5usfi (Saxon 169 (18+593.5)) -1200 -1000 -800 -600 400 -200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 West( -)/East(+) (500 usfT/in) HALLIBURTON Project: Deep Creek Unit BP."v 0,1111" Site: Happy Valley B Pad Well: Plan: Happy Valley B-17 Wellbore: HVB-17 Fm Plan: HVB-17 wp2a WELL DETAILS: Plan: Happy Valley B-17 Ground Level: 593.5 +N/ -S +E/ -W Northing Easting Latittude Longitude Slot 0.0 0.0 2190946.64 223621.86 59° 57 19.319 N 1510 30' 33.646 W REFERENCE INFORMATION Co-ordinate (N/Q Reference: Well Plan: Happy Valley B-17, True North Vertical (TVD) Reference: HV B-17 611.5usfl (Saxon 169 (18+593.5)) Measured Depth Reference: HV B-17 611.5usfi (Saxon 169 (18+593.5)) -1200 -1000 -800 -600 400 -200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 West( -)/East(+) (500 usfT/in) HALLIBURTON Database: Sperry EDM - NORTH US + CANADA Company: Hilcorp Energy Company Project: Deep Creek Unit Site: Happy Valley B Pad Well: Plan: Happy Valley B-17 Wellbore: HVB-17 Design: HVB-17 wp2a Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: Happy Valley B-17 HV B-17 @ 611.5usft (Saxon 169 (18+593.5)) HV B-17 @ 611.5usft (Saxon 169 (18+593.5)) . True Minimum Curvature Project Deep Creek Unit Map System: US State Plane 1927 (Exact solution)' System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) • Using Well Reference Point Magnetics Map Zone: Alaska Zone 04 Declination Dip Angle Field Strength Site Happy Valley B Pad (°) Site Position: Northing: 2,190,994.66 usft Latitude: 59° 59'19.821 N From: Map Easting: 223,750.88 usft Longitude: 151 ° 30'31.132 W Position Uncertainty: 0.0 usft Slot Radius: 13-3/16" Grid Convergence: -1.31 ° 73.03 55,143 Well Plan: Happy Valley B-17 Well Position +N/ -S 0.0 usft Northing: 2,190,946.64 usft Latitude: 59° 59'19.319 N +E/ -W 0.0 usft Easting: 223,621.86 usft Longitude: 1510 30'33.646 W Position Uncertainty 0.0 usft Wellhead Elevation: 593.5 usft Ground Level: 593.5 usft Wellbore HVB-17 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 8/26/2015 16.17 73.03 55,143 Design HVB-17 wp2a Audit Notes: Version: Phase: PLAN Tie On Depth: 18.0 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 18.0 0.0 0.0 14.16 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/ -S +E/ -W Rate Rate Rate Tool Face (usft) V) V) (usft) usft (usft) (usft) (°/100usft) ("/100usft) (°/100usft) V) 18.0 0.00 0.00 18.0 -593.5 0.0 0.0 0.00 0.00 0.00 0.00 600.0 0.00 0.00 600.0 -11.5 0.0 0.0 0.00 0.00 0.00 0.00 1,296.3 20.89 10.66 1,281.0 669.5 123.4 23.2 3.00 3.00 0.00 10.66 8,552.1 20.89 10.66 8,059.9 7,448.4 2,666.0 501.6 0.00 0.00 0.00 0.00 8,811.2 16.38 30.70 8,305.6 7,694.1 2,742.9 528.9 3.00 -1.74 7.74 134.39 8,911.2 16.38 30.70 8,401.5 7,790.0 2,767.1 543.3 0.00 0.00 0.00 0.00 10,693.5 16.38 30.70 10,111.5 9,500.0 3,199.3 799.8 0.00 0.00 0.00 0.00 10/16/2015 10:37.23AM Page 2 COMPASS 5000.1 Build 73 Halliburton H A L L I B U R TO N Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well Plan: Happy Valley B-17 Company: Hilcorp Energy Company TVD Reference: HV B-17 @ 611.5usft (Saxon 169 (18+593.5)) Project: Deep Creek Unit MD Reference: HV B-17 @ 611.5usft (Saxon 169 (18+593.5)) Site: Happy Valley B Pad North Reference: True Well: Plan: Happy Valley B-17 Survey Calculation Method: Minimum Curvature Wellbore: HVB-17 Depth Inclination Design: HVB-17 wp2a TVDss +N/ -S Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) V) V) (usft) usft (usft) (usft) (usft) (usft) -593.50 18.0 0.00 0.00 18.0 -593.5 0.0 0.0 2,190,946.64 223,621.86 0.00 0.00 100.0 0.00 0.00 100.0 -511.5 0.0 0.0 2,190,946.64 223,621.86 0.00 0.00 200.0 0.00 0.00 200.0 -411.5 0.0 0.0 2,190,946.64 223,621.86 0.00 0.00 300.0 0.00 0.00 300.0 -311.5 0.0 0.0 2,190,946.64 223,621.86 0.00 0.00 400.0 0.00 0.00 400.0 -211.5 0.0 0.0 2,190,946.64 223,621.86 0.00 0.00 500.0 0.00 0.00 500.0 -111.5 0.0 0.0 2,190,946.64 223,621.86 0.00 0.00 600.0 0.00 0.00 600.0 -11.5 0.0 0.0 2,190,946.64 223,621.86 0.00 0.00 Start Dir 3°/100' : 600' MD, 600'TVD 700.0 3.00 10.66 700.0 88.5 2.6 0.5 2,190,949.20 223,622.40 3.00 2.61 800.0 6.00 10.66 799.6 188.1 10.3 1.9 2,190,956.88 223,624.03 3.00 10.44 900.0 9.00 10.66 898.8 287.3 23.1 4.3 2,190,969.65 223,626.73 3.00 23.47 1,000.0 12.00 10.66 997.1 385.6 41.0 7.7 2,190,987.47 223,630.51 3.00 41.66 1,100.0 15.00 10.66 1,094.3 482.8 64.0 12.0 2,191,010.31 223,635.35 3.00 64.96 1,200.0 18.00 10.66 1,190.2 578.7 91.9 17.3 2,191,038.09 223,641.23 3.00 93.30 1,296.3 20.89 10.66 1,281.0 669.5 123.4 23.2 2,191,069.45 223,647.88 3.00 125.29 End Dir : 1296.3' MD, 1281' TVD 1,300.0 20.89 10.66 1,284.4 672.9 124.7 23.5 2,191,070.74 223,648.15 0.02 126.61 1,400.0 20.89 10.66 1,377.9 766.4 159.7 30.0 2,191,105.62 223,655.54 0.00 162.20 1,500.0 20.89 10.66 1,471.3 859.8 194.7 36.6 2,191,140.50 223,662.93 0.00 197.79 1,600.0 20.89 10.66 1,564.7 953.2 229.8 43.2 2,191,175.39 223,670.32 0.00 233.38 1,700.0 20.89 10.66 1,658.1 1,046.6 264.8 49.8 2,191,210.27 223,677.72 0.00 268.97 1,800.0 20.89 10.66 1,751.6 1,140.1 299.9 56.4 2,191,245.15 223,685.11 0.00 304.56 1,900.0 20.89 10.66 1,845.0 1,233.5 334.9 63.0 2,191,280.03 223,692.50 0.00 340.15 2,000.0 20.89 10.66 1,938.4 1,326.9 370.0 69.6 2,191,314.92 223,699.89 0.00 375.74 2,100.0 20.89 10.66 2,031.8 1,420.3 405.0 76.2 2,191,349.80 223,707.28 0.00 411.34 2,200.0 20.89 10.66 2,125.3 1,513.8 440.0 82.8 2,191,384.68 223,714.67 0.00 446.93 2,300.0 20.89 10.66 2,218.7 1,607.2 475.1 89.4 2,191,419.56 223,722.06 0.00 482.52 2,400.0 20.89 10.66 2,312.1 1,700.6 510.1 96.0 2,191,454.45 223,729.45 0.00 518.11 2,500.0 20.89 10.66 2,405.6 1,794.1 545.2 102.6 2,191,489.33 223,736.84 0.00 553.70 2,600.0 20.89 10.66 2,499.0 1,887.5 580.2 109.2 2,191,524.21 223,744.24 0.00 589.29 2,700.0 20.89 10.66 2,592.4 1,980.9 615.3 115.8 2,191,559.10 223,751.63 0.00 624.88 2,800.0 20.89 10.66 2,685.8 2,074.3 650.3 122.4 2,191,593.98 223,759.02 0.00 660.47 2,900.0 20.89 10.66 2,779.3 2,167.8 685.3 129.0 2,191,628.86 223,766.41 0.00 696.06 3,000.0 20.89 10.66 2,872.7 2,261.2 720.4 135.5 2,191,663.74 223,773.80 0.00 731.65 9 5/8" x 12 1/4" 3,100.0 20.89 10.66 2,966.1 2,354.6 755.4 142.1 2,191,698.63 223,781.19 0.00 767.24 3,200.0 20.89 10.66 3,059.5 2,448.0 790.5 148.7 2,191,733.51 223,788.58 0.00 802.83 3,300.0 20.89 10.66 3,153.0 2,541.5 825.5 155.3 2,191,768.39 223,795.97 0.00 838.42 3,400.0 20.89 10.66 3,246.4 2,634.9 860.5 161.9 2,191,803.27 223,803.36 0.00 874.01 3,500.0 20.89 10.66 3,339.8 2,728.3 895.6 168.5 2,191,838.16 223,810.76 0.00 909.60 3,600.0 20.89 10.66 3,433.3 2,821.8 930.6 175.1 2,191,873.04 223,818.15 0.00 945.19 3,700.0 20.89 10.66 3,526.7 2,915.2 965.7 181.7 2,191,907.92 223,825.54 0.00 980.78 3,800.0 20.89 10.66 3,620.1 3,008.6 1,000.7 188.3 2,191,942.80 223,832.93 0.00 1,016.37 3,900.0 20.89 10.66 3,713.5 3,102.0 1,035.8 194.9 2,191,977.69 223,840.32 0.00 1,051.96 4,000.0 20.89 10.66 3,807.0 3,195.5 1,070.8 201.5 2,192,012.57 223,847.71 0.00 1,087.55 10/16/2015 10:37:23AM Page 3 COMPASS 5000.1 Build 73 Halliburton H A LL I B U R TO N Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well Plan: Happy Valley B-17 Company: Hilcorp Energy Company TVD Reference: HV B-17 @ 611.5usft (Saxon 169 (18+593.5)) Project: Deep Creek Unit MD Reference: HV B-17 @ 611.5usft (Saxon 169 (18+593.5)) Site: Happy Valley B Pad North Reference: True Well: Plan: Happy Valley B-17 Survey Calculation Method: Minimum Curvature Wellbore: HVB-17 Depth Inclination Design: HVB-17 wp2a TVDss +N1S Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N1S +E/ -W Northing Easting DLS Vert Section (usft) (^) (_) (usft) usft (usft) (usft) (usft) (usft) 3,288.88 4,100.0 20.89 10.66 3,900.4 3,288.9 1,105.8 208.1 2,192,047.45 223,855.10 0.00 1,123.14 4,200.0 20.89 10.66 3,993.8 3,382.3 1,140.9 214.7 2,192,082.34 223,862.49 0.00 1,158.73 4,300.0 20.89 10.66 4,087.2 3,475.7 1,175.9 221.3 2,192,117.22 223,869.88 0.00 1,194.32 4,400.0 20.89 10.66 4,180.7 3,569.2 1,211.0 227.9 2,192,152.10 223,877.28 0.00 1,229.92 4,500.0 20.89 10.66 4,274.1 3,662.6 1,246.0 234.4 2,192,186.98 223,884.67 0.00 1,265.51 4,600.0 20.89 10.66 4,367.5 3,756.0 1,281.1 241.0 2,192,221.87 223,892.06 0.00 1,301.10 4,700.0 20.89 10.66 4,460.9 3,849.4 1,316.1 247.6 2,192,256.75 223,899.45 0.00 1,336.69 4,800.0 20.89 10.66 4,554.4 3,942.9 1,351.1 254.2 2,192,291.63 223,906.84 0.00 1,372.28 4,900.0 20.89 10.66 4,647.8 4,036.3 1,386.2 260.8 2,192,326.51 223,914.23 0.00 1,407.87 5,000.0 20.89 10.66 4,741.2 4,129.7 1,421.2 267.4 2,192,361.40 223,921.62 0.00 1,443.46 5,100.0 20.89 10.66 4,834.7 4,223.2 1,456.3 274.0 2,192,396.28 223,929.01 0.00 1,479.05 5,200.0 20.89 10.66 4,928.1 4,316.6 1,491.3 280.6 2,192,431.16 223,936.40 0.00 1,514.64 5,300.0 20.89 10.66 5,021.5 4,410.0 1,526.3 287.2 2,192,466.04 223,943.80 0.00 1,550.23 5,400.0 20.89 10.66 5,114.9 4,503.4 1,561.4 293.8 2,192,500.93 223,951.19 0.00 1,585.82 5,500.0 20.89 10.66 5,208.4 4,596.9 1,596.4 300.4 2,192,535.81 223,958.58 0.00 1,621.41 5,600.0 20.89 10.66 5,301.8 4,690.3 1,631.5 307.0 2,192,570.69 223,965.97 0.00 1,657.00 5,700.0 20.89 10.66 5,395.2 4,783.7 1,666.5 313.6 2,192,605.58 223,973.36 0.00 1,692.59 5,800.0 20.89 10.66 5,488.6 4,877.1 1,701.6 320.2 2,192,640.46 223,980.75 0.00 1,728.18 5,900.0 20.89 10.66 5,582.1 4,970.6 1,736.6 326.8 2,192,675.34 223,988.14 0.00 1,763.77 5,906.4 20.89 10.66 5,588.0 4,976.5 1,738.8 327.2 2,192,677.56 223,988.61 0.00 1,766.03 Big -135 5,996.3 20.89 10.66 5,672.0 5,060.5 1,770.3 333.1 2,192,708.92 223,995.26 0.00 1,798.03 Tyonek 6,000.0 20.89 10.66 5,675.5 5,064.0 1,771.6 333.3 2,192,710.22 223,995.53 0.00 1,799.36 6,100.0 20.89 10.66 5,768.9 5,157.4 1,806.7 339.9 2,192,745.11 224,002.92 0.00 1,834.95 6,200.0 20.89 10.66 5,862.3 5,250.8 1,841.7 346.5 2,192,779.99 224,010.32 0.00 1,870.54 6,249.9 20.89 10.66 5,909.0 5,297.5 1,859.2 349.8 2,192,797.41 224,014.01 0.00 1,888.32 T-6 6,300.0 20.89 10.66 5,955.8 5,344.3 1,876.8 353.1 2,192,814.87 224,017.71 0.00 1,906.13 6,400.0 20.89 10.66 6,049.2 5,437.7 1,911.8 359.7 2,192,849.75 224,025.10 0.00 1,941.72 6,500.0 20.89 10.66 6,142.6 5,531.1 1,946.9 366.3 2,192,884.64 224,032.49 0.00 1,977.31 6,597.8 20.89 10.66 6,234.0 5,622.5 1,981.1 372.8 2,192,918.75 224,039.72 0.00 2,012.12 T-10 6,600.0 20.89 10.66 6,236.1 5,624.6 1,981.9 372.9 2,192,919.52 224,039.88 0.00 2,012.91 6,700.0 20.89 10.66 6,329.5 5,718.0 2,016.9 379.5 2,192,954.40 224,047.27 0.00 2,048.50 6,800.0 20.89 10.66 6,422.9 5,811.4 2,052.0 386.1 2,192,989.28 224,054.66 0.00 2,084.09 6,900.0 20.89 10.66 6,516.3 5,904.8 2,087.0 392.7 2,193,024.17 224,062.05 0.00 2,119.68 6,968.1 20.89 10.66 6,580.0 5,968.5 2,110.9 397.2 2,193,047.94 224,067.09 0.00 2,143.93 T-17 7,000.0 20.89 10.66 6,609.8 5,998.3 2,122.1 399.3 2,193,059.05 224,069.44 0.00 2,155.27 7,100.0 20.89 10.66 6,703.2 6,091.7 2,157.1 405.9 2,193,093.93 224,076.84 0.00 2,190.86 7,200.0 20.89 10.66 6,796.6 6,185.1 2,192.2 412.5 2,193,128.82 224,084.23 0.00 2,226.45 7,300.0 20.89 10.66 6,890.0 6,278.5 2,227.2 419.1 2,193,163.70 224,091.62 0.00 2,262.04 7,400.0 20.89 10.66 6,983.5 6,372.0 2,262.2 425.7 2,193,198.58 224,099.01 0.00 2,297.63 7,500.0 20.89 10.66 7,076.9 6,465.4 2,297.3 432.3 2,193,233.46 224,106.40 0.00 2,333.22 10/16/2015 10:37:23AM Page 4 COMPASS 5000.1 Build 73 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Coordinate Reference: Well Plan: Happy Valley B-17 Company: Hilcorp Energy Company TVD Reference: HV B-17 @ 611.5usft (Saxon 169 (18+593.5)) Project: Deep Creek Unit MD Reference: HV B-17 @ 611.5usft (Saxon 169 (18+593.5)) Site: Happy Valley B Pad North Reference: True Well: Plan: Happy Valley B-17 Survey Calculation Method: Minimum Curvature Wellbore: HVB-17 Depth Inclination Design: HVB-17 wp2a TVDss +N/ -S Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) V) V) (usft) usft (usft) (usft) (usft) (usft) 6,558.82 7,600.0 20.89 10.66 7,170.3 6,558.8 2,332.3 438.8 2,193,268.35 224,113.79 0.00 2,368.81 7,700.0 20.89 10.66 7,263.8 6,652.3 2,367.4 445.4 2,193,303.23 224,121.18 0.00 2,404.40 7,800.0 20.89 10.66 7,357.2 6,745.7 2,402.4 452.0 2,193,338.11 224,128.57 0.00 2,439.99 7,871.5 20.89 10.66 7,424.0 6,812.5 2,427.5 456.7 2,193,363.06 224,133.86 0.00 2,465.45 T-40 7,900.0 20.89 10.66 7,450.6 6,839.1 2,437.4 458.6 2,193,372.99 224,135.96 0.00 2,475.58 8,000.0 20.89 10.66 7,544.0 6,932.5 2,472.5 465.2 2,193,407.88 224,143.36 0.00 2,511.17 8,100.0 20.89 10.66 7,637.5 7,026.0 2,507.5 471.8 2,193,442.76 224,150.75 0.00 2,546.76 8,200.0 20.89 10.66 7,730.9 7,119.4 2,542.6 478.4 2,193,477.64 224,158.14 0.00 2,582.35 8,300.0 20.89 10.66 7,824.3 7,212.8 2,577.6 485.0 2,193,512.52 224,165.53 0.00 2,617.94 8,400.0 20.89 10.66 7,917.7 7,306.2 2,612.7 491.6 2,193,547.41 224,172.92 0.00 2,653.53 8,500.0 20.89 10.66 8,011.2 7,399.7 2,647.7 498.2 2,193,582.29 224,180.31 0.00 2,689.12 8,552.1 20.89 10.66 8,059.8 7,448.3 2,666.0 501.6 2,193,600.46 224,184.16 0.00 2,707.67 Start Dir 3°1100' : 8552.1' MD, 8059.9'TVD 8,600.0 19.91 13.67 8,104.7 7,493.2 2,682.3 505.1 2,193,616.70 224,188.04 3.00 2,724.35 8,700.0 18.05 20.93 8,199.3 7,587.8 2,713.3 514.7 2,193,647.50 224,198.31 3.00 2,756.77 8,800.0 16.53 29.63 8,294.8 7,683.3 2,740.1 527.3 2,193,674.05 224,211.49 3.00 2,785.87 8,811.2 16.38 30.70 8,305.5 7,694.0 2,742.9 528.9 2,193,676.75 224,213.14 3.00 2,788.92 End Dir : 8811.2' MD, 8305.6' TVD 8,900.0 16.38 30.70 8,390.7 7,779.2 2,764.4 541.6 2,193,697.99 224,226.41 0.00 2,812.93 8,909.7 16.38 30.70 8,400.0 7,788.5 2,766.8 543.0 2,193,700.30 224,227.86 0.00 2,815.54 T-70 8,911.2 16.38 30.70 8,401.5 7,790.0 2,767.1 543.3 2,193,700.67 224,228.09 0.00 2,815.96 8,960.7 16.38 30.70 8,449.0 7,837.5 2,779.1 550.4 2,193,712.51 224,235.49 0.00 2,829.34 T-80 9,000.0 16.38 30.70 8,486.7 7,875.2 2,788.7 556.0 2,193,721.90 224,241.36 0.00 2,839.96 9,100.0 16.38 30.70 8,582.6 7,971.1 2,812.9 570.4 2,193,745.81 224,256.31 0.00 2,866.99 9,200.0 16.38 30.70 8,678.6 8,067.1 2,837.2 584.8 2,193,769.73 224,271.25 0.00 2,894.02 9,300.0 16.38 30.70 8,774.5 8,163.0 2,861.4 599.2 2,193,793.64 224,286.20 0.00 2,921.06 9,400.0 16.38 30.70 8,870.4 8,258.9 2,885.7 613.6 2,193,817.55 224,301.14 0.00 2,948.09 9,500.0 16.38 30.70 8,966.4 8,354.9 2,909.9 628.0 2,193,841.47 224,316.09 0.00 2,975.12 9,600.0 16.38 30.70 9,062.3 8,450.8 2,934.2 642.4 2,193,865.38 224,331.03 0.00 3,002.16 9,700.0 16.38 30.70 9,158.3 8,546.8 2,958.4 656.8 2,193,889.29 224,345.98 0.00 3,029.19 9,758.1 16.38 30.70 9,214.0 8,602.5 2,972.5 665.2 2,193,903.18 224,354.66 0.00 3,044.89 T-120 9,800.0 16.38 30.70 9,254.2 8,642.7 2,982.6 671.2 2,193,913.20 224,360.93 0.00 3,056.22 9,900.0 16.38 30.70 9,350.2 8,738.7 3,006.9 685.6 2,193,937.12 224,375.87 0.00 3,083.25 10,000.0 16.38 30.70 9,446.1 8,834.6 3,031.1 700.0 2,193,961.03 224,390.82 0.00 3,110.29 10,100.0 16.38 30.70 9,542.0 8,930.5 3,055.4 714.4 2,193,984.94 224,405.76 0.00 3,137.32 10,200.0 16.38 30.70 9,638.0 9,026.5 3,079.6 728.8 2,194,008.86 224,420.71 0.00 3,164.35 10,300.0 16.38 30.70 9,733.9 9,122.4 3,103.9 743.2 2,194,032.77 224,435.65 0.00 3,191.38 10,400.0 16.38 30.70 9,829.9 9,218.4 3,128.1 757.6 2,194,056.68 224,450.60 0.00 3,218.42 10,416.8 16.38 30.70 9,846.0 9,234.5 3,132.2 760.0 2,194,060.70 224,453.11 0.00 3,222.96 T-155 10,500.0 16.38 30.70 9,925.8 9,314.3 3,152.4 772.0 2,194,080.59 224,465.55 0.00 3,245.45 10/16/2015 10:37:23AM Page 5 COMPASS 5000.1 Build 73 HALLIBURTON Database: Sperry EDM - NORTH US + CANADA Company: Hilcorp Energy Company Project: Deep Creek Unit Site: Happy Valley B Pad Well: Plan: Happy Valley B-17 Wellbore: HVB-17 Design: HVB-17 wp2a Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: Happy Valley B-17 HV B-17 @ 611.5usft (Saxon 169 (18+593.5)) HV B-17 @ 611.5usft (Saxon 169 (18+593.5)) True Minimum Curvature 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) 9,410.25 10,600.0 16.38 30.70 10,021.7 9,410.2 3,176.6 786.4 2,194,104.51 224,480.49 0.00 3,272.48 10,693.5 16.38 30.70 10,111.5 • 9,500.0 3,199.3 799.8 2,194,126.87 224,494.47 0.00 3,297.76 Total Depth : 10693.5' MD, 10111.5' TVD - 5 1/2" x 6 1/2" Targets Target Name hittmiss target Dip Angle Dip Dir. TVD +N/ -S +EI -W Northing Easting Shape {°) (°) (usft) (usft) (usft) (usft) (usft) HV1317 wp2 T-70 0.00 0.00 8,401.5 2,767.1 543.3 2,193,700.67 224,228.09 - plan hits target center -Circle (radius 100.0) HV1317 wp2 TD 0.00 0.00 10,111.5 3,199.3 799.8 2,194,126.88 224,494.47 - plan hits target center - Circle (radius 100.0) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 3,000.0 2,872.7 9 5/8" x 12 1/4" 9-5/8 12-1/4 10,693.5 10,111.5 5 1/2" x 8 1/2" 5-1/2 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (°) C) 5,996.3 5,672.0 Tyonek 0.00 8,909.7 8,400.0 T-70 0.00 7,871.5 7,424.0 T-40 0.00 10,416.8 9,846.0 T-155 0.00 6,597.8 6,234.0 T-10 0.00 6,968.1 6,580.0 T-17 0.00 6,249.9 5,909.0 T-6 0.00 8,960.7 8,449.0 T-80 0.00 9,758.1 9,214.0 T-120 0.00 5,906.4 5,588.0 Big -135 0.00 10/16/2015 10:37:23AM Page 6 COMPASS 5000.1 Build 73 HALLIBURTON Database: Sperry EDM - NORTH US + CANADA Company: Hilcorp Energy Company Project: Deep Creek Unit Site: Happy Valley B Pad Well: Plan: Happy Valley B-17 Wellbore: HVB-17 Design: HVB-17 wp2a Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: Happy Valley B-17 HV B-17 @ 611.5usft (Saxon 169 (18+593.5)) HV B-17 @ 611.5usft (Saxon 169 (18+593.5)) True Minimum Curvature Pian Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 600.0 600.0 0.0 0.0 Start Dir 31/100' : 600' MD, 6007VD 1,296.3 1,281.0 123.4 23.2 End Dir : 1296.3' MD, 1281' TVD 8,552.1 8,059.8 2,666.0 501.6 Start Dir 3°/100' : 8552.1' MD, 8059.97VD 8,811.2 8,305.5 2,742.9 528.9 End Dir : 8811.2' MD, 8305.6' TVD 10,693.5 10,111.5 3,199.3 799.8 Total Depth: 10693.5' MD, 10111.5' TVD 10/16/2015 10:37.23AM Page 7 COMPASS 5000.1 Build 73 Hilcorp Energy Company Deep Creek Unit Happy Valley B Pad Plan: Happy Valley B-17 HVB-17 HV13-17 wp2a Sperry Drilling Services Clearance Summary Anticollision Report 16 October, 2015 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: Happy Valley B Pad - Plan: Happy Valley B-17 - HVB-17 - HVB-17 wp2a Well Coordinates: 2,190,946.64 N, 223,621.86 E (59` 59' 19.32" N, 151. 30' 33.65- W) Datum Height: HV B-17 @ 611.5usR (Saxon 169 (18+593.5)) Scan Range: 0.0 to 10,693.5 usi t. Measured Depth. Scan Radius is 1,267.6 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is Unlimited Version: 5000.1 Build: 73 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 2004 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Orllling Services HALLIBURTON Anticollision Report for Plan: Happy Valley B-17 - HVB-17 wp2a Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) @Measured Clearance Summary Based on Reference Design: Happy Valley B Pad -Plan: Happy Valley B-17 - HVB-17 - HVB-17 wp2a Depth Scan Range: 0.0 to 10,693.5 usft. Measured Depth. (usft) usft Scan Radius is 1,267.6 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited 746.8 8,420.0 Measured Minimum @Measured Site Name DepthDistance Pass - Depth Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) Happy Valley A Pad 21.800 Ellipse Separation Pass - 119.9 Happy Valley A-10 - HV #10 - HV #10 6,986.5 817.0 6,986.5 Happy Valley A-10 - HV #10 - HV #10 7,025.0 817.9 7,025.0 Happy Valley B Pad 6.883 Clearance Factor Pass - 147.1 Happy Valley B-12 - HV #12 - HV #12 1,049.0 111.0 1,049.0 Happy Valley B-12 - HV #12 - HV #12 1,050.0 111.0 1,050.0 Happy Valley B-12 - HV #12 - HV #12 1,250.0 126.3 1,250.0 Happy Valley B-13 - HV #13 - HV #13 707.3 29.8 707.3 Happy Valley B-13 - HV #13 - HV #13 725.0 30.5 725.0 Happy Valley B-14 - HVB-14 - HVB-14 25.0 147.9 25.0 Happy Valley B-14 - HVB-14 - HVB-14 925.0 149.7 925.0 Happy Valley B-14 - HVB-14 - HVB-14 1,250.0 172.6 1,250.0 Happy Valley B-15 - HV #15 - HV #15 538.0 73.4 538.0 Happy Valley B-15 - HV #15 - HV #15 550.0 73.5 550.0 Happy Valley B-15 - HV #15 - HV #15 625.0 77.7 625.0 Happy Valley B-16 - HV #16 - HV #16 2053 107.2 205.3 Happy Valley B-16 - HV #16 - HV #16 250.0 107.3 250.0 Happy Valley B-16 - HV #16 - HV #16 1,675.0 181.3 1,675.0 Happy Valley B-16 - HV #16A - HV #16A 205.3 107.2 205.3 Happy Valley B-16 - HV #16A- HV #16A 250.0 107.3 250.0 Happy Valley B-16 - HV #16A- HV #16A 1,675.0 181.3 1,675.0 Hileorp Energy Company Deep Creek Unit Ellipse @Measured Clearance Summary Based on Separation Depth Factor Minimum (usft) usft 746.8 8,420.0 11.635 Ellipse Separation Pass - 747.5 8,420.0 11.615 Clearance Factor Pass - 105.9 1,045.0 21.825 Centre Distance Pass - 105.9 1,045.9 21.800 Ellipse Separation Pass - 119.9 1,234.6 19.736 Clearance Factor Pass - 25.6 716.6 6.953 Ellipse Separation Pass - 26.0 733.3 6.883 Clearance Factor Pass - 147.1 21.6 175.314 Centre Distance Pass - 145.0 918.8 32.106 Ellipse Separation Pass - 166.2 1,233.3 26.973 Clearance Factor Pass - 70.1 543.0 21.991 Centre Distance Pass - 70.1 554.7 21.499 Ellipse Separation Pass - 73.8 624.0 19.720 Clearance Factor Pass - 105.6 202.4 67.514 Centre Distance Pass - 105.5 246.6 60.211 Ellipse Separation Pass - 170A 1,634.7 16.513 Clearance Factor Pass - 105.6 202.4 67.514 Centre Distance Pass - 105.5 246.6 60.211 Ellipse Separation Pass - 170.4 1,634.7 16.510 Clearance Factor Pass - Separation Warning 16 October, 2015 - 10:36 Page 2 of 5 COMPASS HALLIBURTON Anticollision Report for Plan: Happy Valley B-17 - HVB-17 wp2a Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 18.0 3,500.0 HVB-17 wp2a MWD+SC+sag 3,500.0 10,693.5 HVB-17 wp2a 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. Hilcorp Energy Company Deep Creek Unit 16 October, 2015 - 10.36 Page 3 o15 COMPASS HALLIBURTON Anticollision Report for Plan: Happy Valley B-17 - HVB-17 wp2a Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to HV B-17 @ 611.5usft (Saxon 169 (18+593.5)). Northing and Easting are relative to Plan: Happy Valley B-17. Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04. Central Meridian is -150.000, Grid Convergence at Surface is: -1.31 °. Hilcorp Energy Company Deep Creek Unit 15 October, 2015 • 10:36 Page 40/5 COMPASS Ladder Plot I I I I I I I I I I I I I I I I I I I I I I I I I I I I � I I I I 1200-I I I I I I I I I 0 0 J LEGEND c O HappyValleyA-10,HV#10,HV#10 VO 800— tp $ HappyValleyB-12,HIV#12,W#12 V0 a � ♦- HappyValley&13,HV#13,HV#13V0 U) $ HappyValleyB-14,HVB-14,HV6-14VO $ Happy ValleyB-15,HV#15,HV#15V0 C Happy ValleyB-16,HV#16,HV#16V0 U 400— -� Happy ValleyB-16,W#16A,HV#16AV0 $ B-17vvp2a HV N C U 0 0 15 00 3000 4500 6000 7500 Measured Depth (1500 usfUin) 15 October, 2015 • 10:36 Page 40/5 COMPASS I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I I I � I I I I I I I I I I I I I I I I I 15 October, 2015 • 10:36 Page 40/5 COMPASS HALLIBURTON Anticollision Report for Plan: Happy Valley B-17 - HVB-17 wp2a Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor 10.( 8. C/) 3.7 2E 1.2 0.0 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 Meast.red Depth (1500 LtWin) D_- 0 5 Collision Avoidance Req aGo Zone -Stop Drillin Hilcorp Energy Company Deep Creek Unit LEGEND -¢-- FlappyValleyA-10,HV#10,HV#10V0 $ Happy ValleyB-12,HV#12,HV#12V0 $ HappyUalleyB-13,FN#13,HV#13V0 " Happy ValleyB-14,HVB-14,HVB-14V0 $ Happy ValleyB-15,FN#15,HV#15V0 3— HappyUalleyB-16,HV#16,W#16V0 -Ar- HappyUalleyB-16,FN#16A,FN#16AV0 $ FNB-17wp2a 16 October, 2015 - 10:36 Page 5 o/ 5 COMPASS Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, October 27, 2015 9:45 AM To: Monty Myers (mmyers@hilcorp.com); David Duffy (dduffy@hilcorp.com) Subject: Happy Valley B-17 (PTD #215-189) - Spacing Monty and David, Just a heads up for Happy Valley B-17: Conservation Order No. 553 governs the Happy Valley Beluga/Tyonek Gas Pool. Most of the planned well course for B- 17 will lie within portions of Sections 21 and 22, T2S, R13W that are located inside the pool boundary. Reservoir sands opened by B-17 within those portions of Sections 21 and 22 will not require a spacing exception. B-17 will reach total depth in the SW % SW % of Section 15, T2S, R13W. This portion of Section 15 lies outside of the pool, and it is governed by statewide spacing requirements. According to these requirements, any sands opened by B-17 within that portion of Section 15 will need a spacing exception because A-10 lies within 3000' and it is an active gas producer from the same pool. B-16 also lies within 3000' and it also appears to be open to the same pool. Please let me know if you have any questions. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC TRANSMITTAL LETTER CHECKLIST WELL NAME:(" 17 PTD: Development Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: C'rc��_ POOL: 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 onpermit). The permit is approved subject to full compliance with q . Approval to produce/inject is contingent upon issuanc6 df 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 2/2015 WELL PERMIT CHECKLIST Field & Pool DEEP CK, HV BELUGA/TYONEK GAS - 160550 Well Name: HAPPY VALLEY B-17 __ Program DEV Well bore seg ❑ PTD#: 2151890 Company HILCORP ALASKA LLC Initial Class/Type DEV / PEND GeoArea 820 Unit 50420 On/Off Shore On Annular Disposal ❑ Administration 1 Perm it fee attached- _ _ _ _ -------------------------------------- - NA_ _ -------------------------------------------------------------------------- 2 Lease number appropriate_ - - - - - - - -- - ---------- - - --------------- Yes - - - - _ Surface location in CIRI Lease C061589;_top productive interval in CIRI_Lease 0061590-- - - - - - - - - - - - - - - 3 Unique welf-name and number - - Yes - - - - - - TD in_CIRI_Lease_CO61588- - - _ - _ - - - - - - - - - - - - - - - - - - - - - 4 Well located in_a.defined_pool_------------------------ - - - - - --- Yes - - . _ _ _ DEEP CK,_HAPPY VALLEY BELUGA/TYONEK_GAS POOL- 160550, governed by CO No._553------------ 5 Well.located proper distance from drilling unit boundary -- --- Yes V CO 553, Rule 2, Well Spacing:_Spacing units shall be a minimum of 10 acres. The Happy alley - - - _ 6 Well located proper distance from other wells . _------------_ _ - - - - ----- Yes _ _ _ _ _ _ _ Beluga(Tyonek Gas Pool shall not be opened in -any well closer than 1500' to the external _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 Sufficient acreage _avaiIable in -drilling unit - - ------------------ - Yes _ _ _ _ _ _ _ boundaryof the -Deep Creek Unit. Opening_sands_within Sections 21_ & 22 will not require a spacing exception. 8 If deviated, iswellbore plat included Yes _ _ _ Opening BelugalTyoneksands_in SW/4-SW/-4-of Section_ 15 will require a -spacing exception, _ _ - - - - - - - - - 9 Operator onlyaffected party __________- - - - - -- Yes______________ 10 Operator has -appropriate _bond inforce ------ _-- - - - -_ -------------------------- --------.---------- 11 Permit can be issued -without conservation order_ - - - - - - _ _ - - - - - - - - Yes - - - - - - - Exception will be needed if B-17 opens Beluga/Tyonek_sandS_in SW/4 SW/4 Section 15-- - - - - - - - - - - - - - Appr Date 12 Permit_ can beissued -without administrative- approval _ - - - - _ - - - . - - - - - Yes - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 13 Can permit be approved before 15 -day wait- - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - SFD 10/27/2015 14 Well located within area and -strata authorized by_ Injection Order # (put_ 10# in -comments)- (For_ _NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ..... - - - - - - - - - - - - - - 15 All wells -within 1/4_mile_area_of review identified (For service well only)_ _ . - . _ _ - - - NA_ - - _ - - - - - - - - - - -- - - - - - - - - - - - - 16 Pre -produced injector: dur_ation_of pre --production less than 3 months_ (For service well only) - NA_ _ _ - - _ - _ - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 _N_onconven. gasconforms to AS31:05:030Q.1.A),(1.2.A-D) - - - - - - - - - - - - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 Conductor string- provided _ - _ _ _ _ Yes _ _ _ - - _ - 16" conductor to be set at -120 ft md_ - _ - . Engineering 19 Surface casing_ protects all -known USDWs - _ _ - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ _ - _ 9 5/8" surface -casing will be set and -fully -cemented at 3000_ft_ and - - - - - -- - - - - - - - _ _ 20 CMT.vol adequate to circulate_on conductor & surf_csg - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - _ - - - - - - - - - - - - - - - - - - - _ - - _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ - - - - - - - - - - - 21 CMT vol adequate to tie-in -long string to -surf csg_ _ _ - - - - - - _ _ - ------------ - - - Yes - 5 1/2" production casing_will be cemented back to 2500 ft._md. _Also_using swe11_pack_er ._ - - - - - - - - - - - - - -- 22 CMT_willcoverallknown_productivehorizons- - - - - - - - - - - - - - - - _ Yes - - _ _ _ _ - - - _ - - - - - - - - _ _ _ _ - _ _ _ - - - - - - - _ - - - -- - - - - - _ - - - - - - - 23 _C_asing desgns adequate for C,_T, B &_ permafrost ------------ - - - - - - - - - Yes - - - _ - _ - BTC calculations provided. Values_ meet industry standard_s---------- - - - - - - - - - - - _ _ _ _ - _ _ _ _ _ _ _ 24 Adequate tankage -or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - Yes _ _ - - - _ _ Rig has steel pits.. All waste will be transported to KGF G &_I - _ - - _ - - - _ _ - - - _ _ _ _ _ - _ _ _ _ _ - - - - 25 If_a_re-drill, has_a 10-403 for abandonment been approved _ _ _ _ - - - - - - NA_ - - Grassroots gas well-- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 26 Adequate wellbore separation _proposed _ - - - - - - - ------------- - - - - _ _ - - Yes _ - - - - - - Anti -collision report -provided.. No issues with close crossings -on pad. - 27 If_diverter required, does it meet regulations- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ - - - - - - - Diverter waived_pe[ 20_AAC 25.035 (h)(2) ., 500 ft from closest surface -casing point on pad, Appr Date 28 Drilling fluid- program schematic & equip Iist_adequat_e- - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - _ _ Max formation_ press= 434 -8 -psi- ( 8.3 ppg_EMW) Will drill with 9-1.0_ppg mud ._ - - - - - _ - - - _ _ _ - _ _ _ _ _ _ _ _ _ GLS 10/27/2015 29 BOPEs,_do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - . - - - _ Saxon 169_has 11 "BOPE , 3 rare and_1_annular, - _ _ _ _ _ - - _ - - - _ _ _ - - - _ _ _ _ _ _ _ - _ _ - _ _ - - 30 BOPE_press rating appropriate; test to -(put psig in comments)- - - - - - - - - - - - - - - - - - - - Yes _ _ - - - - - MASP= 3337 psi -Will test BOPE to 4500 psi 1 annular to 2500 psi) _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 Choke_manifold complies WAR RP -53 (May 84)_ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - _ Yes - - - - - - - ch_oke skematic_provided---------------- 32 Work will occur without operation shutdown_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - After well completion_a CBL and charted MIT -1A are required_( Swell packer). - _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 33 Js presence of H2S gas probable_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - N_o-------- H2S not expected..- Rig has_sensors_and alarms. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 34 Mechanical_condition of wells within AOR verified (For service well only_) - - - - - - - - - - - - - - NA_ _ _ _ _ _ _ _ _ _ _ - _ - - - - - - - _ - - - - - - - - - - - -------------------------------------------- 35 Permit can be issued w/o hydrogen sulfide measures- - - - - - - - - - - - - - - - - - - - - - - - -Yes _ _ - _ _ _ _ Nearby_wells did not encounter_H2S_gas._Measures not required._ -------------- Geology 36 Data -presented on potential overpressure zones _ - _ _ _ - - - - - - - - - - - - _ - - - _ Yes _ _ _ _ _ _ _ Planned mud weights appear_adequate_to control the_ operator's forecast of -most likely pore pressures_ - _ - - - Appr Date 37 Seismic analysis - - -shallow gas zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - - N_ - _ _ _ _ _ _ _ presented in_the geologic prognosis. No abnormally geo-pressured strata are anticipated._ - - - - - - - _ _ _ _ _ _ _ SFD 10/27/2015 38 Seabed condition survey (if off_ -shore) _ - - - - - - _ NA_ _ _ - _ _ 39 Contact name/phone for weekly_progress reports_ [exploratory only] _ - _ _ - _ NA_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Engineering Public As planned, B-17 well will reach total depth in the SW '% SW 'Y4 of Section 15, T2S-R13W. This portion of B-17 will lie outside of Date: Date Date Happy y g y Opening y 9 y p q Commissioner: Com issioner Commissioner the defined Ha Valle Belu a/T onek Gas Pool. O enin of an Belu a/T onek sands in this portion of Section 15 will require a spacing exception under statewide spacing rules. SFD 1 Happy Valley B-17 50-231-20049-00-00 Deep Creek Unit Kenai Peninsula Borough, Alaska November 28, 2015 – December 13, 2015 Provided by: Approved by: David Buthman Compiled by: Donna New Ralph Winkelman Paul Webster Distribution Date: January 18, 2016 2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ............................................................................................... 3 1.1 Equipment Summary.................................................................................................................... 3 1.2 Crew .......................................................................................................................................... 3 2 GENERAL WELL DETAILS ................................................................................................................ 4 2.1 Well Objectives ........................................................................................................................... 4 2.2 Hole Data ................................................................................................................................... 5 2.3 Daily Activity Summary ................................................................................................................ 6 3 GEOLOGICAL DATA ....................................................................................................................... 10 3.1 Lithostratigraphy ....................................................................................................................... 10 3.2 Lithology Details ........................................................................................................................ 11 3.3 Sampling Program ..................................................................................................................... 29 4 DRILLING DATA .............................................................................................................................. 30 4.1 Surveys .................................................................................................................................... 30 4.2 Bit Record ................................................................................................................................ 35 4.3 Mud Record .............................................................................................................................. 36 4.4. Drilling Progress ........................................................................................................................ 37 5 SHOW REPORTS............................................................................................................................ 38 6 DAILY REPORTS ............................................................................................................................ 39 Enclosures 2” / 100’ Formation Log (MD/TVD) 5” / 100’ Formation Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) Final Data CD 3 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Computers – Surface Logging (3) Rigwatch Server, Rigwatch Remote DML, LWD WITS, Rigwatch Remote 0 Ditch gas QGM gas trap; Flame ionization total gas & chromatography. Hook Load / Weight on bit WITS from Pason 0 Mud Flow In Calculated value derived from Strokes/Minute and Pump Output 0 Mud Flow Out WITS from Pason 0 Pit Volumes, Pit Gain/Loss WITS from Pason 0 Pump Pressure WITS from Pason 0 Pump Stroke Counters (2) WITS from Pason 0 Rate of Penetration Calculated from Pason 0 RPM WITS from Pason 0 Torque WITS from Pason 0 WITS To/ From Pason Rigwatch Remote (HP Compaq) 0 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML030 Logging Geologists Years1 Days2 Sample Catchers Years Days2 Donna New 9 15 Karen Austin 4 11/25 Ralph Winkelman 24 11/25 Chad Record 8 11/25 Paul Webster 36 12/9 *1 Years experience as Mudlogger *2 Days at wellsite between rig up and rig down of logging unit. 4 2 GENERAL WELL DETAILS 2.1 Well Objectives HV B-17 is a build and hold directional grassroots development well to be drilled off of the Happy Valley B pad. Reservoir analysis and subsurface mapping has identified an optimal location for infill development of the Middle Tyonek sands. Primary undepleted reservoir objectives are Lower Beluga, Upper Tyonek. T-40, T-80 and T- 155 sands. The base plan is a directional wellbore with a kick off point at 600’ MD. Maximum hole angle will be 21 deg. And TD of the well will be 10694’ MD/ 10111’TVD, ending with a 16 deg inclination left in the hole. Vertical section will be 3279’. Operator: HILCORP ALASKA, LLC Well Name: Happy Valley B-17 (HVB-17) Field: Happy Valley Field County: Kenai Peninsula Borough State: Alaska Company Representatives: Rance Pederson, Shane Hauck, Shane Barber, Marvin Rogers Location: Surface Coordina tes 2947’ FNL, 406’ FEL, Sec 21, T2S, R13W, SM, AK Ground ( Pad ) Elevation 593.5’ AMSL Rotary Table Elevation 611.5’ AMSL Classification: Single Zone Development Gas API #: 50-213-20049-00-00 Permit #: 215-189 Rig Name/Type: Saxon 169 / Land / Double Spud Date November 28, 2015 Total Depth Date: December 13, 2015 Total Depth 10695’ MD / 10117.52’ TVD Primary Targets Lower Beluga, Upper Tyonek, T-40, T-80, T-155 Primary Target Depths (5867/5588),(5956/5672),(7794/7424),(8871/8449),(10326/9846) Total Depth Formation: Tyonek Completion Status: 5 1/2” Casing LWD-MWD Services. Halliburton / Sperry Drilling Services Directional Drilling Halliburton / Sperry Drilling Services Drilling Fluids Service Halliburton / Baroid Wireline Logging Service Schlumberger 5 2.2 Hole Data Hole Section Max Depth TD Formation MW ppg Dev oinc Csg Dia Shoe Depth LOT ppg MD (ft) TVD (ft) MD (ft) TVD (ft) 12 ¼” 2980’ 2855.16’ Beluga 9.5 21.45 9 5/8” 2970’ 2845’ 12.0 8 ½” 10695’ 10117.52’ Tyonek 9.4 12.58 5 1/2” 10631’ 10056’ 6 2.3 Daily Activity Summary 11/27/2015: Rig up and adjust catwalk; install weatherization tarps; work on electric and breaker for test pump; work on steam system; build spud mud; test BOP; test diverter with state witness; buoy line 112’ from ignition 98’; bag close 43 seconds; knife 12 sec; koomy operating pressure 3100psi; bleed to 1500 200 psi increase 19 sec; full recovery 96 sec; 4 bottles @ 2625psi; test PVT Gain/Loss flow alarms - Total Safety Alarms; rig up and tear down rig acceptance check list; function test mud pump; check emergency kill pressure; pressure test stand pipe kelly hose; stage tubulars and strap; install wear bushing. Work on communication to rig smart; calibrate tracking and communication equipment; detangle climbing assist; straighten up floor; pick up singles of HWDP; and rack back in derrick; pick up 55 singles of new drill pipe and make, torque, break, re-dope, make, torque, break and rack back in derrick; pick up 45 joints of previously run drill pipe and rack back in derrick. 11/28/2015: Continue to pick up and rack back drill pipe while changing pulsation dampener on mud pump #2; pick up BHA #1; drill from 128’ to 221’; pull out of hole and pick up smart tools; pump through to warm up tools, down load tools; up load data to LWD; safety meeting on installing nukes; shallow test MWD. Return to drilling; rotate from 221’ to 493’; Pooh from 493’ to 190’; Trip in hole from 190’ to 493’; Picking up NMFC and Jars on the way in/ no fill. Rotate 493’ to 565’, slide 565’ to 590’; rotate 590’ to 623’, slide 623’ to 644’; rotate 644’ to 687’, slide 687’ to 709’, rotate from 709’ to 753’. 11/29/2015: Drill from 753’ to 1497’. Circulate bottoms up for wiper trip; pull out of hole from 1497’ to 765’ with no issues; hole took 0.6 barrels over calculated fill. Trip back to bottom and resume drilling; Drill from 1497’ to 1622’; slide from 1622’ TO 1637’, rotate from 1637’ to 1840’; rotate from 1840’ to 2244’, circulate hole clean for short trip. 11/30/2015: Make short trip; pull out of hole from 2244’ to 1454’ no issues; run in hole from 1454’ to 2241’, 9’ of hole fill; hole took 1.3 barrels under calculated displacement. Drill from 2244’ to 2752’ pumped nut plug sweep at 2430’. Rotate from 2752’ to 2878’ circulate cut tings out of hole, remove clamp from quill, break connection between saver sub and double ball valve sub; break saver sub out of stump with iron roughneck and rack stand back; install new saver sub; circulate while installing back up clamp; run stand back in hole; rotate from 2878’ to 2980’; circulate two bottoms up. Pull out of hole 12/1/2015: Remove sources and down load; lay down BHA; clean floor and prepare to run in hole; Run in hole and clean out tight spot at 2334’/; kelly up and wash through; no issues; no fill; 2.4 barrels under calculated displacement; pump high vis nut plug sweep and circulate hole clean; pump second sweep and circulate hole clean. Trip out from 2980’ to 1440’ with no issues. POOH from 1440’ to the bit; scrape clay off of bit and stabilizers, drain motor and flush with water before laying it down, no issues hole took 4.4 barrels over calculated displacement; clean rig floor; and rig up wire line equipment and tools; Run in hole for RFT log; valid test =10; unstabilized=13; tight tests= 8; POOH with wireline total tool assembly length=31’; rig down wireline tools and equipment; service top drive; crown, blocks, and draw works; Pick up previous bit and motor and make up 8” flex collars. 12/2/2015: Continue picking up BHA for clean out run; run in hole from 107’ to 2980’; pump high vis sweep and circulate out; POOH from 2980’ to 2011’; POOH from 2011 to 202’; lay down 8” directional tools, flex collars, mud motor, and bit; clean and organize rig floor; suck out cellar box and remove wear bushing; rig up Weatherford casing running equipment. Continue to rig up Weatherford; set up pipe racks and stage shoe track; stage centralizers, pre-job safety meeting with crew and Weatherford; pick up shoe track and check float. Run in hole with casing; condition mud and circulate; stage mud pump up to 7 bbls per minute; continue to run in hole with casing to 2943’; condition mud and circulate ; stage pump up to 7 barrels per minute; change out short bails to long bails; pick up and make up landing joint and hanger. 7 12/3/2015: Rig up cross over and cement head circulating while rigging up Schlumberger cementers; pump 10 barrels of water to pits and 2 barrels to well; shut down and shut in for pressure test; pump cement; shut down and drop top plug and bump plug and held for 5 minutes; checked float and did not hold; bleed back 2.5 barrels; shut in head and hold 450psi; bumped plug at 12:18 hours; clean up cement truck back to cellar; suck out cellar box with vac truck; flush out diverter with black water; flush cement lines with water and blow down lines with air ; rig down cement lines; waiting on cement to set up; nipple down diverter line; install choke hose to catwalk; continue to nipple down diverter line; flow bleeder line, knife valve and koomey lines, 4 bolt flanges; install kill line to mez. valve; clean work area; function and wash bag; bleed pressure off of accumulator; rig down and lay down cement head; clear rig floor; pull landing joint and make up pack off run tool; set pack off; continue to nipple down diverter stack; remove knife valve, bell nipple, annular bag,; divert “T”, DSA, stage and nipple up well head. 12/4/2015: Continue to nipple up BOP’s; install 2’ spacer spool and 16” spacer spool; pick up and make up BOP’s on spacer spools; install kill line on mezzanine deck; install kill HCR, inside choke and choke HCR on BOP’s ; Torque bolts on flanges; continue torqueing bolts on flanges; install catch can, flow line, bell nipple, install choke hose to BOP’s; hook up bleed off line to flow line; connect BOP chains to support stack; hook up koomey lines; function test BOP’s. Rig up test equipment; flood the stack and choke manifold while removing long bails; Total Safety test alarms. Recalibrate gas detectors; shell test; re-torque flange between inside kill and HCR kill; fix hydro leak on HCR kill; retest shell - good test; Test upper pipe rams, annular; lower pipe rams, TIW, and Koomey draw down test; test coke manifold; blind rams; inside kill; electric choke; and manual choke; rig down and blow down test equipment; blow down choke manifold and kill line; install wear bushing. 12/5/2015: Pick up 90 joints of drill pipe and run in to 2842’- tagged cement at 2842’; pull out of hole from 2842’ to 994’ pull out to flex collar; strap and tally drill pipe; pick up 64 joints drill pipe; and pull out and rack back in derrick. Continue to pull out and rack back in derrick; ready floor to pick up BHA; PJSM with crew and Halliburton; blow down kill line; Pick up and make up BHA; T/TM collar; circulate and warm tools; down load tools; strap and tally drill pipe; shallow test MWD tool; PJSM with crew and Halliburton; load source; blow down top drive; continue to pick up and make up BHA. Run in hole with HWDP; turn elevator, input pipe tally, pick up drill pipe from cat walk; break in new pipe threads to 2630’. 12/6/2015: Continue picking up drill pipe from 2630’ to 2812’; circulate bottoms up to air out drill pipe and casing; rig up to test casing; test casing to 3300psi; hold pressure for 30minutes; rig down test equipment; slip and cut 90’ of drill line; drill out float equipment; continue to drill out float equipment and 20’ of new formation; displace with 9.3 ppg KCl mud; Rig up to perform FIT to 414 psi , bleed down to 300 psi in 10 minutes; pumped 17.58 gals and bleed 10gals back; rig down test equipment; drill from 3000’ to 3202’ Continue to drill ahead with occasional slides from 3202’ to 3616’ midnight depth. Drill from 3616’ to 3997’; pull off bottom and flow check well; Begin wiper trip. POOH on elevators from 3990’ to 3614’. 12/7/2015: Continue with wiper trip from 3714’ to 3234’; washing and reaming from 3234’ to 2967’; rig service ; change our grabber dies on TDS; change out saver sub; run in hole from 2967’ to 3937’ and wash last stand to bottom; drill from 3997’ to 4114’; drill from 4114’ to 4568’. Drill from 4568’ to 4992’; prep for wiper trip take survey, stand back one stand, blow down top drive; flow check well; POOH from 4992’ to 2944’. 12/8/2015: Drill from 5056’ to 5490’; drill from 5490’ to 5801’; circulate bottoms up; POOH from 5801’ to 4462’; continue to POOH from 4462’ to 3898’. Run in hole from 3898’ to 5790’; kelly up and wash down 10’ of fill; drill ahead from 5801’ to 6060’ midnight depth. 12/9/2015: Drill from 6060’ to 6606’, Pump high vis sweep and circulate bottoms up (w/50% increase in cuttings); perform short trip from 6606’ to 5046’ (tight spots at 5627’-5607’, 5305’, 5237’, and 5225’). RIH from 8 5046’ to 6527’ (tagged hole fill), wash and ream from 6527’ to 6606’ (had 25’ hole fill). Drill from 6606’ to 7412’. Pump high vis sweep and circulate bottoms up . Begin short trip at 7412’. 12/10/2015: Monitor well, well static. POOH on elevators from 7412’ to 5801’. 2.5 barrels lost to hole. Tight spots at 7073’ (20k over), 7062’ (25k over), 6780’-6760’ (60k over), 6750’ (60k over), 6469’ (50k over), 6399’ (40k over), 6379’ (60k over), 6373’-6367’ (20k over), 6353’-6349’ (40k over), 6345’-6341’ (40k over), and 6266’ (20k over). Service rig. RIH on elevators from 5863’ to 7333’. Wash from 7333’ to 7412’. Drill from 7412’ to 8222’. Pump high vis sweep, circulate bottoms up (60% increase in cuttings).Unable to break out connection, break out saver sub and inspect same. Rack back one stand, rig up headpine and circulate (inconclusive). Make up new saver sub, reset top drive torque to 4150 psi and 21504 ft lbs/torque. POOH from 8159’ to 6545’ (Back ream 7165’-7034’). Service rig. RIH on elevators from 6604’ to 8104’. 12/11/2015: Finish RIH on elevators from 6604’ (ream 8104’ to bot tom). Drill from 8221’ to 9028’, pump high seep and circulate bottoms up (150% increase in cuttings). Wipe hole from 9028’ to 7484’ (no tight spots). RIH form 7464’ to 8977’ (tagged ay 8977’). Wash down from 8977’ to 9028’. Drill from 9028’ to 9287’. 12/12/2015: Drill from 9287’ to 9484’. Rack back one stand, condition mud and circulate, change out swab in mud pump #2. RTB. Drill from 9484’ to 9851’. Pump high vis sweep and circulate bottoms (200% increase in cuttings). Wipe hole from 9851’ to 8275’ (no tight spots). RIH from 8275’ to 9826’ (tagged up). Ream to bottom. Drill from 9851’ to 10232’. Pump high vis sweep, circulate ~37 minutes (150% increase in cuttings). Drill from 10232’ to 10295’. 12/13/2015: Drill from 10295’ to 10397’, pumped walnut sweep with 50% increase in cuttings. Drill from 10397’ to 10695’TD. Circulate bottoms up at TD. Pump 18 barrel high vis sweep and circulate out same (75% increase in cuttings). POOH from 10695’ to 9115’. Pump dry job. POOH on elevators from 9115’ to about 4815’. Encounter tight hole, back ream to about 4628’. POOH on elevators from ~4628’ to ~4560’. Back ream from ~4560’ to ~3465’. POOH on elevators from ~3465’ to 3091’. Break circulation. 12/14/2015: Break circulation. Pump high sweep at 3091’. Pump high vis sweep (100% increase in cuttings). POOH on elevators from 3091’ to 2941’. Slip and cut drill line. Service rig. Lay down bad pipe joints. RIH on elevators from 3941’ to 8472’. Circulate while cooling down rad cooling fan for Eaton brake and hydraulics. RIH from 8472’ to 10649’ (tagged on hole fill), wash to bottom; Pump high vis sweep and circulate out; Continue circulate high vis sweep out; Pumped second high vis sweep and circulate out, weight up to 9.7 ppg; POOH on elevators from 10695’ to 2944’. Flow check well. Check TDS, tong, iron wrench (all good). POOH on elevators from 2944’ to 2547’. 12/15/2015: POOH on elevators from 2547’ to 166’. Handle and lay down BHA. Change out rubber air bag on bell nipple/clean off rig floor. Hold JSA meeting with rig and Schlumberger wireline crew. Rig up wireline equipment. RIH with RFT logging tools (took 5 impressions 3096’-3265’). RIH with RFT logging tools (took 8 impressions 3940’-4424’). RIH with RFT logging tools to 6724’, to 7910’. Tagged up on bridge at 7910’ and could not RIH further. Took a total of 45 impressions with 32 good impressions. POOH with RFT wireline tools. Rig down Schlumberger wireline equipment. Clear rig floor, stage dumb iron assembly. Pick up and make up BHA. Pick up 2 joints from catwalk. RIH on elevators to 2903’. Fill pipe, circulate and warm mud at shoe. Service rig. RIH on elevators from 2909’ to 5147’. 12/16/2015: RIH on elevators from 5147’ to 9294’ (tight spots 7920’, 8296’, 8427’, wash and ream from 9035’ to 9050’ and from 9166’ to 9183’). RIH (tight 9294’, 9370’, 9555’ with spot washing and reaming required). Wash and ream from 9555’ to 10695’. Pump sweep, rotate and reciprocate out sweep. POOH from 10695’ to 8990’ (tight spots at 9952’, 9940’, 9885’, and 9683’). RIH from 8990’ to 10671’. Wash from 10671’ to 10696’ (25’ fill). Pump high vis sweep and circulate hole clean (seep arriving 103 barrels late). Pull 2 stands, check flow (OK). Pump dry job. POOH, laying down drill pipe from 10582’ to 8741’. 12/17/2015: POOH, laying down drill pipe from 8741’ to 2860’ (encounter 15k overpull at 6450’ and 6098’, hole taking 9 barrels over calculated hole fill). Cut and slip 110’ drill line. Lay down drill pipe from 2860’ to bit (hole 10.3 barrels over calculated fill volume for entire trip). Pull wear bushing and install test plug. Change upper 9 pipe rams to 5 ½”. Test upper rams 250 psi for 5 minutes / 4500 psi for 10 minutes. Dummy run hanger = good land. Clear rig floor, stage casing centralizers. Rig up Weatherford power tongs, air slips, spider. Fill up line stage shoe track. Hold JSA. Run 5 ½” liner to about 1750’. 12/18/2015: Run 5 ½” casing from about 1750’ to 5950’. Reciprocate and circulate to turn mud over (Max Gas = 110u). RIH with 5 ½” casing from 5950’ to 8585’. Reciprocate and circulate to turn mud over (Max Gas = 318u). Make up swell packer. RIH with 5 ½” casing from 8585’ to 10608’. Pick up and make landing. RIH and land out at 10631.58’. Condition and circulate mud (Max Gas = 441u). Pick up and rig up Weatherford equipment. Circulate and condition mud. 10 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Tops provided by Hilcorp Geologist, Dave Buthman FORMATION PROGNOSED ACTUAL MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) Blg-135 5867’ 5588’ -4978 5,982 5,664 -5,054 Tyonek 5956’ 5672’ -5062’ 6,089 5,763 -5,153 T-10 6545’ 6234’ -5624’ 6,676 6,311 -5,701 T-17 6908’ 6580’ -5970’ 7,010 6,623 -6,013 T-40 7794’ 7424’ -6814’ 7,922 7,473 -6,863 T-70 8819’ 8400’ -7790’ 8,911 8,403 -7,793 T-80 8871’ 8449’ -7839’ 8,946 8,437 -7,827 T-120 9668’ 9214’ -8604’ 9,731 9,191 -8,581 T-155 10326’ 9846’ -9236’ 10,434 9,864 -9,254 11 3.2 Lithology Details As per Hilcorp direction, a Canrig-provided full service mudlogging program, with lithology descriptions of interval-collected rock cuttings samples in the Sterling, Beluga and Tyonek Formations , was initiated at the spud (128’ MD / 128’ TVD). The Kenai Group formations of Alaska’s Cook Inlet Basin, which include the Sterling , Beluga, and Tyonek were deposited in a variable-energy fluvial system within a large closed fore-arc basin. The stratigraphic column consists of very dominant thin to massive sections of sandstone and claystone -siltstone , which are interrupted by extensively-distributed thinner zones of coal and carbonaceous rocks, locally to generally abundant thin layers of original and re-deposited volcanic ash, and minor beds of basal or modal conglomerate. Gradational upward-fining sequences and bi-modal zones are abundant within the sandstones. Stratovolcanoes, perpetually forming along the fore-arc’s margins; produced abundant widely-distributed deposits of vitric air fall volcanic ash; which became a major directly-derived source, and/or a consistent lithogenic influence, for all Tertiary soft- sediment rocks in the Cook Inlet Basin. Note that the special modifying term “tuffaceous” in Canrig Lithology Descriptions was created to address the diversity of volcanic-origin rocks in the Cook Inlet basin, and its use may include everything from discernible micro-shard concentrations of disaggregated volcanic glass to rare layers of vitric ignimbrite. Sand/ Conglomerate/ Gravel (138' - 220') = medium to medium dark gray overall with individual liths dominantly black, dark gray, greenish gray, green, clear to translucent quartz; very fine upper to rock fragments (30+mm), dominantly very coarse; angular, shattered fragments to well rounded, dominantly subangular; poorly sorted; unconsolidated. Sand (220' - 300') = very light gray to medium dark gray; framework predominantly translucent to opaque white to very light gray quartz; fine to medium grain; moderately to poorly sorted; sub rounded to sub angular; sphericity moderately high; predominantly unconsolidated with occasional large firmly friable specimens; argillaceous cementation; sparse matrix material and predominantly grain supported; interstices well filled; poor visible porosity; lithics less than 1%. Tuffaceous Siltstone (300'- 360') = very pale gray to very pale orange; stiff consistency; dense tenacity; fracture sub planar to sub hackly; cuttings habit irregular to sub wedge like; luster dull to occasional waxy when scored with probe; texture silty to very slightly silty; structure massive; very fine laminar inclusions of carbonaceous material. Carbonaceous Material (300' - 420') = black to very dark gray; easily crunched; fracture sub blocky to sub planar; cut habit tabular to blocky to very thin laminar; luster dull to slightly resinous texture smooth to very slightly silty with occasional slightly sandy; very thinly laminated structure; commonly very thinly interbedded with siltstone, sandstone, and tuffaceous sandstones and siltstones. Conglomeratic Sand (390'- 510') = very light gray to light grayish white; framework translucent and transparent colorless to white quartz with common opaque white to whitish gray grains and occasion light blue, light green, and medium orange grains; trace muscovite/phlogopite; very fine to upper very coarse; poorly sorted; sub angular to sub rounded; sphericity mod to moderately high; unconsolidated to very easily friable; sparse to no cementation; sparse tuffaceous matrix; grain supported; occasionally very interbedded with very thin laminar carbonaceous material. Tuffaceous Claystone (510' - 560') = very light gray to light grayish brown with occasional pale yellowish brown; stiff consistency; dense tenacity; sub planar to slightly earthy fracture; cut habit massive rounded to massive irregular slightly wedge like; luster dull to earthy; texture smooth to slightly silty with occasional slightly gritty; structure predominantly massive with common specimens showing thin laminar inclusions of carbonaceous material. 12 Sand (560' - 710') = medium gray to medium dark gray; occasional light gray to whitish gray; framework mostly white translucent quartz to transparent colorless quartz with common gray, light blue, light green, medium orange grains; dark gray lithics approx. 5%; trace micas includes readily discernible muscovite and chlorite; very fine grains to upper medium and lower coarse grains; poorly to moderately poorly sorted; sub angular to sub rounded with occasional angular; sphericity moderately high to occasionally high; rare surface abrasions; unconsolidated for the most part with rare preserved easily friable specimens; no cementation or matrix evident; preserved specimens show little to no interstitial voids and predominantly poor visible porosity; inclusions of thin laminae carbonaceous ma terial occasionally as well as occasional tuffaceous component evident; interbedded with tuffaceous siltstones and tuffaceous clays. Tuffaceous Siltstone (720' - 780') = medium gray to light medium gray; consistency stiff and fairly dense; tenacity barely crumbly; fracture sub planar to firm earthy; cuttings habit rounded massive; luster dull and earthy with occasional slightly sparkling in specimens with trace sand; texture silty to slightly gritty on occasion; structure massive with occasional very thin laminae of carbonaceous material; associated with and commonly interbedded with tuffaceous claystones and tuffaceous sandstones. Tuffaceous Claystone (780' - 850') = light gray to medium gray; clumpy sticky consistency; malleable tenacity; semi liquid fracture; cuttings habit rounded lumps deforming with pressure of gravity; luster dull and earthy; texture very smooth; structure massive; interbedded with tuffaceous sandstone and tuffaceous siltstones; washes from sample fairly easily. Sand/ Sandstone (850' - 930') = light to very light gray overall with individual grains dominantly clear to trans lucent quartz and volcanic glass with trace black, orange and green liths; very fine lower to trace medium lower, dominantly fine lower; moderately well sorted; dominantly disaggregated with light gray sandstone; very fine; angular to subangular; soft; grain supported; non calcareous. Sand (930' - 990') = medium light to light gray with individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray to greenish gray, black, pale rose, rust and orange; angular to subangular; very fine upper to very coarse upper, dominantly coarse; poorly sorted; unconsolidated; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (990' - 1050') = light gray to very light gray with light yellowish gray secondary hues; shapeless, globular cuttings; soft; sticky; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble; moderately expansive; poor cohesiveness; fair adhesiveness; non calcareous; trace coal/ carbonaceous material; no outgassing detected. Sand/ Conglomeratic Sand/ Sandstone (1050' - 1120') = medium light gray overall with abundant multicolored liths, dominantly clear to translucent quartz and volcanic glass, medium to dark gray, black, rust, orange, pale rose, light to medium green to greenish gray; very fine upper to trace very coarse upper, dominantly medium upper to coarse lower; angular to subangular; poorly sorted; dominantly unconsolidated with trace sandstone; hard to brittle; medium to coarse grain; angular; abundant multicolored liths with a yellowish gray to tan hue from slight to moderate calcareous cement. Tuffaceous Claystone/ Tuffaceous Siltstone (1120' - 1180') = light gray to very light gray with light yellowish gray secondary hues; shapeless, globular cuttings; soft; sticky; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble; moderately expansive; poor cohesiveness; fair adhesiveness; non calcareous; trace coal/ carbonaceous material; firm to very hard; black; blocky to platy; planar fracture dominant; trace outgassing bubbles observed. Sand (1180' - 1240') = medium light to light gray with individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray to greenish gray, black, pale rose, rust and orange; angular to subangular; very fine upper to medium upper, dominantly fine; poorly sorted; unconsolidated; trace thin coal beds. 13 Sand (1240' - 1300') = medium light to light gray with abundant multicolored lit hs, dominantly clear to translucent quartz and volcanic glass, light to dark gray, greenish gray, black, rust and dusky red; very fine upper to medium lower, dominantly fine; angular to subangular; moderately well to very well sorted; unconsolidated; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (1300' - 1350') = light gray to very light gray with light yellowish gray secondary hues; shapeless, globular cuttings; soft; sticky; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble; moderately expansive; poor cohesiveness; fair adhesiveness; non calcareous; present as minor component of dominantly unconsolidated sands. Sand (1350' - 1410') = medium light to light gray with a moderate salt and pepper appearance with abundant multicolored liths, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, black, greenish gray and trace dusky red and rust; very fine lower to coarse lower, dominantly fine upper to medium upper; angular to subangular; poor to fair sorting; unconsolidated; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (1410' - 1470') = light gray to very light gray with light yellowish gray secondary hues; shapeless, globular cuttings; soft; sticky; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble; moderately expansive; poor cohesiveness; fair adhesiveness; non calcareous; present as minor component in dominantly loose sands and acts as loose supporting matrix at times. Sand/ Conglomeratic Sand/ Sandstone (1470' - 1550') = medium light gray overall with abundant multicolored liths, dominantly clear to translucent quartz and volcanic glass, medium to dark gray, black, rust, orange, pale rose, light to medium green to greenish gray; very fine upper to very coarse upper, dominantly medium upper to coarse lower; angular to subangular; poorly sorted; dominantly unconsolidated with trace sandstone; hard to brittle; medium to coarse; angular; moderately calcareous cement. Tuffaceous Claystone (1550' - 1620') = light gray to medium gray; consistency gelatinous to mushy; thin runny easily washed away to sticky and malleable; cuttings habit rounded to irregular lumps; luster dull and earthy; texture smooth to slightly silty; structure massive; occasional thin laminar inclusions of carbonaceous material; associated and interbedded with tuffaceous sandstones and siltstones and thin stringers of coal and carbonaceous material. Coal (1620' - 1650') = black to blackish gray with occasional brownish black; firmly crunchy tenacity; fracture sub planar to planar with occasional slightly conchoidal; cuttings habit predominantly tabular with occasional platy to flaky; luster resinous to sub vitreous; texture smooth; structure thinly laminated; thin beds within tuffaceous sandstones; tuffaceous siltstones and tuffaceous claystones. Tuffaceous Siltstone (1650' - 1740') = light gray to light medium gray; dense but easily crunched tenacity; fracture sub hackly to sub planar; cuttings habit wedgelike to irregular massive; luster dull and earthy; texture silty to very slightly gritty; structure massive; associated with thinly interbedded tuffaceous sandstones and claystones as well as thin coals. Tuffaceous Sandstone (1740' - 1850') = light gray to light medium gray with occasional whitish gray to pale orangish gray; frame work predominantly quartz translucent white to pale gray and transparent colorless to white occasional light blue; light green; pale orange, moderate pink, dark green, and black grains; very fine to upper medium grained; poorly sorted; sub angular to sub rounded; sphericity moderate high; minimal abrasion of grain surfaces; predominantly unconsolidated with rare preserved very soft specimens; weak tuffaceous cementation with sparse to no matrix material evident; grain supported; interstice moderately well to well filled yielding poor visible porosity; bedding massive; dark lithic clasts 3% to 5%; trace micaceous accessory probably muscovite. 14 Tuffaceous Claystone (1850' - 1920') = very light gray to light medium gray; gelatinous to sticky consistency; malleable to soft and runny tenacity; fracture very wet earthy; cuttings habit slightly stiff to runny blobs; luster dull and earthy; texture smooth to very slightly silty with trace to occasional slightly gritty due to entrained sand; structure massive; associated with and thinly interbedded with tuffaceous sandstone and tuffaceous siltstones as well as occasional very thinly bedded coals. Tuffaceous Sandstone (1920'- 1980') = light gray to light medium gray with occasional whitish gray frame work predominantly translucent white to pale gray quartz and colorless to white transparent quartz with occasional light blue; light green; pale orange; dark green, and traces very pale pink; very fine to upper medium grained; mod to poorly sorted show poor visible porosity sub rounded to sub angular; minor to no abrasion of grain surfaces; predominantly unconsolidated with rare preserved easily friable specimens; trace tuffaceous cementation with no matrix material evident; mostly grain supported; bedding massive; trace mica accessory probably muscovite. Carbonaceous Shale/ Coal (1980' - 2020') = black to very dark gray with trace brownish black to brownish gray; brittle crunchy tenacity; sub planar to sub conchoidal fracture; cuttings habit blocky to tabular; luster resinous to vitreous; texture smooth; thinly laminated structure; Tuffaceous Claystone (2000' - 2160') = very light gray to light medium gray; gelatinous to gummy consistency; malleable to soft pliable tenacity; fracture earthy; cuttings habit stiff blobs to runny blobs; luster dull and earthy; texture smooth to very slightly silty with traces of included sand stringers yielding gritty texture on occasion; structure massive; associated with thinly interbedded tuffaceous sandstones and tuffaceous siltstones and occasional thinly bedded coals. Carbonaceous Shale/ Coal (2160' - 2244') = black to grayish black with occasional brownish black; tenacity very firmly crunchy to brittle; fracture mostly sub planar occasional conchoidal; cut habit blocky to tabular occasionally elongate; luster vitreous to resinous; texture smooth; very thinly laminated structure. Tuffaceous Claystone/ Tuffaceous Siltstone (2244' - 2310') = medium light gray; shapeless, globular cuttings; very soft; very sticky; slimy; mushy; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble; slight to moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous trace thin coal beds; black with brownish black secondary hues; hard; brittle at times; blocky to platy; plana r fracture dominant; weak outgassing present. Sand (2310' - 2360') = medium to medium light gray with individual grains dominantly medium to dark gray, clear to translucent quartz and volcanic glass, greenish gray; fine lower to trace medium lower, dominantly fine upper; angular to subangular; moderately well sorted; unconsolidated; present as loose grains supported by very soft tuffaceous claystone; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (2360' - 2420') = medium light gray; shapeless, amorphous cuttings; very soft; very sticky; slimy; mushy; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble; slight to moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous commonly supporting loose sand grains. Sand (2420' - 2490') = medium to medium dark gray with moderate salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass, light to medium greenish gray; very fine upper to trace coarse upper, dominantly fine upper to lower; angular to trace subrounded, dominantly subangular; fair to good sorting; disaggregated; non calcareous; abundant clay acting as supporting matrix for loose sand grains. Sand/ Sandstone (2490' - 2550') = medium to medium dark gray with a salt and pepper appearance, individual grains dominantly medium to dark gray, clear to translucent quartz and volcanic glass, black and trace greenish gray; very fine upper to coarse lower, dominantly fine lower to medium lower; angular to subangular; dominantly unconsolidated with trace salt and pepper sandstone; hard; fine to medium; fair sorting; moderately calcareous cement; medium gray sandstone; very fine; very hard; very calcareous. 15 Tuffaceous Claystone/ Tuffaceous Siltstone (2550' - 2610') = medium light gray; shapeless, globular cuttings; very soft; very sticky; slimy; mushy; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble; slight to moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace thin coal beds. Sand (2610' - 2680') = medium to medium dark gray with moderate salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass, light to medium greenish gray; very fine upper to very coarse lower, dominantly fine upper to medium lower; angular to subangular; poor to fair sorting; dominantly disaggregated; non calcareous; trace thin coal beds. Tuffaceous Claystone/ Tuffaceous Siltstone (2680' - 2740') = medium light to light gray with very light gray secondary hues; very soft; very sticky; shapeless, globular cuttings; silty to clayey texture; dull to greasy luster; slimy to mushy; hydrophilic; very soluble; moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace thin coal beds. Sand (2740' - 2800') = medium to medium dark gray with individual grains dominantly medium to dark gray, clear to translucent quartz and volcanic glass, greenish gray; fine lower to coarse lower, dominantly fine upper; angular to subangular; moderately well sorted; unconsolidated; present as loose grains supported by very soft tuffaceous claystone; non calcareous; trace thin coals. Tuffaceous Claystone/ Tuffaceous Siltstone (2800' - 2840') = medium light gray; shapeless, globular cuttings; very soft; very sticky; slimy; mushy; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble; slight to moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace thin coal beds. Tuffaceous Sandstone (2840' - 2910') = light gray to light medium gray; predominantly translucent white to pale gray opaque quartz grains with occasional transparent colorless; occasional light blues and greens, pale pinks and oranges; very fine to lower medium grained; moderately to poorly sorted; sub rounded to sub angular slight to no abrasion of grain surfaces; predominantly unconsolidated with rare preserved easily friable specimens; grain supported; associated with thin coals/carbonaceous shales and clays. Tuffaceous Claystone (2910' - 2980') = light gray to light medium gray; sticky, lumpy consistency; tenacity soft and easily washed away; cuttings habit deformed clumps; luster dull to earthy; texture smooth; structure massive. Tuffaceous Claystone/ Tuffaceous Siltstone (2980' - 3100') = medium light gray to light gray with light yellowish gray and very light olive gray secondary hues; very soft to slightly firm; irregular to wedgelike with trace PDC bit action shaped cuttings; silty to clayey texture; dull to slightly waxy luster; hydrophilic; moderately soluble and expansive; fair to good cohesiveness; poor to fair adhesiveness; trace dark brown to black microthin carbonaceous laminations and inclusions; trace thin coal beds Sand/ Sandstone (3100' - 3180') = medium to medium dark gray with salt and pepper appearance, individual grains dominantly medium to dark gray, black, light gray and clear to translucent quartz and volcanic glass; very hard and brittle to crunchy; very fine lower to medium lower, dominantly fine; angular to subangular; poor to fair sorting; moderate to very calcareous cement; trace ashy matrix supported grains; very light gray to grayish white; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (3180' - 3240') = medium light gray to light gray with light yellowish gray and light brownish gray secondary hues; very soft to slightly firm; irregular to wedgelike with trace PDC bit action shaped cuttings; silty to clayey texture; dull to slightly waxy luster; hydrophilic; moderately soluble and expansive; fair to good cohesiveness; poor to fair adhesiveness; trace dark brown to black microthin carbonaceous laminations and inclusions; non calcareous. 16 Sand (3240' - 3300') = medium to medium dark gray with weak salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass, and light to medium greenish gray; very fine upper to trace very coarse upper, dominantly fine upper to medium upper; angular to trace subrounded, dominantly subangular; poor to fair sorting; disaggregated; non calcareous; trace thin coal beds. Tuffaceous Claystone/ Tuffaceous Siltstone (3300' - 3360') = medium light to light gray with trace very light brownish gray secondary hues; very soft to slightly firm; irregular to sub tabular shaped cuttings; silty to clayey texture; dull, earthy to slightly waxy luster; slight to moderately soluble; hydrophilic; fair to good cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. Sand (3360' - 3420') = medium gray to light gray with occasional medium dark gray; frame work predominantly translucent colorless to whitish gray quartz and medium gray to dark gray reworked lithics; very fine to upper fine; moderately well sorted; subangular to sub round; sphericity high to moderately high, slight surface abrasion; unconsolidated; no evidence of cementation or matrix; associated with thinly bedded tuffaceous claystones and tuffaceous siltstone with occasional very thin stringers of coal and/or carbonaceous shale, grades to siltstone. Tuffaceous Siltstone (3420' - 3500') = light gray to medium gray; crumbly to very slightly crunchy tenacity; fracture earthy to slightly hackly; cuttings habit massive slightly rounded to rounded wedge like; luster dull and earthy; texture slightly to moderately silty; structure massive; associated with tuffaceous claystone; both with abundant tuffaceous component. Tuffaceous Claystone (3500' - 3560') = light gray to medium gray with common whitish gray; consistency gelatinous to pasty and sticky; tenacity soft to semi solid; no fracture; cuttings habit mostly lumpy to blobby; luster dill to earthy; texture smooth to slightly silty structure massive; thinly interbedded with tuffaceous siltstone and occasionally unconsolidated sandstone. Tuffaceous Siltstone (3420' - 3500') = light gray to medium gray; easily crumbled to slightly firmer with a very slightly crunchy tenacity; fracture irregular and slightly hackly to earthy; cuttings habit rounded wedge like to rounded sub tabul ar; luster dull to earthy; texture silty; structure mass; interbedded with tuffaceous claystone. Coal (3600' - 3630') = very dark gray to black with trace brownish black; tenacity firmly crunchy and brittle to moderate crunchy; fracture sub planar and blocky to trace conchoidal; cuttings tabular to blocky to occasionally elongate or splintery with trace slightly wedge like; luster vitreous to resinous texture smooth; structure thinly laminated; moderately to poorly developed. No visible outgassing observed. Tuffaceous Siltstone (3630' - 3800') = medium gray to light gray with trace medium dark gray; tenacity easily crunched to firmly crumbly; fracture moderately hackly to firmly earthy; trace slightly irregular; cuttings habit mostly wedge like with trace PDC imbrication; luster dull to earthy; texture slightly to moderately gritty; structure massive; interbedded with tuffaceous claystone and trace thin sandstones. Trimodal Sandstone (3780' - 3830') = first mode: light gray to medium gray; very fine to upper fine, well sorted; subangular to sub rounded; high sphericity; mostly unconsolidated; predominantly quartz and re-worked lithi cs; second mode: very dark gray to medium gray with white speckles; very fine to fine grain; well sorted; sub rounded; high sphericity; very hard; mostly quartz and very dark lithics; silica cementation; interstices very well filled; grain supported; no vi sible porosity; third mode white to very pale gray; course translucent colorless quartz in very fine grained white granular non calcareous matrix; very soft; no visible cementation; interstices well filled; poor visible porosity; not lithic clasts. 17 Tuffaceous Siltstone (3830' - 3900') = medium gray to medium dark gray; easily crumbled to slightly crunchy; fracture; sub planar to slightly hackly; habit wedge like to sub tabular; luster dull to earthy; texture moderat ely silty to occasional very silty; massive structure; associated with interbedded tuffaceous claystone and trace to occasional thin lenses sandstone with all very tuffaceous; non calcareous. Tuffaceous Claystone (3900' - 3997') = medium gray to light gray; consistency gelatinous to fairly stiff and pasty; tenacity soft to slightly crumbly; fracture none to slightly hackly to slightly earthy in the interior less washed portion of each cutting; cuttings habit spherical blob like; luster dull; texture clayey to slight silty; structure massive. Sand (4000' - 4050') = medium to medium dark gray with weak salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass, and light to medium greenish gray; very fine upper to trace coarse upper, dominantly fine upper to medium upper; angular to trace subrounded, dominantly subangular; poor to fair sorting; disaggregated; non to moderately calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (4050' - 4110') = medium light to light gray with light brownish gray secondary hues; very soft to slightly firm; irregular to shapeless, globular cuttings; silty to clayey texture; dull to slightly waxy luster; hydrophilic; moderately soluble and expansive; poor to fair adhesiveness; poor cohesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in firmer fragments. Sand (4110' - 4170') = medium to medium dark gray with individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass, trace greenish gray; very fine upper to medium lower, dominantly fine; angular to subangular; fair to good sorting; dominantly unconsolidated with loose grains supported in claystone; non calcareous; trace thin coal beds. Sand/ Sandstone (4170' - 4230') = medium to medium dark gray with salt and pepper appearance, individual grains dominantly medium to dark gray, black, light gray and clear to translucent quartz and volcanic glass; very hard and brittle to crunchy; very fine lower to medium lower dominantly fine; angular to subangular; fair to good sorting; moderate to very calcareous cement; trace thin coal beds. Tuffaceous Claystone/ Tuffaceous Siltstone (4230' - 4300') = medium light to light gray with light brownish gray secondary hues; very soft to slightly firm; irregular to shapeless, globular cuttings; silty to clayey texture; dull to slightly waxy luster; hydrophilic; moderately soluble and expansive; poor to fair adhesiveness; poor cohesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in firmer fragments; scattered medium dark gray siltstone/ sandstone; hard to brittle; very fine ;hard to brittle; very calcareous cement. Tuffaceous Claystone/ Tuffaceous Siltstone (4300' - 4360') = medium light to light gray; very soft; sticky at times; silty to clayey texture; dull to greasy luster; shapeless to globular cuttings; hydrophilic; poor cohesiveness; fair adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in rare firm fragments. Sand/ Sandstone (4360' - 4420') = medium to medium dark gray with a weak salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass very fine upper to medium upper, dominantly fine upper to medium lower; angular to subangular; poor to fair sorting; dominantly unconsolidated with very fine sandstone; hard; medium dark gray; well sorted; very calcareous cement. Tuffaceous Claystone/ Tuffaceous Siltstone (4420' - 4480') = medium light to light gray; very soft; sticky at times; silty to clayey texture; dull to greasy luster; shapeless to globular cuttings; hydrophilic; poor cohesiveness; fair adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in rare firm fragments. 18 Sand (4480' - 4540') = medium to medium dark gray with individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass trace greenish gray; very fine upper to medium lower, dominantly fine; angular to subangular; fair to good sorting; dominantly unconsolidated with loose grains supported in claystone; non calcareous; trace thin coal beds. Tuffaceous Claystone/ Tuffaceous Siltstone (4540' - 4610') = medium light to light gray with light brownish gray secondary hues; very soft to slightly firm; irregular to shapeless, globular cuttings; silty to clayey texture; dull to slightly waxy luster; hydrophilic; moderately soluble and expansive; poor to fair adhesiveness; poor cohesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in firmer fragment s; scattered medium dark gray siltstone/ sandstone; hard to brittle; very fine; hard to brittle; very calcareous cement. Sand/ Sandstone (4610' - 4680') = medium to medium dark gray with a weak salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass very fine upper to coarse lower, dominantly fine upper to medium lower; angular to subangular; poor to fair sorting; dominantly unconsolidated with very fine sandstone; hard; medium dark gray; well sorted; very calcareous cement; trace thin coal beds. Tuffaceous Claystone (4680' - 4800') = light gray to medium gray w/occasional slightly lighter gray; consistency stiff to gelatinous with occasional pasty; tenacity malleable to occasional very slightly crumbly; fracture muddy to runny; cuttings habit massive semispherical domelike blobs; luster dull to earthy; texture smooth to very slightly silty; structure massive with occasional very thin dark discontinuous laminae moderate to strong tuffaceous component. Tuffaceous Siltstone (4740' - 4830') = light gray to medium gray w/ occasional medium dark gray; slightly crumbly to slightly crunchy tenacity; fracture sub planar to slight hackly, occasionally slightly irregular; cuttings habit wedgelike with slightly rounded edges to sub tabular also with rounded edges; luster dull to earthy; texture slightly silty to moderately silty structure massive with occasional very thin discontinuous laminae of dark brownish carbonaceous material. Carbonaceous Shale (4830' - 4990') = very dark brownish gray to black, firmly crunchy to brittle, occasional very firm, occasional easily crunched, occasional planar parting; cuttings habit wedge like to irregular tabular with occasional slightly blocky, occasional elongated and slightly to moderately splintery; texture smooth to slightly silty; structure thinly laminated; grades to coal; associated and thinly interbedded within tuffaceous claystone, tuffaceous siltstone and thin lenses and beds tuffaceous sandstone; sparse short duration out gassing observed in the best developed coals. Sand (4860’ -4900') = light gray to medium gray, occasional dark gray, occasional salt and pepper appearance; very fine to upper fine grained; moderately well sorted; sub angular to sub rounded; sphericity high; predominantly unconsolidated; matrix when present mostly tuffaceous; occasional trace silica cement in well preserved harder specimens; grain supported; interbedded with thin carbonaceous shales and coals as well as tuffaceous claystones and tuffaceous siltstones. Tuffaceous Siltstone (4900' - 5100') = light gray to light medium gray; tenacity crumbly to slightly crunchy; fracture sub planar to slightly earthy; cutting habit mostly wedge like to sub planar; luster dull to earthy; texture silty to occasionally slightly sandy due to thin discontinuous lenses sand; interbedded w/ thin carbonaceous shales grading to thin sof t coals. Carbonaceous Shale/ Coal (5100' - 5160') = very dark brown to brownish black with occasional black; tenacity moderately tough to easily crunched; fracture hackly to slightly earthy; cuttings habit slightly wedge like to tabular with occasional sub tabular to slightly irregular occasional planar parting; luster resinous to vitreous; texture smooth to slightly silty; structure very thinly laminated; the carbonaceous shale grades to coal with occasional very well developed specimens showing conchoidal fracture; blocky habit; vitreous luster; hard to brittle tenacity; thin laminated structure; sparse, short duration, outgassing seen. 19 Sand (5160' - 5230') = medium gray to medium light gray with a moderate salt and pepper appearance, individual grains dominantly light to medium gray, clear to translucent quartz and volcanic glass, dark gray to black; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; disaggregated with trace very fragile grain supported sandstone; fine; light gray; fragile; non calcareous; trace thin coal beds throughout interval. Tuffaceous Claystone/ Tuffaceous Siltstone (5230' - 5300') = medium light gray to light gray with very light olive gray secondary hues; very soft to moderately firm; sticky; mushy; irregular to shapeless, amorphous cuttings; silty to clayey texture; dull to greasy and waxy luster; hydrophilic; moderate to very soluble; moderately expansive; poor to fair cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in firmer fragments; trace thin coal beds. Sand/ Sandstone (5300' - 5370') = medium to medium dark gray with strong salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass very fine upper to medium upper, dominantly fine upper to medium lower; angular to subangular; poor to fair sorting; dominantly unconsolidated with very fine sandstone; hard; medium dark gray; well sorted; very calcareous cement. Tuffaceous Claystone/ Tuffaceous Siltstone (5370' - 5430') = medium light gray to light gray with very light olive gray secondary hues; very soft to moderately firm; sticky; mushy; shapeless to trace PDC bit action shaped; silty to clayey texture; dull to greasy and waxy luster; hydrophilic; moderate to very soluble; moderately expansive; poor to fair cohesiveness; fair to good adhesiveness; non calcareous; trace thin coal beds. Coal/ Carbonaceous Shale (5430' - 5490') = black with brownish black secondary hues; very firm to hard and brittle; blocky to planar fracture dominant; platy to tabular; smooth texture; resinous luster; trace prolonged outgassing bubbles observed; coal present as thin beds in dominantly tuffaceous claystone/ siltstone formation with interbedded sands. Sand/ Sandstone (5490' - 5550') = medium to medium light gray with a weak salt and pepper appearance, individual grains dominantly light to dark gray, black, clear to translucent quartz and volcanic glass; very fine lower to medium upper, dominantly fine upper to lower; angular to subangular; moderately well sorted; dominantly disaggregated with light gray sandstone; fine; fragile to brittle; moderate to very calcareous cement; trace thin coal beds throughout interval. Tuffaceous Claystone/ Tuffaceous Siltstone (5550' - 5610') = medium light gray; irregular, sub tabular to rounded cuttings; soft to slightly firm; silty to clayey texture; dull to slightly waxy luster; slight to moderately soluble and expansive; hydrophilic; poor adhesiveness fair to good cohesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace thin coal beds. Sand (5610' - 5680') = medium gray to medium light gray with a moderate salt and pepper appearance, individual grains dominantly light to medium gray, clear to translucent quartz and volcanic glass, dark gray to black; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; disaggregated with trace very fragile grain supported sandstone; fine; light gray; fragile; moderately calcareous; trace to common thin coal beds throughout interval. Tuffaceous Claystone/ Tuffaceous Siltstone (5680' - 5740') = medium light gray to light gray with very light olive gray secondary hues; very soft to moderately firm; sticky; mushy; shapeless to trace PDC bit action shaped; silty to clayey texture; dull to greasy and waxy luster; hydrophilic; moderate to very soluble; moderately expansive; poor to fair cohesiveness; poor to fair adhesiveness; non calcareous; trace to common thin coal beds. 20 Coal/ Carbonaceous Shale (5740' - 5800') = black with brownish black secondary hues; very firm to hard and brittle; blocky to planar fracture dominant; platy to tabular; smooth texture; resinous luster; trace prolonged outgassing bubbles observed; coal present as thin beds in dominantly tuffaceous claystone/ siltstone formation with interbedded sands. Tuffaceous Siltstone (5800' - 5870') = light gray to medium gray with traces very pale orangish gray; tenacity easily crunched to slightly crumbly; fracture slightly hackly to slightly earthy; cuttings habit predominantly wedge like with occasional sub tabular; luster dull to earthy; texture silty to occasionally slightly gritty; structure massive w/ very thin discontinuous laminae of carbonaceous shale. Tuffaceous Claystone (5870' - 5930') = medium gray with common light gray; consistency mushy too stiff with common pasty; tenacity malleable to semi-solid; fracture none to earthy; cuttings habit spherical to slightly flattened; dull to earthy luster; texture smooth to occasionally slightly silty; structure amorphous. Sandstone/ Sand (5910' - 6000') = light gray to medium dark gray; frame work predominantly translucent to transparent color les quartz with abundant medium gray to light gray lithic fragments; upper very fine to upper fine with rare lower medium grains; well to fairly well sorted; sub rounded to sub angular; sphericity high to moderately high; easily friable with abundant loose grains; argillaceous/tuffaceous matrix material; mostly matrix supported with rare grain supported; interstices well filled; trace thin laminae of carbonaceous material. Tuffaceous Siltstone (6000' - 6070') = light gray to medium gray ; tenacity slightly crumbly to easily crunched; fracture slightly hackly to earthy; cuttings habit mostly wedge like with rounded edges to sub tabular also with rounded edges, trace PDC imbrication; luster dull to earthy; texture silty to occasionally slightly gritty; structure massive w/ very thin discontinuous laminae of carbonaceous shale. Tuffaceous Claystone (6070' - 6130') = medium gray with common light gray; consistency mushy to occasionally slightly firm, tacky to sticky; tenacity malleable to stiff; fracture slightly earthy to sample is cut with probe rather than fractured; cuttings habit massive rounded with most nearly spherical; luster dull and earthy; texture smooth to slightly silty with occasional gritty due to minor sand component; occasional very thin discontinuous laminae of carbonaceous material. Sand/ Sandstone (6130' - 6210') = very pale whitish gray to medium dark gray with abundant light gray; very fine to fine grained; well sorted; sub round to sub angular; sphericity high; very easily friable to abundant loose grains with occasional specimens very firmly friable (especially the darkest gray specimens); cementation none to rare silica cemented examples; grain support; interstices moderately well filled; up to 50% lithics in occasional specimens; interbedded with tuffaceous claystones and tuffaceous siltstones. Tuffaceous Siltstone (6210' - 6290') = light gray to medium gray with occasional medium dark gray; tenacity slightly crunchy to moderately crunchy; fracture sub planar to occasionally earthy; cuttings habit wedge like to sub tabular; luster dull to earthy; texture silty to trace slightly sandy due to small sand lenses; structure thinly laminated to massive; occasional thin discontinuous lenses of carbonaceous material; thinly interbedded with increasing argillaceous sandstones and sand. Sandstone/ Sand (6290' - 6410') = very light gray to medium gray with occasional to fairly common whitish gray specimens; very fine to upper fine with rare lower medium grains; well to fairly well sorted; sub round to sub angular; sphericity moderate high to high; common abraded grain surfaces with scarce to no pitting; predominantly loose grains with occasional very small preserved specimens; argillaceous to tuffaceous matrix; no evident cement; grain supported; interstices moderately well filled; decreased lithics up to 5%; thinly interbedded coal and carbonaceous shales common; decreased thin laminar tuffaceous claystones and tuffaceous siltstones; associated with increase in gas. 21 Carbonaceous Shale (6390' - 6470') = very dark gray to dark grayish brown; slightly crumbly to moderately crunchy; fracture earthy to sub planar with occasional hackly and occasional planar parting; poorly to mod developed fissility; cuttings habit mostly sub tabular to slightly blocky with occasional slightly wedge like; luster dull to resinous with occasional slight sparkle; texture predominantly smooth with trace slightly silty material entrained at boundaries of laminations; structure thinly laminated; thinly laminated with in massive sands and thin tuffaceous siltstones and tuffaceous claystones. Tuffaceous Claystone (6470' - 6550') = light gray to medium gray w/ occasional slightly darker gray and occasional trace light orangish gray; consistency stiff paste to stiff; fracture earthy to very slightly irregular hackly; cuttings habit mostly slightly spherical; luster dull and earthy; texture smooth to slightly silt with occasional trace of very fine sand stringers providing slight gritty texture; structure massive with trace very thin laminae carbonaceous material and thicker laminae of coals and carbonaceous shales; trace out gassing seen in coals and carbonaceous shales. Sand/ Sandstone/ Tuffaceous Sandstone (6550' - 6660') = medium to medium light gray overall with a salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, black and light greenish gray; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; loosely consolidated to disaggregated; sandstone; firm to hard and brittle; very fine to medium; very calcareous cement; trace ashy matrix supported grains; very soft; pulverulent; non calcareous; trace to common thin coal beds throughout. Sand/ Tuffaceous Sandstone (6660' - 6730') = light to very light gray overall, individual grains dominantly clear to translucent quartz and volcanic glass, trace dark gray to black; very fine lower to medium lower, dominantly fine; angular to subangular; very well sorted; very loosely supported from ashy matrix; very soft and fragile; pulverulent ; dirty white with darker gray secondary hues; visible glass shards; non to slightly calcareous. Tuffaceous Siltstone/ Tuffaceous Claystone (6730' - 6790') = medium light gray to light gray with light yellowish gray and light brownish gray secondary hues; soft to slightly firm; irregular to sub tabular with PDC bit action shaped cuttings common; silty to slightly gritty texture; dull to earthy luster; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. Sand/ Sandstone/ Tuffaceous Sandstone (6790' - 6850') = medium to medium light gray overall with a salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, black and light greenish gray; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; loosely consolidated to disaggregated; sandstone; firm to hard and brittle. Coal/ Carbonaceous Shale (6850' - 6910') = black with brownish black secondary hues; very firm to hard and brittle; massive to blocky and platy; planar fracture dominant with trace conchoidal and birdeye; smooth to slightly gritty and silty; earthy to vitreous; bituminous and grading to a carbonaceous shale; firm; dark brown; trace to common outgassing bubbles present in coal and some less developed shale. Tuffaceous Claystone/ Tuffaceous Siltstone (6910' - 6980') = medium light gray to light gray with light yellowish gray and light brownish gray secondary hues; soft to slightly firm; irregular to sub tabular with PDC bit action shaped cuttings common; silty to slightly gritty texture; dull to earthy luster; non calcareous; moderately soluble; fair to good cohesiveness; poor adhesiveness; trace dark brown to black microthin carbonaceous laminations and inclusions. Sandstone/ Tuffaceous Sandstone (6980' - 7040') = medium light to gray with a strong salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, dark gray to black and light greenish gray; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; moderately well consolidated with calcareous and non-calcareous cement; hard to brittle and soft and pulverulent; common ashy matrix. 22 Tuffaceous Sandstone (7040' - 7100') = very light gray to grayish white with streaky dark brown and black secondary hues; soft to pulverulent; irregular shaped cuttings; fragile; non calcareous ashy matrix supports very fine to very coarse sand grains; individual grains dominantly clear to translucent quartz and volcanic glass, trace dark liths; well sorted in fine range; friable; angular to subangular. Tuffaceous Siltstone/ Tuffaceous Claystone (7100' -7160') = medium light gray to light gray with light yellowish gray and light brownish gray secondary hues; soft to slightly firm; irregular to sub tabular with PDC bit action shaped cuttings common; silty to slightly gritty texture; dull to earthy luster; non calcareous; trace light yellowish gray siltstone grades between sandy siltstone and silty sandstone; very firm to brittle; non calcareous; trace thin coal beds throughout interval. Tuffaceous Claystone (7160' - 7240') = medium dark gray, medium to brownish gray, occasional light gray, light yellowish gray; blocky to very slightly platy cuttings; slight to moderate firm; easily to moderately firm; dull luster; finely grainy texture; occasional thin interbeds of carbonaceous seams and organic matter; grades evenly to tuffaceous siltstone; occasionally abundant coal associated with high gas zones. Sand/ Sandstone (7240' - 7300') = dominantly clear, common black, occasionally white; sandstone overall very light gray to off white; lower fine to upper medium; dominant upper fine to lower medium; moderately sorted; angular to subrounded, dominant subangular; dominantly moderate to occasional low sphericity; dominant quartz, common mafic-rich grains, occasional feldspar. Sand (7300' - 7350') = clear, common to occasional black, occasional white; upper fine to upper coarse, dominant upper medium; moderately to poorly sorted; angular to subrounded, dominant subangular; dominant moderate to occasional low sphericity; probably all sandstone in situ; dominant quartz, common to occasional mafic-rich grains; occasional feldspar. Tuffaceous Claystone/ Siltstone (7350' - 7390') = brownish gray, dark medium to medium gray; rounded, blocky cuttings; slight to moderate firm; easily to moderately crumbly; dull luster; finely grainy to grainy texture; occasional to common interbedding with other lith types; grade evenly to each other. Tuffaceous Sandstone (7390' - 7470') = very light gray; rounded to slightly angular cuttings; moderate to mushy, dominant easily friable; lower very fine to upper medium; dominant fine; moderate sorting; dominant matrix-support with ashy volcanic debris, occasional grain-packed; dominantly quartz, common mafics, feldspar. Tuffaceous Sandstone (7470' - 7530') = very light gray; rounded cuttings; soft to slightly firm; easily friable; lower very to upper medium, dominant fine; moderate to well sorted; angular to subrounded, dominantly subangular; dominant moderate to occasional low sphericity; matrix- supported with abundant ashy volcanic material; dominant quartz, common mafic-rich grains, feldspar. Tuffaceous Claystone/ Siltstone (7530' - 7580') = medium to medium light gray to brownish gray secondary hue, grading to grayish brown; blocky cuttings; slight to moderate firm; easily to moderately crumbly; dull luster; very fine grainy to finely grainy texture; occasional bedding contact with arenites; appears organic-rich. Sandstone (7580' - 7630') = very light gray with dark gray secondary hues; rounded cuttings; easily to moderately friable; lower fine to upper medium, dominantly fine; moderately sorted; angular to subrounded, dominantly subangular; moderate sphericity; grain to matrix support; grades to tuffaceous sandstone; dominant quartz, common mafics, occasional feldspar. 23 Tuffaceous Claystone/ Tuffaceous Siltstone (7630' - 7700') = medium to medium light gray with light gray and dark brownish gray secondary hues; soft to firm to very firm and hard; irregular to wedge to trace PDC bit action shaped cuttings; silty to clayey to slightly gritty texture; dull, earthy to waxy luster; slight to moderately soluble and expansive; fair to good cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace to common thin coal beds throughout interval. Coal/ Carbonaceous Shale (7700’ - 7770') = black with brownish black and dark brown secondary hues; very firm to hard and brittle; massive; blocky to platy; planar fracture dominant with trace conchoidal and birdeye; smooth to slightly gritty texture; earthy to vitreous luster; trace to common, vigorous outgassing bubbles present; coal is bituminous and grades down to a less developed carbonaceous shale with more brown hues. Tuffaceous Claystone/ Tuffaceous Siltstone (7770' - 7840') = medium light to light gray with light yellowish gray and light olive gray secondary hues; irregular to wedgelike and PDC bit action shaped cuttings; soft and fragile to very firm; silty to clayey texture to slightly gritty; dull. earthy to waxy luster; slight to moderately soluble and expansive; fair to good cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; light yellowish gray siltstone commonly grades between sandy siltstone and silty sandstone; firm to friable; grain supported. Tuffaceous Claystone/ Tuffaceous Siltstone (7840' - 7910') = medium to medium light gray with light gray and dark brownish gray secondary hues; soft to firm to very firm and hard; irregular to wedge to trace PDC bit action shaped cuttings; silty to clayey to slightly gritty texture; dull, earthy to waxy luster; slight to moderately soluble and expansive; fair to good cohesiveness; poor adhesiveness; non calcareous. Coal/ Carbonaceous Shale (7910' - 7960') = black with brownish black and dark brown secondary hues; very firm to hard and brittle; massive; blocky to platy; planar fracture dominant with trace conchoidal and birdeye; smooth to slightly gritty texture; earthy to vitreous luster; trace to common, vigorous outgassing bubbles present; dominantly bituminous. Sand/ Tuffaceous Sandstone (7960' - 8030') = light gray to very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass trace darker liths; very fine lower to fine upper, dominantly fine lower; angular to subangular; very well sorted; unconsolidated with scattered ashy matrix supported grains; light grayish white; very fragile; pulverulent; non calcareous; thin coal beds common. Tuffaceous Sandstone (8030' - 8090') = very light gray to grayish white with abundant darker weak secondary hues; very fragile and pulverulent; irregular, subrounded cuttings; ashy matrix acts as supporting matrix for loose sands; clear to translucent quartz and volcanic glass with trace darker liths; very fine lower to trace very coarse upper, dominantly fine; angular to subangular; moderately well sorted; non calcareous; trace to common thin coal beds throughout. Tuffaceous Claystone/ Tuffaceous Siltstone (8090' - 8160') = medium to medium light gray with light gray and dark brownish gray secondary hues; soft to firm to very firm and hard; irregular to wedge to trace PDC bit action shaped cuttings; silty to clayey to slightly gritty texture; dull, earthy to waxy luster; slight to moderately soluble and expansive; fair to good cohesiveness; poor adhesiveness; non calcareous. Coal/ Carbonaceous Shale (8160' - 8220') = black with brownish black and dark brown secondary hues; very firm to hard and brittle; massive; blocky to platy; planar fracture dominant with trace conchoidal and birdeye; smooth to slightly gritty texture; earthy to vitreous luster; trace to common, vigorous outgassing bubbles present; dominantly bituminous. Sandstone (8235’ - 8270') = light gray to very light gray; rounded cuttings; easily to moderately friable; lower very fine to upper coarse; poorly sorted; angular to subrounded, dominant subangular; moderate sphericity; grain to matrix supported; dominant quartz, common mafic-rich grains. 24 Tuffaceous Siltstone (8300' - 8335') = brownish gray, light to very light gray; blocky cuttings; soft and mushy to moderate firm and crumbly; dull luster; finely grainy texture; no evident structure; coarsens upward to dirty, very fine to fine sandstone; occasional grading to tuffaceous claystone. Sandstone (8345' - 8400') = brownish gray to very light gray; irregular cuttings; dominant soft, mushy, and very argillaceous to occasional moderately firm and friable; dominant very to occasional lower medium (fining down to siltstone); moderately sorted; angular to subrounded, dominant subangular; moderate sphericity; dominant argillaceous matrix-supported to occasional grain-packed; dominant quartz, common to occasional mafic-rich grains, occasional feldspar. Tuffaceous Siltstone/ Claystone (8410' - 8450') = dominant light gray, common medium gray, occasional brownish gray; rounded cuttings; dominant slight to occasional moderate firm; dominant easily to occasional moderately crumbly; dull luster; very finely grainy to grainy texture; grading evenly to each other; coarsens up to sandstone. Sandstone (8460' - 8505') = medium gray to light gray with common brownish hues; lower very fine to lower fine; well sorted; angular to subrounded, dominant subangular; moderate sphericity; abundant argillaceous matrix; dominant soft and easily friable to occasional moderate firm and friable; dominant quartz, common to occasional mafic-rich grains, occasional feldspar. Tuffaceous Sandstone (8515' - 8545') = very light gray; dominant soft and easily friable to occasional moderate firm and friable; lower very fine to lower medium, dominant fine; supported by ashy matrix; dominant quartz, common to occasional mafic-rich grains. Tuffaceous Siltstone (8555' - 8585') = light to medium gray, brownish gray; blocky to slightly tabular cuttings; slight to very firm; easily to slightly crumbly; dull luster; finely grainy texture; no evident structure; grades to both tuffaceous claystone and sandstone. Sand/ Tuffaceous Sandstone (8585' - 8650') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace dark gray, black and light greenish gray; very fine lower to medium lower, dominantly fine upper to lower; angular to subrounded, dominantly subangular; well sorted; dominantly unconsolidated with ashy matrix supporting individual grains; grayish white with darker secondary hues very soft; friable; pulverulent; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (8650' - 8720') = medium light to light gray with light yellowish gray and light olive gray secondary hues; irregular to wedgelike and PDC bit action shaped cuttings; soft and fragile to very firm; silty to clayey texture to slightly gritty; dull earthy to waxy luster; slight to moderately soluble and expansive; fair to good cohesiveness; fair adhesiveness; non calcareous; common thin coal beds throughout interval. Coal/ Carbonaceous Shale (8720' - 8780') = black with brownish black and dark brown secondary hues; very firm to hard and brittle; massive; blocky to platy; planar fracture dominant with trace conchoidal and birdeye; smooth to slightly gritty texture; earthy to vitreous luster; trace to common, vigorous outgassing bubbles present; dominantly bituminous; abundant carbonaceous shale; dark brownish gray; silty. Sand/ Tuffaceous Sandstone (8780' - 8840') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace dark gray, black and light greenish gray; very fine lower to medium lower, dominantly fine upper to lower; angular to subrounded, dominantly subangular; fair sorting dominantly uncons olidated with ashy matrix supporting individual grains; grayish white with darker secondary hues very soft; friable; pulverulent; non calcareous. 25 Tuffaceous Sandstone/ Sand/ Sandstone (8840' - 8900') = very light gray to dirty white with abundant darker secondary hue very soft to slightly firm; fragile to pulverulent; crunchy; irregular shaped; silty to gritty texture; sparkling luster abundant glass shards present; non calcareous; ash matrix supports loose grain sand s; very fine to medium; dominantly clear to translucent quartz and volcanic glass with trace darker liths. Sand/ Tuffaceous Sandstone (8900' - 8970') = very light gray overall with individual grains dominant ly clear to translucent quartz and volcanic glass, trace dark gray, black and light greenish gray; very fine lower to medium lower, dominantly fine upper to lower; angular to subrounded, dominantly subangular; well sorted; very loosely consolidated with ashy matrix supporting individual grains; grayish white with darker secondary hues very soft; friable; crunchy; non calcareous. Coal/ Carbonaceous Shale (8720' - 8780') = black with brownish black and dark brown secondary hues; very firm to hard and brittle; massive; blocky to platy; planar fracture dominant with trace conchoidal and birdeye; smooth to slightly gritty texture; earthy to vitreous luster; trace to common outgassing observed. Sand (8780' - 9090') = light gray to very light gray overall with individual liths dominantly clear to translucent quartz and volcanic glass, trace medium to dark gray to black; very fine lower to trace very coarse upper, dominantly fine upper to medium lower; ang ular to subangular; poorly sorted; dominantly unconsolidated with common ashy matrix supported grains and salt and pepper sandstone; fine to medium; hard to brittle; moderate to very calcareous cement. Tuffaceous Sandstone (9100' - 9140') = very light gray to off-white; rounded cuttings; soft, mushy, easily friable; lower very fine to upper fine; well to moderately sorted; angular to subrounded, dominant subangular; moderate sphericity; dominant quartz, common to occasional mafic-rich grains, all with ashy tuffaceous matrix support. Sand (9150' - 9190') = dominant clear, common to occasional black, translucent; upper very fine to lower coarse, dominant fine; moderately sorted; angular to subrounded, dominant subangular; moderate sphericity; dominant quartz, common to occasional mafic-rich grains; probably all sandstone in situ. Sandstone (9200' - 9255') = light to medium gray; angular to rounded cuttings; slight to very firm; easily to slightly friable; lower very fine to lower coarse, dominant lower fine; moderate sorting; angular to subrounded, dominant subangular; moderate sphericity; dominant argillaceous matrix support to occasional grain packed with occasional calcite cement; dominant quartz, common to occasional mafic-rich grains, occasional feldspar. Sand (9265' - 9300') = dominant clear to translucent, occasional black, trace whitish; upper very fine to upper fine, dominant lower fine; overall well sorted; angular to subrounded, dominant subangular; moderate sphericity overall; dominant quartz, occasional mafic-rich grains, trace feldspar. Tuffaceous Siltstone (9310' - 9345') = medium gray with occasional brownish hues; blocky cuttings; dominant slight to occasional moderate firm; dominant easily to occasional moderately crumbly; dull luster; finely grainy texture; no evident structure; grades to both sandstone and tuffaceous claystone. Coal (9355' - 9380') = black; blocky to angular cuttings; slightly hard but extremely brittle; silky, shiny luster; occasional sub -conchoidal cleavages when broken but no structure; occasionally grades to carbonaceous shale. Sand (9425' - 9460') = dominant clear to translucent, occasional black; lower fine to upper coarse, dominant lower medium; moderately sorted; angular to subrounded, dominant subangular; overall moderate sphericity; dominant quartz, occasional mafic-rich grains, trace feldspar. 26 Tuffaceous Sandstone (9470' - 9500') = very light gray; soft; mushy, easily friable; common lower very fine to occasional lower fine, dominant upper very fine; matrix supported by abundant bentonitic ash; individual grains are dominant quartz, occasional mafics. Sand (9510' - 9545') = dominant clear to translucent, common to occasional white, occasional black; lower very fine to lower fine; overall well sorted; angular to subrounded, dominant subangular; moderate sphericity; dominant quartz, common to occasional feldspar, occasional mafic-rich grains. Tuffaceous Sandstone (9555' - 9595') = very light gray; soft and mushy to slightly firm and easily friable; lower very fine to lower fine; well sorted; rounded cuttings; matrix supported with dominant bentonitic to occasional moderately feldspathic matrix; dominant individual grains quartz, occasional mafic-rich and feldspar grains. Sandstone (9605' - 9660') = light to very light gray; dominant rounded to occasional angular cuttings; moderately firm and friable to occasionally hard and slightly friable; upper very fine to lower fine; well sorted; angular to subrounded, dominant subangular; moderate sphericity; dominant grain-packed with common calcite cement to common with moderately bentonitic matrix-support; dominant quartz, common mafic-rich grains, occasional to common feldspar. Coal (9660' - 9720') = black with brownish black and grayish black secondary hues; firm to hard and brittle; tabular to platy; planar fracture dominant with trace conchoidal and birdeye; smooth to slightly gritty texture; earthy to vitreous luster; dominantly bituminous but occasionally grading to a silty carbonaceous shale; abundant and vigorous outgassing bubbles present. Sand/ Tuffaceous Sandstone/ Conglomeratic Sand (9720' - 9790') = very light gray overall with clear to translucent quartz and volcanic glass dominant, slight trace darker liths; very fine upper to trace very coarse upper, dominantly fine; angular to subangular; very well sorted; dominantly disaggregated with ashy matrix common supporting structure for loose grain sands; trace salt and pepper sandstone; fine; hard; moderate to very calcareous cement. Tuffaceous Claystone/ Tuffaceous Siltstone (9790' - 9850') = medium to medium light gray with light gray and dark brownish gray secondary hues; soft to firm to very firm and hard; irregular to wedge to trace PDC bit action shaped cuttings; silty to clayey to slightly gritty texture; dull, earthy to waxy luster; fair to good cohesiveness; poor adhesiveness; non calcareous; abundant thin coal beds throughout interval. Sand/ Tuffaceous Sandstone/ Conglomeratic Sand (9850' - 9920') = very light gray overall with clear to translucent quartz and volcanic glass dominant, slight trace darker liths ; very fine upper to trace very coarse upper, dominantly fine; angular to subangular; very well sorted; dominantly disaggregated with ashy matrix common supporting structure for loose grain sands; common thin coal beds. Tuffaceous Sandstone/ Sand/ Conglomeratic Sand (9920' - 9980') = very light gray to grayish white with very light brown and grayish black, streaky secondary hue soft to slightly firm; crunchy; irregular shaped cuttings; pulverulent; abundant visible glass shards; non calcareous; ash matrix supports sand grains; very fine to medium lower, dominantly fine; angular to subangular; moderately well sorted; trace very coarse liths. Sand/ Conglomeratic Sand/ Tuffaceous Sandstone (9980' - 10040') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace gray, pale rose and light green to greenish gray; very fine lower to very coarse upper, dominantly fine; angular to subangular; well sorted in fine range; very loosely consolidated with ashy matrix; very fragile white to dirty white; pulverulent; non calcareous; trace thin coal beds. 27 Coal (10040' - 10100') = black with brownish black and grayish black secondary hues; firm to hard and brittle; tabular to platy; planar fracture dominant with trace conchoidal and birdeye; smooth to slightly gritty texture; earthy to vitreous luster; dominantly bituminous but occasionally grading to a silty carbonaceous shale; abundant and vigorous outgassing bubbles present; numerous thin coal beds throughout interval. Tuffaceous Sandstone (10105' - 10155') = very light gray to off white; lower very fine to lower fine; overall well sorted; soft to slightly firm; easily friable; angular to subrounded, dominant subangular; moderate sphericity; bentonitic matrix support; occasionally with less bentonite, grading to grain-packed calcite cemented sandstone; individual grains dominant quartz, common mafic-rich grains, occasional feldsphatic. Sand (10165' - 10205') = dominant clear, common translucent, black; lower very fine to lower medium, dominant lower fine; moderately sorted; angular to subrounded, dominant subangular; overall moderate sphericity; dominant quartz, common mafic-rich grains, occasional feldspar; probably derived from bit -crushed tuffaceous sandstone. Tuffaceous Sandstone (10215' - 10270') = very light gray to off white; lower fine to upper coarse, dominant lower medium; moderately sorted; soft to slightly firm; easily friable; angular to subrounded, dominant subangular; moderate sphericity; bentonitic matrix support with occasional less bentonite, grading to calcite cemented sandstone; individual grains dominant quartz, common mafic- rich grains; occasionally feldsphatic. Coal (10280' - 10300') = black; blocky cuttings; moderate to very firm; brittle to punky; silky, shiny luster; smooth texture; occasionally grading very dark to dark brown carbonaceous shale. Sandstone (10330' - 10375') = dominant medium to occasional light gray; lower very fine to lower fine; well sorted; dominant hard and slightly friable to occasional moderately firm and friable; well sorted; platy cuttings; exists as thin stringers; grain-packed with some calcite cement; occasionally grades to tuffaceous sandstone; dominant quartz, common mafics, occasional feldspar. Sand (10385' - 10420') = dominant clear, common translucent, occasional black, white; lower fine to lower medium; well sorted; common angular to good trace round, dominant subangular to subrounded; dominant moderate, occasional low, good trace high sphericity; dominant quartz, occasional mafic-rich grains, feldspar. Tuffaceous Sandstone (10430' - 10480') = very light gray; slightly firm to soft; easily friable; lower fine to upper coarse, dominantly lower medium; moderately sorted; angular to round, dominant subangular to subrounded, common angular, occasional round; dominant moderate, common low, occasion high sphericity; abundant bentonitic matrix support; individual grains dominant quartz, occasional mafics, feldspar. Coal (10490' - 10515') = black, dominant angular to occasional shardy cuttings; moderately hard to hard; brittle; silky, shiny luster; smooth texture; no evident structure; trace grading to very dark to dark brown carbonaceous shale. Tuffaceous Sandstone (10525' - 10585') = very light gray; rounded to blocky cuttings; slight firm to soft; easily friable to mushy; upper very fine to lower coarse, dominant upper fine to lower medium; moderate sorting; angular to subrounded, dominant subangular; overall moderate sphericity; bentonitic matrix support; occasionally grading to cemented, grain-packed sandstone with some bentonite; individual grains dominant quartz, occasional to common mafic-rich and feldspar grains. Tuffaceous Siltstone (10595' - 10630') = dominant brownish gray to occasional medium gray; blocky cuttings; dominant slightly to occasionally moderately firm; dominant easily to occasional moderately firm; dull luster; finely grainy texture; common high organi c content; grades to tuffaceous claystone. 28 Sand/ Tuffaceous Sandstone/ Conglomeratic Sand (10630' - 10695') = very light gray overall with clear to translucent quartz and volcanic glass dominant, slight trace darker liths; very fine upper to trace very coarse upper, dominantly fine; angular to subangular; very well sorted; dominantly disaggregated with ashy matrix; very fragile; scattered salt and pepper sandstone; fine grain; well sorted; hard; moderate calcareous cement. 29 3.3 Sampling Program Set Type and Purpose Interval Frequency Distribution A Washed and Dried Reference 138’ – 5610’ 5610 – 10695 30’ 20’ David Buthman Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 B Washed and Dried Reference 138’ – 5610’ 5610 - 10695 30’ 20’ David Buthman Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 30 4 DRILLING DATA 4.1 Surveys Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 18 0 0 18 0 0 0 0 175.21 0.12 347.48 175.21 0.17 -0.04 0.15 0.08 206.09 0.14 32.63 206.09 0.23 -0.02 0.22 0.33 267.16 0.17 44.93 267.16 0.36 0.08 0.37 0.08 328.22 0.26 344.11 328.21 0.56 0.11 0.57 0.38 389.66 0.14 321.9 389.66 0.75 0.02 0.73 0.23 448.76 0.14 326.09 448.76 0.87 -0.06 0.83 0.02 521.05 0.14 314.07 521.05 1.00 -0.17 0.93 0.04 582.74 1.50 14.54 582.73 1.83 -0.02 1.77 2.34 643.43 3.45 15.95 643.36 4.36 0.68 4.40 3.21 704.70 5.35 13.20 704.45 8.92 1.84 9.10 3.12 768.22 7.11 10.67 767.59 15.67 3.25 15.98 2.80 829.72 8.79 9.31 828.50 24.04 4.71 24.47 2.75 892.02 10.76 9.38 889.89 34.48 6.43 35.00 3.16 952.99 11.24 10.80 949.74 45.93 8.47 46.60 0.91 1015.41 11.28 10.49 1010.96 57.91 10.72 58.77 0.12 1077.41 12.58 10.33 1071.61 70.51 13.03 71.56 2.10 1140.34 14.90 10.96 1132.74 85.20 15.80 86.48 3.70 1203.53 16.28 11.42 1193.60 101.87 19.10 103.44 2.19 1264.08 17.60 11.34 1251.52 119.16 22.58 121.07 2.17 1328.68 19.22 10.56 1312.82 139.19 26.45 141.43 2.53 1390.13 19.68 10.77 1370.76 159.30 30.24 161.85 0.76 1451.04 19.53 10.43 1428.15 179.38 34.00 182.25 0.31 1514.95 19.51 10.53 1488.38 200.38 37.88 203.56 0.06 1576.45 19.67 10.12 1546.32 220.66 41.58 224.13 0.33 1639.34 20.44 11.11 1605.40 241.86 45.55 245.65 1.34 1700.60 20.97 10.93 1662.71 263.12 49.69 267.28 0.86 1761.85 20.92 10.61 1719.91 284.62 53.79 289.13 0.20 1824.94 20.85 10.62 1778.85 306.72 57.93 311.58 0.10 1887.64 21.06 10.30 1837.41 328.78 62.00 333.95 0.38 1949.06 21.12 10.20 1894.71 350.52 65.93 356.00 0.11 2012.43 21.12 9.87 1953.82 373.01 69.91 378.78 0.19 2074.88 20.93 10.12 2012.12 395.07 73.80 401.12 0.35 2136.98 20.87 10.84 2070.13 416.85 77.83 423.23 0.43 31 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 2196.08 20.83 11.53 2125.37 437.49 81.91 444.24 0.42 2262.14 20.99 11.87 2187.07 460.58 86.69 467.79 0.30 2323.26 21.20 11.77 2244.09 482.11 91.20 489.77 0.34 2386.79 21.33 11.76 2303.30 504.66 95.90 512.79 0.21 2450.97 21.58 11.37 2363.03 527.66 100.60 536.24 0.45 2514.88 21.76 11.47 2422.43 550.79 105.27 559.81 0.29 2578.09 21.93 11.43 2481.10 573.84 109.94 583.30 0.27 2641.55 22.07 11.23 2539.94 597.15 114.61 607.04 0.25 2704.82 21.54 10.05 2598.69 620.24 118.96 630.50 1.09 2768.45 20.97 9.24 2657.98 642.98 122.82 653.49 1.00 2831.65 21.12 9.36 2716.96 665.38 126.49 676.10 0.25 2894.12 21.30 9.64 2775.21 687.67 130.22 698.64 0.33 2931.99 21.45 9.49 2810.47 701.29 132.52 712.40 0.42 3032.16 21.60 9.76 2903.65 737.53 138.66 749.04 0.18 3094.18 21.62 8.29 2961.31 760.09 142.25 771.79 0.87 3156.32 21.52 7.41 3019.10 782.72 145.37 794.50 0.54 3217.97 21.54 6.09 3076.45 805.18 148.03 816.93 0.79 3280.15 20.57 9.92 3134.48 827.29 151.12 839.13 2.70 3341.43 20.90 9.95 3191.79 848.66 154.87 860.76 0.53 3403.53 20.35 12.54 3249.91 870.11 159.12 882.60 1.71 3465.90 20.41 11.95 3308.38 891.34 163.73 904.31 0.34 3528.23 20.35 10.86 3366.81 912.61 168.02 925.98 0.62 3590.35 20.51 9.81 3425.03 933.94 171.91 947.62 0.65 3652.16 19.89 12.86 3483.04 954.86 176.10 968.93 1.97 3713.77 20.01 12.54 3540.94 975.37 180.72 989.94 0.26 3776.59 20.20 12.58 3599.93 996.45 185.41 1011.53 0.30 3839.48 20.60 12.05 3658.88 1017.87 190.09 1033.44 0.70 3900.60 20.52 11.11 3716.11 1038.89 194.40 1054.88 0.56 3962.24 20.74 10.18 3773.79 1060.24 198.41 1076.56 0.63 4025.55 21.28 10.27 3832.89 1082.57 202.44 1099.20 0.85 4087.45 20.09 11.95 3890.81 1104.02 206.64 1121.03 2.14 4149.62 20.11 11.71 3949.19 1124.94 211.02 1142.38 0.14 4212.07 20.01 11.22 4007.85 1145.93 215.28 1163.78 0.31 4274.39 19.85 9.94 4066.44 1166.81 219.18 1184.98 0.75 4336.70 19.92 9.73 4125.04 1187.69 222.80 1206.11 0.16 4398.58 19.92 9.58 4183.21 1208.48 226.33 1227.13 0.08 4460.33 20.02 9.16 4241.25 1229.29 229.77 1248.15 0.28 4522.55 20.03 7.87 4299.71 1250.36 232.92 1269.35 0.71 4583.57 20.81 10.63 4356.90 1271.36 236.35 1290.55 2.03 4645.87 20.60 9.75 4415.17 1293.04 240.25 1312.52 0.60 32 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 4709.49 21.41 11.86 4474.57 1315.43 244.53 1335.28 1.74 4771.11 21.43 11.03 4531.93 1337.48 249.00 1357.76 0.49 4833.32 21.17 10.23 4589.89 1359.69 253.17 1380.32 0.63 4895.49 20.69 10.04 4647.95 1381.56 257.08 1402.47 0.78 4958.51 20.48 9.74 4706.96 1403.39 260.88 1424.57 0.37 5019.83 21.15 11.47 4764.27 1424.80 264.90 1446.31 1.49 5081.49 20.57 10.52 4821.89 1446.35 269.09 1468.24 1.10 5143.65 21.69 11.87 4879.87 1468.33 273.44 1490.61 1.96 5206.25 21.78 11.46 4938.02 1491.04 278.13 1513.77 0.29 5268.25 21.78 10.58 4995.59 1513.62 282.53 1536.74 0.53 5331.14 21.49 9.34 5054.05 1536.46 286.54 1559.87 0.86 5392.45 20.94 8.83 5111.20 1558.36 290.05 1581.97 0.96 5454.77 20.95 12.57 5169.41 1580.25 294.18 1604.20 2.14 5516.17 20.68 12.58 5226.80 1601.54 298.93 1626.01 0.44 5578.96 20.16 12.03 5285.64 1622.95 303.60 1647.91 0.88 5641.43 19.72 11.12 5344.36 1643.82 307.87 1669.19 0.86 5703.23 21.47 14.18 5402.21 1665.03 312.66 1690.92 3.32 5763.57 20.91 13.73 5458.48 1686.20 317.92 1712.74 0.96 5827.15 20.66 13.09 5517.91 1708.14 323.15 1735.30 0.53 5889.76 20.04 12.49 5576.62 1729.38 327.97 1757.07 1.04 5951.72 19.68 12.13 5634.89 1749.95 332.46 1778.11 0.61 6013.92 20.47 10.83 5693.31 1770.88 336.71 1799.44 1.46 6075.59 21.45 11.90 5750.89 1792.50 341.06 1821.47 1.70 6136.75 21.20 11.78 5807.87 1814.28 345.62 1843.70 0.41 6199.36 20.56 10.76 5866.36 1836.16 349.99 1865.99 1.18 6262.60 21.08 10.79 5925.47 1858.24 354.19 1888.43 0.83 6323.69 21.00 9.93 5982.49 1879.81 358.13 1910.31 0.52 6386.39 20.34 9.67 6041.16 1901.62 361.90 1932.38 1.05 6447.32 21.95 9.80 6097.99 1923.29 365.62 1954.29 2.64 6507.98 21.26 9.94 6154.38 1945.29 369.45 1976.56 1.15 6571.60 20.91 9.35 6213.75 1967.85 373.28 1999.38 0.64 6633.15 20.56 9.81 6271.31 1989.34 376.91 2021.10 0.63 6695.73 21.26 10.79 6329.76 2011.31 380.91 2043.38 1.25 6757.16 21.18 10.53 6387.03 2033.16 385.02 2065.57 0.20 6819.47 20.87 10.47 6445.19 2055.14 389.09 2087.88 0.51 6880.79 19.87 10.47 6502.68 2076.13 392.97 2109.18 1.62 6943.02 21.25 11.61 6560.94 2097.58 397.17 2131.01 2.31 7004.94 20.64 11.00 6618.77 2119.28 401.51 2153.11 1.06 7065.89 21.80 10.56 6675.59 2140.95 405.63 2175.13 1.92 7128.45 22.04 10.52 6733.62 2163.91 409.90 2198.44 0.39 33 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 7190.30 21.38 9.63 6791.08 2186.43 413.91 2221.26 1.20 7252.34 19.89 8.54 6849.14 2208.02 417.37 2243.03 2.47 7314.83 20.67 12.28 6907.77 2229.31 421.29 2264.64 2.42 7377.10 19.51 12.42 6966.24 2250.21 425.86 2286.02 1.86 7437.52 20.52 12.17 7023.01 2270.41 430.27 2306.69 1.68 7500.80 22.10 10.16 7081.97 2292.98 434.71 2329.65 2.75 7562.44 22.08 9.83 7139.08 2315.80 438.73 2352.77 0.20 7624.22 21.16 8.36 7196.52 2338.28 442.33 2375.44 1.72 7687.71 22.11 9.24 7255.53 2361.41 445.92 2398.75 1.58 7749.60 21.71 8.45 7312.95 2384.23 449.47 2421.74 0.81 7811.76 20.76 8.28 7370.89 2406.50 452.74 2444.14 1.53 7873.68 21.68 9.32 7428.61 2428.65 456.18 2466.45 1.61 7936.30 21.17 8.85 7486.90 2451.23 459.79 2489.23 0.86 7997.87 20.26 8.29 7544.49 2472.76 463.04 2510.91 1.51 8061.78 21.28 10.58 7604.25 2495.12 466.76 2533.49 2.04 8123.84 20.76 10.79 7662.18 2516.99 470.89 2555.71 0.86 8184.63 20.09 10.51 7719.15 2537.84 474.81 2576.89 1.10 8247.25 20.87 12.97 7777.81 2559.29 479.27 2598.78 1.86 8308.38 19.90 12.43 7835.10 2580.06 483.96 2620.06 1.62 8371.39 20.59 11.70 7894.23 2601.39 488.51 2641.85 1.16 8434.66 21.90 11.80 7953.20 2623.83 493.18 2664.76 2.08 8496.29 21.61 11.61 8010.44 2646.20 497.81 2687.58 0.49 8559.26 21.24 17.06 8069.06 2668.46 503.49 2710.56 3.22 8620.48 19.53 23.01 8126.45 2688.49 510.75 2731.75 4.39 8683.35 18.82 28.38 8185.83 2707.08 519.68 2751.96 3.02 8745.08 18.72 28.07 8244.28 2724.59 529.07 2771.23 0.23 8807.63 16.89 29.19 8303.84 2741.38 538.23 2789.75 2.98 8870.88 16.60 28.58 8364.41 2757.33 547.03 2807.37 0.53 8932.07 16.27 28.17 8423.09 2772.56 555.26 2824.15 0.58 8992.96 16.07 28.82 8481.57 2787.46 563.35 2840.58 0.44 9055.82 14.90 29.52 8542.15 2802.12 571.52 2856.79 1.89 9118.70 15.71 27.52 8602.80 2816.71 579.44 2872.87 1.54 9182.10 16.78 24.89 8663.67 2832.63 587.26 2890.22 2.05 9246.52 16.22 24.12 8725.43 2849.27 594.85 2908.22 0.93 9308.15 16.82 29.68 8784.53 2864.88 602.79 2925.29 2.74 9373.57 15.85 30.59 8847.31 2880.80 612.02 2942.99 1.53 9436.40 15.04 30.65 8907.86 2895.20 620.54 2959.03 1.30 9499.49 16.36 29.71 8968.60 2909.95 629.12 2975.44 2.13 9563.79 15.79 29.70 9030.38 2925.42 637.94 2992.59 0.88 9626.73 16.95 30.19 9090.77 2940.79 646.79 3009.66 1.86 34 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 9690.42 15.78 31.06 9151.88 2956.23 655.93 3026.87 1.88 9753.37 16.52 29.71 9212.35 2971.34 664.79 3043.69 1.32 9815.98 16.14 29.37 9272.42 2986.66 673.47 3060.66 0.63 9880.91 17.54 27.81 9334.57 3003.18 682.46 3078.88 2.27 9944.11 17.88 27.58 9394.77 3020.21 691.40 3097.58 0.55 10005.84 18.01 27.63 9453.50 3037.07 700.21 3116.08 0.21 10070.61 18.11 27.90 9515.08 3054.83 709.57 3135.59 0.20 10133.49 16.61 33.11 9575.10 3070.99 719.05 3153.59 3.43 10197.27 15.93 33.51 9636.33 3085.93 728.86 3170.47 1.08 10259.89 16.62 30.70 9696.44 3100.80 738.18 3187.16 1.67 10323.43 15.74 32.10 9757.46 3115.91 747.40 3204.07 1.51 10387.44 15.38 32.49 9819.12 3130.43 756.57 3220.39 0.58 10450.74 15.14 33.13 9880.19 3144.43 765.60 3236.18 0.46 10513.67 14.48 34.17 9941.02 3157.82 774.51 3251.35 1.14 10577.70 13.54 35.54 10003.15 3170.55 783.36 3265.85 1.56 10641.17 12.58 38.25 10064.98 3182.02 791.96 3279.08 1.79 10695* 12.58 38.25 10117.52 3191.23 799.22 3289.78 0 * projected 35 4.2 Bit Record BIT NO. SIZE TYPE S/N JETS/ TFA IN OUT Feet Drilled HRS AVE ROP (Ft/HR) CONDITION 1 12 ¼” HDBS QHC1GRC 12460781 3x16, 14/ 0.7394 128 2980 2852 34.25 83.3 3-3-CT -A-E-I-BU-TD 1RR1 12 ¼” HDBS QHC1GRC 12460781 3x16, 14/ 0.7394 2980 2980 0 0 0 CLEAN OUT RUN #1 1RR2 12 ¼” HDBS QHC1GRC 12460781 3x16, 14/ 0.7394 2980 2980 0 0 0 CLEAN OUT RUN #2 2 8 ½” Varel V513GH 4008323 4x1 2,10,11, 14/ 0.7616 2980 10695 7715 97.06 79.5 3-2-BT -A-X-2-CT -TD 2RR1 8 ½” Varel V513GH 4008323 4x12,10,11, 14/ 0.7616 10695 10695 0 0 0 CLEAN OUT RUN AFTER TD 36 4.3 Mud Record Contractor: M.I. Swaco Date Depth MW (ppg) VIS (s/qt) PV YP Gels FL (cc) FC Sols (%) O/W Ratio Sd (%) MBT pH Cl (ml/l) Ca (ml/l) MD (ft) TVD (ft) SPUD MUD 11/27/15 120 120 9.0 232 34 55 25/62/71 11.9 2/0 4.2 0/95.6 -- 22.5 10.4 250 20 11/28/15 430 430 9.35 202 38 56 21/60/71 9.0 2/0 6.8 0/93.0 1.40 24.5 9.5 200 20 11/29/15 1732 1692 9.35 145 29 43 15/77/91 9.0 2/0 7.5 0/92.3 7.5 20.5 8.7 225 40 11/30/15 2891 2809 9.35 57 18 29 11/23/28 7.6 2/0 7.5 0/92.3 0.1 20.0 8.4 350 20 12/01/15 2980 2855 9.30 57 18 27 11/26/33 7.6 2/0 7.3 0/92.5 0.1 21.0 8.3 200 40 12/02/15 2980 2855 9.45 79 27 35 14/23/32 7.8 2/0 8.4 0/91.4 0.15 19.0 7.8 250 20 12/03/15 2980 2855 9.50 50 20 15 4/8/11 6.8 2/0 8.8 0/91.0 0.10 18.0 8.1 250 400 12/04/15 2980 2855 9.30 43 7 14 4/5/7 5.4 1/0 5.3 0.5/92.7 -- 1.8 8.7 29000 100 12/05/15 2980 2855 9.25 58 9 18 5/7/8 5.4 1/0 4.8 0.3/93.3 -- 1.5 9.1 30500 88 12/06/15 3618 3457 9.40 57 11 22 6/10/12 4.2 1/0 5.3 0.3/92.0 0.05 1.8 8.2 30500 140 12/07/15 4802 4560 9.40 55 14 198 5/9/12 4.4 1/2 5.3 0.3/92.0 0.10 2.5 9.6 30500 80 12/08/15 5985 5667 9.40 47 13 20 6/8/13 4.4 1/2 5.6 0.5/91.5 0.15 3.3 9.6 30500 60 12/09/15 7347 6941 9.35 47 12 19 5/8/10 4.2 1/2 5.2 1.0/91.3 0.10 3.5 9.0 31000 48 12/10/15 8221 7753 9.35 48 13 22 6/10/14 3.8 1/2 5.3 0.5/91.8 0.05 3.5 9.5 30500 80 12/11/15 9216 8697 9.40 54 15 21 5/9/13 3.6 1/2 5.5 0.5/91.5 0.01 4.3 9.0 31000 80 12/12/15 10234 9672 9.50 54 17 18 4/7/12 3.9 1/2 6.1 1.0/90.6 0.01 4.5 9.9 29000 40 12/13/15 10695 10117 9.65 50 16 20 5/8/13 3.3 1/2 6.7 0.8/90.2 0.01 5.0 9.7 29000 40 12/14/15 10695 10117 9.75 57 19 25 7/11/17 3.0 1/2 6.9 0.8/89.8 0.15 5.0 9.6 31500 20 12/15/15 10695 10117 9.75 61 18 26 7/12/16 2.9 1/2 6.6 0.8/90.2 0.10 5.0 9.8 31000 40 12/16/15 10695 10117 9.80 54 19 24 7/10/14 3.0 1/2 7.3 1.8/88.7 0.10 5.0 9.9 29000 40 12/17/15 10695 10117 9.75 57 18 22 6/11/14 2.8 1/2 6.8 1.5/89.4 0.10 5.0 9.2 29000 100 12/18/15 10695 10117 9.80 54 14 22 6/12/14 3.0 1/2 7.2 1.5/89.0 0.10 5.0 9.1 30000 60 Abbreviations: MW = Mud Weight VIS = Funnel Viscosity PV = Plastic Viscosity YP = Yield Point Gels = Gel Strength FL = Water or Filtrate Loss FC = Filter Cake O/W = Oil to Water ratio Sols = Solids Sd = Sand content MBT = Methylene Blue Alk, Pm = Alkalinity, Mud pH = Acidity Cl = Chlorides Ca = Hardness Calcium nr = Not Recorded 37 4.4. Drilling Progress 0 2000 4000 6000 8000 10000 11/ 2 5 / 2 0 1 5 11/ 2 6 / 2 0 1 5 11/ 2 7 / 2 0 1 5 11/ 2 8 / 2 0 1 5 11/ 2 9 / 2 0 1 5 11/ 3 0 / 2 0 1 5 12/ 1 / 2 0 1 5 12/ 2 / 2 0 1 5 12/ 3 / 2 0 1 5 12/ 4 / 2 0 1 5 12/ 5 / 2 0 1 5 12/ 6 / 2 0 1 5 12/ 7 / 2 0 1 5 12/ 8 / 2 0 1 5 12/ 9 / 2 0 1 5 12/ 1 0 / 2 0 1 5 12/ 1 1 / 2 0 1 5 12/ 1 2 / 2 0 1 5 12/ 1 3 / 2 0 1 5 12/ 1 4 / 2 0 1 5 12/ 1 5 / 2 0 1 5 12/ 1 6 / 2 0 1 5 12/ 1 7 / 2 0 1 5 12/ 1 8 / 2 0 1 5 12/ 1 9 / 2 0 1 5 12/ 2 0 / 2 0 1 5 12 1/4" 8 1/2" 38 5 SHOW REPORTS Hydrocarbon Show Report # 1 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 169 3096'MD 3265'MD Country: 20 2963'TVD 3120'TVD Averages Before During After Maximum ROP (fph) 101 ft/hr 121 ft/hr 165 ft/hr 398 ft/hr WOB 14 klbs 9 klbs 8 klbs 10 klbs RPM 46 rpm 51 rpm 75 rpm 79 rpm PP 1597 psi 1580 psi 1545 psi 1680 psi Mud Weight 9.3 lbs/gal 9.3 lbs/gal 9.3 lbs/gal 9.3 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 22 41 159 187 C1 (ppm) 4,476 7,992 31,364 34,997 C2 (ppm) 16 44 88 170 C3 (ppm) - - - - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/6/2015 4:46 PM Residual Cut Sand/Sandstone = medium to medium dark gray with salt and pepper appearance, individual grains dominantly medium to dark gray, black, light gray and clear to translucent quartz and volcanic glass; very hard and brittle to to crunchy; very fine lower to medium lower dominantly fine; angular to subangular; poor to fair sorting; moderate to very calcareous cement; trace dry ashy matrix supported grains; very light gray to grayish white; non calcareous. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 2 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 97 3270'MD 3367'MD Country: 20 3125'TVD 3216'TVD Averages Before During After Maximum ROP (fph) 117 ft/hr 154 ft/hr 74 ft/hr 395 ft/hr WOB 8 klbs 8 klbs 8 klbs 10 klbs RPM 57 rpm 72 rpm 24 rpm 86 rpm PP 1592 psi 1554 psi 1573 psi 1613 psi Mud Weight 9.3 lbs/gal 9.3 lbs/gal 9.3 lbs/gal 9.3 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 42 197 82 457 C1 (ppm) 8,063 40,833 15,873 93,427 C2 (ppm) 41 56 66 263 C3 (ppm) - - - - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sand = medium to medium dark gray with weak salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass, and light to medium greeninsh gray; very fine upper to trace very coarse upper , dominantly fine upper to medium upper; angular to trace subrounded, dominantly subangular; poor to fair sorting; disaggregated; non calcareous; trace thin coal beds. Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/6/2015 7:14 PM Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 3 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 169 3930'MD 4050'MD Country: 20 3744'TVD 3856'TVD Averages Before During After Maximum ROP (fph) 117 ft/hr 189 ft/hr 96 ft/hr 806 ft/hr WOB 9 klbs 9 klbs 10 klbs 10 klbs RPM 72 rpm 70 rpm 24 rpm 82 rpm PP 1680 psi 1651 psi 1713 psi 1847 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 102 523 76 1,103 C1 (ppm) 19,556 90,157 15,084 212,244 C2 (ppm) 99 443 62 1,265 C3 (ppm) 2 24 - 109 C4 (ppm) 0 5 - 23 C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/7/2017 5:07 AM Residual Cut Sand = medium to medium dark gray with weak salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass, and light to medium greenish gray ; very fine upper to trace coarse upper; angular to trace subrounded, dominantly subangular; poor to fair sorting; disaggregated; not to moderately calcareous. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 4 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 169 4100'MD 4280'MD Country: 20 3903'TVD 4072'TVD Averages Before During After Maximum ROP (fph) 169 ft/hr 126 ft/hr 127 ft/hr 419 ft/hr WOB 9 klbs 9 klbs 8 klbs 11 klbs RPM 66 rpm 74 rpm 66 rpm 80 rpm PP 1682 psi 1728 psi 1789 psi 1825 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 390 136 100 299 C1 (ppm) 67,507 26,908 20,095 59,548 C2 (ppm) 329 105 83 219 C3 (ppm) 17 1 0 11 C4 (ppm) 3 - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sand = medium to medium dark gray with individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass, trace greenish gray; very fine upper to medium lower, dominantly fine; angular to subangular; fair to good sorting; dominantly unconsolidated with loose grains supported in claystone; non calcareous; trace thin coal beds. Sand/Sandstone = medium to medium dark gray with salt and pepper appearance, individual grains dominantly medium to dark gray, black, light gray and clear to translucent quartz and volcanic glass; very hard and brittle to crunchy; very fine lower to medium lower dominantly fine; angular to subangular; fair to good sorting; moderate to very calcareous cement; trace thin coal beds. Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/7/2015 12:08 PM Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 5 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 130 4320'MD 4450'MD Country: 20 4109'TVD 4232'TVD Averages Before During After Maximum ROP (fph) 131 ft/hr 161 ft/hr 156 ft/hr 391 ft/hr WOB 10 klbs 11 klbs 12 klbs 13 klbs RPM 72 rpm 66 rpm 67 rpm 68 rpm PP 1780 psi 1756 psi 1864 psi 1928 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 134 337 206 757 C1 (ppm) 26,378 66,402 39,263 145,876 C2 (ppm) 101 311 151 784 C3 (ppm) 1 19 15 46 C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/7/2015 3:11 PM Residual Cut Sand/Sandstone = medium to medium dark gray with a weak salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass; very fine upper , dominantly fine upper to medium lower; angular to subangular; poor to fair sorting; dominantly unconsolidated with very fine sandstone; hardl medium dark gray; well sorted; very calcareous cement. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 6 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 119 4565'MD 4684'MD Country: 20 4339'TVD 4451'TVD Averages Before During After Maximum ROP (fph) 134 ft/hr 105 ft/hr 94 ft/hr 248 ft/hr WOB 11 klbs 10 klbs 9 klbs 14 klbs RPM 59 rpm 58 rpm 30 rpm 80 rpm PP 1730 psi 1802 psi 1802 psi 1961 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 163 188 126 361 C1 (ppm) 31,210 37,017 24,778 73,594 C2 (ppm) 124 156 103 286 C3 (ppm) 4 4 3 22 C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sand/Sandstone = medium to medium dark gray with a weak salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear, to translucent quartz and volcanic glass, very f ine upper to medium lower, dominantly fine upper to medium lower; angular to subangular; poor to fair sorting; dominantly unconsolidated with very fine sandstone; hard; medium dark gray; well sorted; very calcareous cement; trace thin coal beds. Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/7/2015 6:16 PM Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 7 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 150 4700'MD 4850'MD Country: 20 4466'TVD 4605'TVD Averages Before During After Maximum ROP (fph) 99 ft/hr 155 ft/hr 128 ft/hr 850 ft/hr WOB 10 klbs 13 klbs 13 klbs 16 klbs RPM 49 rpm 74 rpm 74 rpm 75 rpm PP 1704 psi 1884 psi 1911 psi 1941 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 166 199 16 535 C1 (ppm) 32,651 37,514 3,141 100,576 C2 (ppm) 137 99 11 279 C3 (ppm) 4 3 - 16 C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/7/2015 8:35 PM Residual Cut Sand = light gray to medium gray, occasional dark gray, occasional salt and pepper appearance; very fine to upper fine grained; moderately well sorted; subangular to sub rounded with high sphericity; predominantly unconsolidated; mostly tuffaceous matrix when present; occasional trace silica cementin well preserved harder specimens; grain supported; interbedded with thin carbonaceous shales and coals as well as tuffaceous claystones and tuffaceous siltstones. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 8 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 80 4890'MD 4970'MD Country: 20 4643'TVD 4718'TVD Averages Before During After Maximum ROP (fph) 138 ft/hr 179 ft/hr 146 ft/hr 418 ft/hr WOB 13 klbs 14 klbs 14 klbs 16 klbs RPM 73 rpm 70 rpm 74 rpm 85 rpm PP 1910 psi 1788 psi 1933 psi 2004 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 100 283 151 514 C1 (ppm) 19,802 55,849 30,165 101,201 C2 (ppm) 73 70 - 185 C3 (ppm) - - - - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sand = light gray to medium gray, occasional gray, occasional dark gray, and occasional salt and pepper appearance; very fine to upper fine grained; moderately well sorted; sub angular to sub rounded with high sphericity; predominantly unconsolidated; matrix is mostly tuffaceous when present; occasional trace silica cement in well preserved harder speciments; gran supported; interbedded with thin carbonaceous shales and coals as well as tuffaceous claystones and tuffaceous siltstones. Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/7/2015 11:02 PM Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 9 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 150 5150'MD 5300'MD Country: 100 4886'TVD 5025'TVD Averages Before During After Maximum ROP (fph) 154 ft/hr 134 ft/hr 117 ft/hr 286 ft/hr WOB 11 klbs 11 klbs 11 klbs 13 klbs RPM 61 rpm 67 rpm 67 rpm 68 rpm PP 1981 psi 1922 psi 2013 psi 1998 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 197 256 134 548 C1 (ppm) 39,555 50,314 27,130 112,766 C2 (ppm) 63 63 25 265 C3 (ppm) - - - - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sand = Medium gray to medium light gray with a moderate salt and pepper appearance, individual grains are dominantly light to medium gray, clear to translucent quartz and volcanic glass dark gray to black; very fine lower to medium lower, dominantly fine; angular to suangular; moderately well sorted; disaggregated with trace very fragile grain supported sandstone; fine; light gray; fragile; non calcareous; trace thin coal beds throughout interval. Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/8/2015 7:55 AM Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 10 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 65 5520'MD 5585'MD Country: 100 5230'TVD 5291'TVD Averages Before During After Maximum ROP (fph) 165 ft/hr 167 ft/hr 157 ft/hr 408 ft/hr WOB 13 klbs 13 klbs 14 klbs 16 klbs RPM 67 rpm 66 rpm 63 rpm 69 rpm PP 2027 psi 2022 psi 2051 psi 2125 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 208 325 197 563 C1 (ppm) 41,416 65,594 38,219 113,297 C2 (ppm) - - 104 - C3 (ppm) - - 1 - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sand/Sandstone = Medium to medium light gray with a weak salt and pepper appearance, individual grains dominantly light to dark gray, black, clear to translucent quartz and volcanic glass; ; very fine lower to medium upper, dominantly fine upper to lower; angular to subangular; moderately well sorted ; dominantly disaggregated with light gray sandstone; fine; fragile to brittle; moderate to very calcareous cement; Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/8/2015 12:56 PM Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 11 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 100 5600'MD 5700'MD Country: 100 5305'TVD 5399'TVD Averages Before During After Maximum ROP (fph) 158 ft/hr 155 ft/hr 168 ft/hr 432 ft/hr WOB 13 klbs 14 klbs 13 klbs 18 klbs RPM 66 rpm 56 rpm 69 rpm 71 rpm PP 2019 psi 2033 psi 2101 psi 2161 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 280 196 237 385 C1 (ppm) 56,382 37,931 46,279 74,660 C2 (ppm) 4 99 26 199 C3 (ppm) - 1 - 11 C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sand = medium gray to medium light gray with a moderate salt and pepper appearance, individual grains dominantly light to medium gray, clear to translucent quartz and volcanic glass dark gray to black; very fine lowr to medium lower, dominantly f ine; angular to subangular; moderately well sorted; disaggregated with trace very fragile grain supported sandstone; fine; light gray; fragile; moderately calcareous; trace to common thin coal beds throughout interval. Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/8/2015 1:44 PM Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 12 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 90 5806'MD 5896'MD Country: 100 5498'TVD 5582'TVD Averages Before During After Maximum ROP (fph) 155 ft/hr 136 ft/hr 108 ft/hr 370 ft/hr WOB 13 klbs 11 klbs 12 klbs 14 klbs RPM 70 rpm 72 rpm 66 rpm 74 rpm PP 2099 psi 2118 psi 2030 psi 2267 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 239 256 211 424 C1 (ppm) 46,824 39,722 41,627 80,963 C2 (ppm) 21 9 36 85 C3 (ppm) - - - - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sand/Sandstone = light gray to medium dark gray; framework is predominantly translucent to transparent colorless quartz with abundant medium gray to light gray lithic fragments; upper very fine to upper fine with rare lower medium grains; well to fairly well sorted; subrounded to subangular; mod high to high sphericity; easily friable with abundant loose grains; argillaceous/tuffaceous matrix material; mostly matrix supported with rare grain supported; interstices are well filled; trace thin laminae of carbonaceous material. Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/8/2015 8:45 PM Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 13 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 110 5940'MD 6050'MD Country: 100 5624'TVD 5727'TVD Averages Before During After Maximum ROP (fph) 126 ft/hr 125 ft/hr 148 ft/hr 430 ft/hr WOB 12 klbs 12 klbs 12 klbs 17 klbs RPM 72 rpm 63 rpm 62 rpm 80 rpm PP 2054 psi 2006 psi 2077 psi 2079 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 243 227 223 720 C1 (ppm) 39,343 44,801 43,918 143,049 C2 (ppm) 40 0 6 14 C3 (ppm) - - 0 - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sand/Sandstone = light gray to medium dark gray; frame work predominantly translucent to transparent colorless quartz with abundant medium gray to light gray lithic fragments; upper very fine to upper fine with rare lower medium grains; well to fairly well sorted; subrounded to subangular; high to moderate sphericity; easily friable with abundant loose grains; argillaceous/tuffaceous matrix material; mostly matrix supported with rare grain supported; interstices well filled; trace thin laminae of carbonaceous material. Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/8/2015 10:27 PM Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 14 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 170 6250'MD 6420'MD Country: 100 5624'TVD 5727'TVD Averages Before During After Maximum ROP (fph) 126 ft/hr 125 ft/hr 148 ft/hr 430 ft/hr WOB 12 klbs 12 klbs 12 klbs 17 klbs RPM 72 rpm 63 rpm 62 rpm 80 rpm PP 2054 psi 2006 psi 2077 psi 2079 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 243 227 223 720 C1 (ppm) 39,343 44,801 43,918 143,049 C2 (ppm) 40 0 6 14 C3 (ppm) - - 0 - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sandstone/Sand = very light gray to medium gray with occasional to fairly common whitish gray specimens ; very fine to upper fine with rare lower medium grains; well to fairly well sorted; subrounded to subangular; moderately high to high sphericity; common abraded grain surfaces with scarce to no pitting; predominantly loose grains with occasionally very small preserved specimens; argillaceous to tuffaceous matrix; no evident cement; grain supported; interstices moderately well filled; decreased lithics up to 5%; thinly interbedded coal and carbonaceous shales common; decreased thin laminar tuffaceous claystones and tuffaceous siltstones; associated with increased gas. Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/9/2015 2:46 AM Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 15 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 50 6510'MD 6560'MD Country: 100 6156'TVD 6203'TVD Averages Before During After Maximum ROP (fph) 156 ft/hr 184 ft/hr 131 ft/hr 448 ft/hr WOB 12 klbs 12 klbs 13 klbs 16 klbs RPM 75 rpm 63 rpm 46 rpm 75 rpm PP 2223 psi 2269 psi 2030 psi 2312 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 187 593 192 841 C1 (ppm) 36,346 123,434 41,307 188,034 C2 (ppm) 107 6,330 561 14,237 C3 (ppm) 9 43 2 64 C4 (ppm) - 8 1 18 C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/9/2015 6:06 AM Residual Cut Sand/Sandstone/Tuffaceous Sandstone = medium to medium light gray overall with a salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, black and light greenish gray; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; loosely consolidated to disaggregated; sandstone; firm to hard and brittle; very fine to medium; very calcareous cement; trace ashy matrix supported grains; very soft; pulverulent; non calcareous; trace to common thin coal beds throughout. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 16 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 240 6680'MD 6920'MD Country: 100 6315'TVD 6539'TVD Averages Before During After Maximum ROP (fph) 150 ft/hr 148 ft/hr 127 ft/hr 481 ft/hr WOB 12 klbs 13 klbs 13 klbs 16 klbs RPM 56 rpm 50 rpm 39 rpm 65 rpm PP 2148 psi 2244 psi 2203 psi 2379 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 275 339 176 755 C1 (ppm) 56,968 65,660 34,640 146,417 C2 (ppm) 1,612 289 142 796 C3 (ppm) 12 14 1 53 C4 (ppm) 2 2 - 18 C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sand/Tuffaceous Sandstone (6660-6730) = light to very light gray overall, individual grains dominantly clear to translucent quartz and volcanic glass, trace dark gra to black; very fine lower to medium lower, dominantly fine; angular to subangular; very well sorted; veryh loosely supported from ashy matrix; very soft and fragile; pulverulent; dirty white with darker gray secondary hues; visible glass shards; non to slightly calcareous. Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/9/2015 1:15 PM Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 17 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 150 7050'MD 7200'MD Country: 100 6661'TVD 6800'TVD Averages Before During After Maximum ROP (fph) 119 ft/hr 148 ft/hr 113 ft/hr 422 ft/hr WOB 13 klbs 13 klbs 12 klbs 18 klbs RPM 39 rpm 57 rpm 58 rpm 69 rpm PP 2186 psi 2138 psi 2164 psi 2359 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 200 441 247 953 C1 (ppm) 39,175 84,781 47,471 180,813 C2 (ppm) 157 419 166 1,100 C3 (ppm) 5 29 13 100 C4 (ppm) - 4 - 25 C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/9/2015 6:15 PM Residual Cut Tuffaceous Sandstone = very light gray to grayish white with streaky dark brown and black secondary hues; soft to pulverulent; irregular shaped cuttings; fragile; non calcareous ashy matrix supports very fine to very coarse sand grains; individual grains dominantly clear to translucent quartz and volcanic glass, trace dark lithics; well sorted in fine range; friable; angular to sub angular. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 18 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 100 7230'MD 7330'MD Country: 100 6829'TVD 6922'TVD Averages Before During After Maximum ROP (fph) 97 ft/hr 136 ft/hr 140 ft/hr 404 ft/hr WOB 12 klbs 13 klbs 14 klbs 16 klbs RPM 68 rpm 53 rpm 50 rpm 72 rpm PP 2039 psi 2219 psi 2127 psi 2278 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 31,000 30,500 Total Gas 208 320 215 550 C1 (ppm) 39,791 61,599 42,193 103,945 C2 (ppm) 179 178 154 437 C3 (ppm) 11 17 12 35 C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sand/Sandstone = dominantly clear, common black, occasionally white; sandstone overall very light gray to off white; lower fine to upper medium; dominant upper fine to lower medium; moderately sorted; angular to subround, dominant subangular; dominant moderate to occasional low sphericity; dominantly quartz; common mafic rich grains; occasional feldspar. Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/9/2015 9:10 PM Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 19 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 167 7430'MD 7597'MD Country: 100 7016'TVD 7172'TVD Averages Before During After Maximum ROP (fph) 131 ft/hr 161 ft/hr 114 ft/hr 396 ft/hr WOB 13 klbs 13 klbs 13 klbs 16 klbs RPM 50 rpm 41 rpm 38 rpm 50 rpm PP 2163 psi 2101 psi 2145 psi 2239 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 31,000 31,000 31,000 31,000 Total Gas 252 417 206 1,024 C1 (ppm) 49,060 75,611 39,012 183,683 C2 (ppm) 153 318 162 815 C3 (ppm) 13 24 10 84 C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/10/2015 5:10 AM Residual Cut Tuffaceous Sandstone = very light gray; rounded to slightly angular cuttings; soft to slightly firm; easily friable; lower very fine to upper medium, dominant fine; moderate to well sorted;qngular to subround, dominantly subangular; dominant moderate to occasionally low sphericity ; matrix-supported with abundant ashy volcanic material; dominantly quartz, common mafic rich grains, feldspar. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 20 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 120 7680'MD 7800'MD Country: 100 7248'TVD 7360'TVD Averages Before During After Maximum ROP (fph) 136 ft/hr 126 ft/hr 97 ft/hr 299 ft/hr WOB 13 klbs 14 klbs 12 klbs 16 klbs RPM 40 rpm 48 rpm 39 rpm 49 rpm PP 2137 psi 2170 psi 2173 psi 2274 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 31,000 31,000 31,000 31,000 Total Gas 368 253 113 591 C1 (ppm) 67,423 48,896 21,550 114,080 C2 (ppm) 287 210 94 516 C3 (ppm) 23 13 1 40 C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/10/2015 8:56 AM Residual Cut Sandstone = very light gray with dark gray secondary hues; rounded cuttings; easily to moderately friable; lower fine to upper medium, dominantly fine; moderately sorted; angular to subround, dom subangular; moderate sphericity; grain to matrix support; grades to tuffaceous sandstone; dominantly quartz, common mafics, occasional feldspars. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 21 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 105 7995'MD 8100'MD Country: 100 7542'TVD 7640'TVD Averages Before During After Maximum ROP (fph) 122 ft/hr 156 ft/hr 123 ft/hr 455 ft/hr WOB 14 klbs 13 klbs 15 klbs 18 klbs RPM 48 rpm 39 rpm 55 rpm 52 rpm PP 2227 psi 2202 psi 2324 psi 2341 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 31,000 31,000 30,500 31,000 Total Gas 173 402 287 877 C1 (ppm) 33,989 78,517 58,145 167,897 C2 (ppm) 154 398 330 978 C3 (ppm) 6 22 22 46 C4 (ppm) 1 2 3 20 C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/10/2015 2:14 PM Residual Cut Tuffaceous Sandstone = very light gray to grayish white with abundant darker weak secondary hues; very fragile and pulverulent; irregular subrounded cuttings;; ashy matrix acts as support for loose sands; clear to translucent quartz and volcanic glass with trace darker lithics; very fine lower to trace very coarse upper, dominantly fine; angular to subangular; moderately well sorted; non calcareous; trace to common thin coal beds throughout. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 22 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 125 8655'MD 8780'MD Country: 100 8159'TVD 8277'TVD Averages Before During After Maximum ROP (fph) 95 ft/hr 111 ft/hr 128 ft/hr 406 ft/hr WOB 12 klbs 11 klbs 14 klbs 19 klbs RPM 34 rpm 54 rpm 54 rpm 67 rpm PP 2224 psi 2201 psi 2325 psi 2345 psi Mud Weight 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 105 190 180 591 C1 (ppm) 20,195 36,887 34,543 118,136 C2 (ppm) 103 176 176 581 C3 (ppm) 8 15 15 50 C4 (ppm) - 2 3 15 C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/11/2015 9:18 AM Residual Cut Sand/Tuffaceous Sandstone = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace dark gray, black and light greenish gray; very fine lower to medium lower, dominantly fine upper to lower; angular to subrounded, dominantly subangular; well sorted; dominantly unconsolidated with ashy matrix supporting individual grains; graysih white with darker secondary hues; very soft; friable; pulverulent; non calcareous; occasional coal beds. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 23 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 100 8800'MD 8900'MD Country: 100 8159'TVD 8277'TVD Averages Before During After Maximum ROP (fph) 95 ft/hr 111 ft/hr 128 ft/hr 406 ft/hr WOB 12 klbs 11 klbs 14 klbs 19 klbs RPM 34 rpm 54 rpm 54 rpm 67 rpm PP 2224 psi 2201 psi 2325 psi 2345 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 105 190 180 591 C1 (ppm) 20,195 36,887 34,543 118,136 C2 (ppm) 103 176 176 581 C3 (ppm) 8 15 15 50 C4 (ppm) - 2 3 15 C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/11/2015 12:08 PM Residual Cut Sand = Light gray to very light gray overall with individual lithics dominantly clear to translucent quartz and volcanic glass; tracemedium to dark gray to black; very fine lower to trace very coarse upper, dominantly fine upper to medium lower; angular to subangular; poorly sorted; dominantly unconsolidated with common ashy matrix supported grains and salt and pepper sandstone; fine to medium; hard to brittle; moderate to very calcareous cement. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 24 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 100 8950'MD 9075'MD Country: 100 8440'TVD 8560'TVD Averages Before During After Maximum ROP (fph) 138 ft/hr 138 ft/hr 80 ft/hr 411 ft/hr WOB 14 klbs 14 klbs 12 klbs 17 klbs RPM 64 rpm 60 rpm 36 rpm 67 rpm PP 2405 psi 2399 psi 2313 psi 2525 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 30,500 30,500 Total Gas 164 584 202 1,099 C1 (ppm) 32,283 113,177 39,874 212,906 C2 (ppm) 169 724 201 1,523 C3 (ppm) 16 62 19 115 C4 (ppm) - 11 4 43 C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/11/2015 1:57 PM Residual Cut Sand = Light gray to very light gray overall with individual lithics dominantly clear to translucent quartz and volcanic glass; tracemedium to dark gray to black; very fine lower to trace very coarse upper, dominantly fine upper to medium lower; angular to subangular; poorly sorted; dominantly unconsolidated with common ashy matrix supported grains and salt and pepper sandstone; fine to medium; hard to brittle; moderate to very calcareous cement. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 25 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 75 9410'MD 9485'MD Country: 100 8882'TVD 8954'TVD Averages Before During After Maximum ROP (fph) 142 ft/hr 120 ft/hr 112 ft/hr 380 ft/hr WOB 17 klbs 15 klbs 14 klbs 18 klbs RPM 63 rpm 54 rpm 52 rpm 67 rpm PP 2454 psi 2453 psi 2635 psi 2559 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 30,500 30,500 31,000 30,500 Total Gas 371 496 279 1,366 C1 (ppm) 72,219 104,032 54,749 320,000 C2 (ppm) 418 332 251 955 C3 (ppm) 36 37 20 130 C4 (ppm) 8 6 6 26 C5 (ppm) - 1 - 12 Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/12/2015 2:58 AM Residual Cut Sand = Dominantly clear to translucent, occasional black; lower fine to upper coarse, dominant lower medium; moderately sorted;angular to subround; dominantly quartz, occasional mafic-rich grains, trace feldspar. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 26 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 70 9500'MD 9570'MD Country: 100 8969'TVD 9036'TVD Averages Before During After Maximum ROP (fph) 100 ft/hr 130 ft/hr 105 ft/hr 366 ft/hr WOB 14 klbs 14 klbs 14 klbs 19 klbs RPM 42 rpm 58 rpm 46 rpm 60 rpm PP 2433 psi 2657 psi 2500 psi 2712 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 31,000 31,000 31,000 31,000 Total Gas 479 356 337 455 C1 (ppm) 100,685 69,754 65,714 89,285 C2 (ppm) 290 321 352 422 C3 (ppm) 35 26 27 37 C4 (ppm) 5 7 5 13 C5 (ppm) 1 - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/12/2015 6:00 AM Residual Cut Sand = dominantly clear to translucent, common to occasionally white, occasional black; lower very fine to lower fine; overall well sorted; angular to subround, dominant subangular; moderate sphericity; dominant quartz; common to occasional feldspar, occasional mafic rich grains. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 27 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 75 9650'MD 9725'MD Country: 100 9113'TVD 9185'TVD Averages Before During After Maximum ROP (fph) 107 ft/hr 137 ft/hr 83 ft/hr 432 ft/hr WOB 14 klbs 16 klbs 14 klbs 18 klbs RPM 41 rpm 66 rpm 35 rpm 69 rpm PP 2488 psi 2476 psi 2520 psi 2640 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 31,000 31,000 31,000 31,000 Total Gas 365 577 241 1,111 C1 (ppm) 71,510 114,108 46,567 240,279 C2 (ppm) 387 683 218 1,533 C3 (ppm) 28 71 35 172 C4 (ppm) 5 27 7 78 C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/12/2015 8:17 AM Residual Cut Sandstone = light to very light gray; dominantly rounded to occasional angular cuttings; moderately firm and friable to occasionally hard and slightly friable; upper very fine to lower fine; well sorted; rounded cuttings; matrix suppoorted with dominant bentonitic to occasional moderately feldspathic matrix; dominant individual grains quartz,occasionally mafic rich and feldspathic grains. Tuffaceous Sandstone/Sand/Conglomeratic Sand = very light gray overall with clear to translucent quartz and volcanic glass dominant, slight trace darker lithics; very fine upper to trace very coarse upper, dominantly fine; angular to subangular; very well sorted; dominantly disaggregated with ashy matrix supporting structure for loose grain sands; trace salt and pepper sandstone; fine; hard; moderate to v ery calcareous cement. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 28 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 195 9855'MD 10050'MD Country: 100 9310'TVD 9495'TVD Averages Before During After Maximum ROP (fph) 106 ft/hr 115 ft/hr 82 ft/hr 415 ft/hr WOB 15 klbs 14 klbs 15 klbs 18 klbs RPM 47 rpm 41 rpm 49 rpm 69 rpm PP 2524 psi 2598 psi 2602 psi 2808 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chloride 31,000 31,000 31,000 31,000 Total Gas 354 599 188 1,108 C1 (ppm) 69,574 114,533 35,452 211,162 C2 (ppm) 381 639 155 1,336 C3 (ppm) 46 28 16 70 C4 (ppm) 14 4 3 30 C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/12/2015 4:38 PM Residual Cut Tuffaceous Sandstone/Sand/Conglomeratic Sand = very light gray to grayish white with very light brown and grayish black, streaky secondary hues; soft to slightly firm; crunchy irregular shaped cuttings; pulverulent; abundant visible glass shards; non calcareous; ash matrix supports sand grains; very fine to medium lower, dominantly fine; angular to subangular; moderately well sorted; trace very coarse lithics. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 29 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 50 10200'MD 10250'MD Country: 100 9639'TVD 9687'TVD Averages Before During After Maximum ROP (fph) 95 ft/hr 82 ft/hr 96 ft/hr 157 ft/hr WOB 16 klbs 15 klbs 16 klbs 20 klbs RPM 49 rpm 34 rpm 48 rpm 50 rpm PP 2661 psi 2570 psi 2652 psi 2765 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.5 lbs/gal 9.4 lbs/gal Chloride 31,000 31,000 29,000 31,000 Total Gas 172 346 205 771 C1 (ppm) 31,296 65,717 37,689 148,096 C2 (ppm) 157 357 224 831 C3 (ppm) 16 33 26 86 C4 (ppm) 2 7 4 19 C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/12/2015 10:26 PM Residual Cut Tuffaceous Sandstone = very light gray to off-white; lower fine to upper coarse, dominant lower medium; moderately sorted; soft to slightly firm; easily friable; angular to subround; dominant subangular; moderate sphericity; bentonitic matrix support with occasional less bentonite, grading to calcite cemented sandstone; individual grains are dominantly quartz, common mafic rich grains; occasionally feldspathic. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 30 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 60 10300'MD 10360'MD Country: 60 9735'TVD 9793'TVD Averages Before During After Maximum ROP (fph) 87 ft/hr 95 ft/hr 82 ft/hr 254 ft/hr WOB 15 klbs 17 klbs 17 klbs 20 klbs RPM 42 rpm 48 rpm 48 rpm 50 rpm PP 2652 psi 2629 psi 2731 psi 2741 psi Mud Weight 9.4 lbs/gal 9.5 lbs/gal 9.5 lbs/gal 9.5 lbs/gal Chloride 29,000 29,000 29,000 29,000 Total Gas 265 127 88 216 C1 (ppm) 48,853 23,427 16,607 39,902 C2 (ppm) 287 138 93 225 C3 (ppm) 31 17 10 33 C4 (ppm) 6 1 2 4 C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-213-20049-00-00 HV B-17 Happy Valley Unit Saxon 169 12/13/2015 1:16 AM Residual Cut Sandstone = dominantly medium to occasionally light gray; lower very fine to lower fine; well sorted; dominantly hard and slightly friable to occasionally moderately firm and friable; well sorted; platy cuttings; exists as thin stringers; grain packed with some calcite cement; occasionally grades to tuffaceous sandstone; dominantly quartz, common maf ics, feldspar. 1 10 100 1000 10000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 40 6 DAILY REPORTS Hilcorp Alaska, LLC KENAI BOROUGH ALASKA DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE 11/27/2015 DEPTH 138 PRESENT OPERATION Prep for Drilling Surface TIME 23:59 pm YESTERDAY 138 24 HOUR FOOTAGE 0 CASING INFORMATION 16"@138' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25 HDBS QHC1GRC Milltooth 12460781 3x16;1x14 138' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 138' MW 9.0 VIS 232 PV 34 YP 56 FL 11.9 Gels 25/62/71 CL- 250 FC 2/0 SOL 4.2 SD OIL 0/95.6 MBT 22.5 pH 10.4 Ca+ 20 Alk 0.25 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS -- CUTTING GAS @ @ WIPER GAS -- CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) @ @ CONNECTION GAS HIGH -- ETHANE (C-2) @ @ AVG -- PROPANE (C-3) @ @ CURRENT -- BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG -- PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Surface PRESENT LITHOLOGY Surface DAILY ACTIVITY SUMMARY Rig up and adjust catwalk; install weatherization tarps; work on electric and breaker for test pump; work on steam system; build spud mud; test BOP; test diverter with state witness; buey line 112’ from ignition 98’; bag close 43 seconds; knife 12 sec; koomy operating pressure 3100psi; bleed to 1500 200 psi increase 19 sec; full recovery 96 sec; 4 bottles @ 2625psi; test PVT Gain/Loss flow alarms - Total Safety Alarms; rig up and tear down rig acceptance check list; function test mud pump; check emergency kill pressure; pressure test stand pipe kelly hose; stage tubulars and strap; install wear bushing. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2885.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Borough DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Nov 28, 2015 DEPTH 480 PRESENT OPERATION Drilling ahead TIME 23:59 pm YESTERDAY 128 24 HOUR FOOTAGE 352 CASING INFORMATION 16" @ 138' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25 HDBS QHC1GRC Milltooth 12460781 3x16; 1x14 128' (480') 352' 4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 488.2 @ 225 1.7 @ 203 107.1 83.13 FT/HR SURFACE TORQUE 5900 @ 470 4028 @ 175 4424.6 5401.48 FT-LBS WEIGHT ON BIT 15 @ 477 0 @ 188 8.5 11.73 KLBS ROTARY RPM 47 @ 206 40 @ 449 40.0 42.57 RPM PUMP PRESSURE 1236 @ 436 612 @ 154 949.7 1228.44 PSI DRILLING MUD REPORT DEPTH 120 MW 9.0 VIS 232 PV 34 YP 56 FL 11.9 Gels 25/62/71 CL- 250 FC 2/0 SOL 4.2 SD -- OIL 0/95.6 MBT 22.5 pH 10.4 Ca+ 20 Alk 0.25 MWD SUMMARY INTERVAL 128 TO 480 TOOLS MWD and Directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1 @ 223 1 @ 223 0.0 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 0 @ 480 0 @ 480 0.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 480 0 @ 480 0.0 AVG 0 PROPANE (C-3) 0 @ 480 0 @ 480 0.0 CURRENT 0 BUTANE (C-4) 0 @ 480 0 @ 480 0.0 CURRENT BACKGROUND/AVG 0 / 0 PENTANE (C-5) 0 @ 480 0 @ 480 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Surface PRESENT LITHOLOGY @ 480’ = Conglomeratic sand 90%; Tuffaceous sand 10% DAILY ACTIVITY SUMMARY Work on communication to rig smart; calibrate tracking and communication equipment; detangle climbing assist; straighten up floor; pick up singles of HWDP; and rack back in derrick; pick up 55 singles of new drill pipe and make, torque, break, re-dope, make, torque, break and rack back in derrick; pick up 45 joints of previously run drill pipe and rack back in derrick. Continue to pick up and rack back drill pipe while changing pulsation dampener on mud pump #2; pick up BHA #1; drill from 128’ to 221’; pull out of hole and pick up smart tools; pump through to warm up tools, down load tools; up load data to LWD; safety meeting on installing nukes; shallow test MWD. Trip back to bottom and resume drilling ahead. Drill from 221’ to 480’ midnight depth. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2885.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Nov 29, 2015 DEPTH 1827 PRESENT OPERATION Drilling ahead TIME 23:59 YESTERDAY 480 24 HOUR FOOTAGE 1347 CASING INFORMATION 16" @ 120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1077.41 12.58 10.33 1071.61 1140.34 14.90 10.96 1132.74 1203.53 16.28 11.42 1193.60 1264.08 17.60 11.34 1251.52 1328.68 19.22 10.56 1312.82 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25 HDBS QHC1GRC Milltooth 12460781 3x16; 1x14 128' (1827') 1699 18.1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 521.7 @ 1684 4.2 @ 1016 118.4 74.86 FT/HR SURFACE TORQUE 9887 @ 1224 4505 @ 493 5696.7 8255.10 FT-LBS WEIGHT ON BIT 27 @ 821 0 @ 688 17.1 25.15 KLBS ROTARY RPM 79 @ 1812 40 @ 504 49.7 77.28 RPM PUMP PRESSURE 2077 @ 1709 841 @ 749 1723.4 2046.44 PSI DRILLING MUD REPORT DEPTH 430 MW 9..35 VIS 202 PV 38 YP 56 FL 9.0 Gels 21/60/71 CL- 200 FC 2/0 SOL 6.8 SD 1.4 OIL 0/93.0 MBT 24.5 pH 9.5 Ca+ 20 Alk 0.15 MWD SUMMARY INTERVAL 128 TO 1827 TOOLS MWD and Directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 89 @ 1790 0 @ 1511 5.8 TRIP GAS 19 CUTTING GAS @ 0 @ WIPER GAS -- CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) 17185 @ 1791 26 @ 1012 944.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 1827 0 @ 1827 0.0 AVG 0 PROPANE (C-3) 0 @ 1827 0 @ 1827 0.0 CURRENT 0 BUTANE (C-4) 0 @ 1827 0 @ 1827 0.0 CURRENT BACKGROUND/AVG 10 / 6 PENTANE (C-5) 0 @ 1827 0 @ 1827 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Surface PRESENT LITHOLOGY @ 1827’ =Sand 50%; Carbonaceous Shale 10%; Coal 10%; Tuffaceous claystone 10%; Tuffaceous siltstone 10%; Tuffaceous sand 10% DAILY ACTIVITY SUMMARY Rotate 490’ to 565’, slide 565’ to 590’; rotate 590’ to 623’, slide 623’ to 644’; rotate 644’ to 687’, slide 687’ to 709’, rotate from 709’ to 753’. Drill from 753’ to 1497’. Circulate bottoms up for wiper trip; pull out of hole from 1497’ to 765’ with no issues; hole took 0.6 barrels over calculated fill. Trip back to bottom and resume drilling; Drill from 1497’ to 1827’ midnight depth. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2885.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Nov 30, 2015 DEPTH 2980 PRESENT OPERATION Circulating, Prep for trip out TIME 23:59 YESTERDAY 1827 24 HOUR FOOTAGE 1153 CASING INFORMATION 16" @ 120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2323.26 21.20 11.77 2244.09 2386.79 21.33 11.76 2303.30 2450.97 21.58 11.37 2363.03 2514.88 21.76 11.47 2422.43 2578.09 21.93 11.43 2481.10 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25 HDBS QHC1GRC Milltooth 12460781 3x16; 1x14 128' (2980') 2852 34.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 443.1 @ 1843 2.2 @ 2494 87.3 36.70 FT/HR SURFACE TORQUE 10275 @ 2721 6374 @ 2495 8353.7 8970.16 FT-LBS WEIGHT ON BIT 28 @ 2522 7 @ 2942 24.2 25.66 KLBS ROTARY RPM 91 @ 2874 70 @ 2581 76.7 82.64 RPM PUMP PRESSURE 2256 @ 2313 1692 @ 2431 2050.2 2027.87 PSI DRILLING MUD REPORT DEPTH 1732/1692 MW 9.35 VIS 145 PV 29 YP 43 FL 9.0 Gels 15/77/91 CL- 225 FC 2/0 SOL 7.5 SD 0.25 OIL 0/92.3 MBT 20.5 pH 8.7 Ca+ 40 Alk 0.20 MWD SUMMARY INTERVAL 128 TO 2980 TOOLS MWD and Directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 138 @ 2245 2 @ 2979 28.3 TRIP GAS 138 CUTTING GAS @ @ WIPER GAS -- CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) 26600 @ 2245 484 @ 2979 5669.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 202 @ 2245 0 @ 2121 25.9 AVG 0 PROPANE (C-3) 0 @ 2980 0 @ 2980 0.0 CURRENT 0 BUTANE (C-4) 0 @ 2980 0 @ 2980 0.0 CURRENT BACKGROUND/AVG 1 / 28 PENTANE (C-5) 0 @ 2980 0 @ 2980 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga PRESENT LITHOLOGY @ 2980’ =Sand 50%; Tuffaceous claystone 50%; DAILY ACTIVITY SUMMARY Drill ahead from 1827’ to 1840’; rotate from 1840’ to 2244’, circulate hole clean for short trip. Make short trip; pull out of hole from 2244’ to 1454’ no issues; run in hole from 1454’ to 2241’, 9’ of hole fill; hole took 1.3 barrels under calculated displacement. Drill from 2244’ to 2752’ pumped nut plug sweep at 2430’. Rotate from 2752’ to 2878’ circulate cuttings out of hole, remove clamp from quill, break connection between saver sub and double ball valve sub; break saver sub out of stump with iron roughneck and rack stand back; install new saver sub; circulate while installing back up clamp; run stand back in hole; rotate from 2878’ to 2980’; circulating two bottoms up. Preparing to pull out of hole. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2885.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 1, 2015 DEPTH 2980 PRESENT OPERATION Rigging up wireline TIME 23:59 YESTERDAY 2980 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2704.82 21.54 10.05 2598.69 2768.45 20.97 9.24 2657.98 2831.65 21.12 9.36 2716.96 2894.12 21.3 9.64 2775.21 2931.99 21.45 9.49 2810.47 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25 HDBS QHC1GRC Milltooth 12460781 3x16; 1x14 128' (2980') 2852 34.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2891/2809 MW 9.35 VIS 574 PV 18 YP 29 FL 7.6 Gels 11/23/28 CL- 350 FC 2/0 SOL 7.5 SD 0.10 OIL 0/92.3 MBT 20.0 pH 8.4 Ca+ 20 Alk 0.25 MWD SUMMARY INTERVAL TO TOOLS None GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 77 CUTTING GAS @ @ WIPER GAS -- CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 1 / 3 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga PRESENT LITHOLOGY @ 2980’ =Sand 50%; Tuffaceous claystone 50%; DAILY ACTIVITY SUMMARY Pull out of hole from 2980’ to 1757’. Pulled free and continued to trip out of hole from 1757 to 450’ hole took 2 barrels over displacement. 12/1/2015: Remove sources and down load; lay down BHA; clean floor and prepare to run in hole; Run in hole and clean out tight spot at 2334’/; kelly up and wash through; no issues; no fill; 2.4 barrels under calculated displacement; pump high vis nut plug sweep and circulate hole clean; pump second sweep and circulate hole clean. Trip out from 2980’ to 1440’ with no issues. POOH from 1440’ to the bit; scrape clay off of bit and stabilizers, drain motor and flush with water before laying it down, no issues hole took 4.4 barrels over calculated displacement; clean rig floor; and rig up wire line. Max Gas for this 24 hours was the trip gas of 77 units. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2885.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 2, 2015 DEPTH 2980 PRESENT OPERATION Running Casing TIME 23:59 YESTERDAY 2980 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2704.82 21.54 10.05 2598.69 2768.45 20.97 9.24 2657.98 2831.65 21.12 9.36 2716.96 2894.12 21.3 9.64 2775.21 2931.99 21.45 9.49 2810.47 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2980/2855 MW 9.30 VIS 57 PV 18 YP 27 FL 7.6 Gels 11/26/33 CL- 200 FC 2/0 SOL 7.3 SD 0.10 OIL 0/92.5 MBT 21.0 pH 8.3 Ca+ 40 Alk -- MWD SUMMARY INTERVAL TO TOOLS None GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 7 CUTTING GAS @ @ WIPER GAS -- CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 1 / 1 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga PRESENT LITHOLOGY @ 2980’ =Sand 50%; Tuffaceous claystone 50%; DAILY ACTIVITY SUMMARY Continue to rig up wire line equipment and tools; Run in hole for RFT log; valid test =10; unstabilized=13; tight tests= 8. POOH with wireline; total tool assembly length=31’; rig down wireline tools and equipment; service top drive, crown, blocks, and draw works; Pick up previous bit and motor and make up 8” flex collars. Continue picking up BHA for clean out run; run in hole from 107’ to 2980’; pump high vis sweep and circulate out; POOH from 2980’ to 2011’; POOH from 2011 to 202’; lay down 8” directional tools, flex collars, mud motor, and bit; clean and organize rig floor; suck out cellar box and remove wear bushing; rig up Weatherford casing running equipment. Continue to rig up Weatherford; set up pipe racks and stage shoe track; stage centralizers, pre-job safety meeting with crew and Weatherford; pick up shoe track and check float, Max gas for past 24 hours was 7 units. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2885.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 3, 2015 DEPTH 2980 PRESENT OPERATION Running Casing TIME 23:59 YESTERDAY 2980 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2704.82 21.54 10.05 2598.69 2768.45 20.97 9.24 2657.98 2831.65 21.12 9.36 2716.96 2894.12 21.3 9.64 2775.21 2931.99 21.45 9.49 2810.47 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL TO TOOLS None GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 5 CUTTING GAS @ @ WIPER GAS -- CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 / 0.5 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga PRESENT LITHOLOGY @ 2980’ = Sand 50%; Tuffaceous claystone 50%; DAILY ACTIVITY SUMMARY Run in hole with casing; condition mud and circulate; stage mud pump up to 7 bbls per minute; continue to run in hole with casing to 2943’; condition mud and circulate ; stage pump up to 7 barrels per minute; change out short bails to long bails; pick up and make up landing joint and hanger. Rig up cross over and cement head circulating while rigging up Schlumberger cementers; pump 10 barrels of water to pits and 2 barrels to well; shut down and shut in for pressure test; pump cement; shut down and drop top plug and bump plug and held for 5 minutes; checked float and did not hold; bleed back 2.5 barrels; shut in head and hold 450psi; bumped plug at 12:18 hours; clean up cement truck back to cellar; suck out cellar box with vac truck; flush out diverter with black water; flush cement lines with water and blow down lines with air ; rig down cement lines; waiting on cement to set up; nipple down diverter line; install choke hose to catwalk; continue to nipple down diverter line; flow bleeder line, knife valve and koomey lines, 4 bolt flanges; install kill line to mez. valve; clean work area; function and wash bag; bleed pressure off of accumulator; rig down and lay down cement head; clear rig floor; pull landing joint and make up pack off run tool; set pack off; continue to nipple down diverter stack; remove knife valve, bell nipple, annular bag,; divert “T”, DSA, stage and nipple up well head. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2885.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 4, 2015 DEPTH 2980 PRESENT OPERATION Testing BOP'S TIME 23:59 YESTERDAY 2980 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2704.82 21.54 10.05 2598.69 2768.45 20.97 9.24 2657.98 2831.65 21.12 9.36 2716.96 2894.12 21.3 9.64 2775.21 2931.99 21.45 9.49 2810.47 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL TO TOOLS None GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga PRESENT LITHOLOGY @ 2980’ = Sand 50%; Tuffaceous claystone 50%; DAILY ACTIVITY SUMMARY Stage and nipple up well head and test; Stage BOP stack and spacer spool; clean area and ready equipment for BOP nipple up; set and raise gas buster; install spacer spool. Continue to nipple up BOP’s; install 2’ spacer spool and 16” spacer spool; pick up and make up BOP’s on spacer spools; install kill line on mezzanine deck; install kill HCR, inside choke and choke HCR on BOP’s ; Torque bolts on flanges; continue torqueing bolts on flanges; install catch can, flow line, bell nipple, install choke hose to BOP’s; hook up bleed off line to flow line; connect BOP chains to support stack; hook up koomey lines; function test BOP’s. Rig up test equipment; flood the stack and choke manifold while removing long bails; Total Safety test alarms. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2885.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 5, 2015 DEPTH 2980 PRESENT OPERATION Picking up BHA TIME 23:59 YESTERDAY 2980 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 120' ; 9 5/8" @ 2970' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2704.82 21.54 10.05 2598.69 2768.45 20.97 9.24 2657.98 2831.65 21.12 9.36 2716.96 2894.12 21.3 9.64 2775.21 2931.99 21.45 9.49 2810.47 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.50 Varel V513GN PDC 4008323 4x12; 1x10;1x11;1x14 2980' 2980' 0 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 2980' TO 2980' TOOLS Directional and triple combo tools GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga PRESENT LITHOLOGY @ 2980’ = Sand 50%; Tuffaceous claystone 50%; DAILY ACTIVITY SUMMARY Recalibrate gas detectors; shell test; re-torque flange between inside kill and HCR kill; fix hydro leak on HCR kill; retest shell - good test; Test upper pipe rams, annular; lower pipe rams, TIW, and Koomey draw down test; test coke manifold; blind rams; inside kill; electric choke; and manual choke; rig down and blow down test equipment; blow down choke manifold and kill line; install wear bushing. Pick up 90 joints of drill pipe and run in to 2842’- tagged cement at 2842’; pull out of hole from 2842’ to 994’ pull out to flex collar; strap and tally drill pipe; pick up 64 joints drill pipe; and pull out and rack back in derrick. Continue to pull out and rack back in derrick; ready floor to pick up BHA; PJSM with crew and Halliburton; blow down kill line; Pick up and make up BHA; T/TM collar; circulate and warm tools; down load tools; strap and tally drill pipe; shallow test MWD tool; PJSM with crew and Halliburton; load source; blow down top drive; continue to pick up and make up BHA. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2885.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 06, 2015 DEPTH 3616 PRESENT OPERATION Drill ahead TIME 23:59 YESTERDAY 2980 24 HOUR FOOTAGE 636 CASING INFORMATION 16" @ 120' ; 9 5/8" @ 2970' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2931.99 21.45 9.49 2810.47 3032.16 21.60 9.76 2903.65 3094.18 21.62 8.29 2961.31 3156.32 21.52 7.41 3019.10 3280.15 20.57 9.92 3134.48 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.50 Varel V513GN PDC 4008323 4x12; 1x10;1x11;1x14 2980 3616 636 26.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 453.4 @ 3390 6.5 @ 3378 121.4 58.62 FT/HR SURFACE TORQUE 8970 @ 2980 5499 @ 3000 6999.7 7318.33 FT-LBS WEIGHT ON BIT 25 @ 2980 0 @ 3436 8.2 7.93 KLBS ROTARY RPM 85 @ 3309 27 @ 3078 56.2 70.63 RPM PUMP PRESSURE 2027 @ 2980 1001 @ 2999 1570.5 1636.53 PSI DRILLING MUD REPORT DEPTH 3555 MW 9.55 VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 2980 TO 3616 TOOLS Triple combo and directional tools GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 457 @ 3304 1 @ 3462 65.7 TRIP GAS -- CUTTING GAS @ @ WIPER GAS -- CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) 93426 @ 3304 226 @ 3462 13186.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 263 @ 3312 0 @ 3180 44.0 AVG 0 PROPANE (C-3) 0 @ 3616 0 @ 3616 0.0 CURRENT 0 BUTANE (C-4) 0 @ 3616 0 @ 3616 0.0 CURRENT BACKGROUND/AVG 43 / 66 PENTANE (C-5) 0 @ 3616 0 @ 3616 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Beluga PRESENT LITHOLOGY @ 3600’: Tuffaceous claystone 80%; Tuffaceous siltstone 20% DAILY ACTIVITY SUMMARY Run in hole with HWDP; turn elevator, input pipe tally, pick up drill pipe from cat walk; break in new pipe threads to 2630’. Continue picking up drill pipe from 2630’ to 2812’; circulate bottoms up to air out drill pipe and casing; rig up to test casing; test casing to 3300psi; hold pressure for 30minutes; rig down test equipment; slip and cut 90’ of drill line; drill out float equipment; continue to drill out float equipment and 20’ of new formation; displace with 9.3 ppg KCl mud; Rig up to perform FIT to 414 psi , bleed down to 300 psi in 10 minutes; pumped 17.58 gals and bleed 10gals back; rig down test equipment; drill from 3000’ to 3202’ Continue to drill ahead with occasional slides from 3202’ to 3616’ midnight depth.High gas this 24 hours 457 units drill gas at 3304'; no connection gasses; average background 66 units gas. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2885.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 07, 2015 DEPTH 4990 PRESENT OPERATION Wiper Trip TIME 23:59 YESTERDAY 3616 24 HOUR FOOTAGE 1374 CASING INFORMATION 16" @ 120' ; 9 5/8" @ 2970' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4709.49 21.41 11.86 4474.57 4771.11 21.43 11.03 4531.93 4833.32 21.17 10.23 4589.89 4895.49 20.69 10.04 4647.95 4958.51 20.48 9.74 4706.96 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.50 Varel V513GN PDC 4008323 4x12; 1x10;1x11;1x14 2980 (4990) 2010 38.6 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 918.1 @ 3746 2.5 @ 4548 135.5 126.59 FT/HR SURFACE TORQUE 9752 @ 4915 6438 @ 3688 7845.3 9441.01 FT-LBS WEIGHT ON BIT 17 @ 4564 2 @ 3642 10.0 14.77 KLBS ROTARY RPM 84 @ 4917 60 @ 4650 66.6 73.99 RPM PUMP PRESSURE 2003 @ 4942 939 @ 4427 1740.9 1919.95 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 2980 TO 3990 TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1103 @ 3934.00000 7 @ 4867.00000 195.2 TRIP GAS 131 CUTTING GAS 0 @ 4990.00000 0 @ 4990.00000 0.0 WIPER GAS -- CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) 212243 @ 3932.00000 1414 @ 4866.00000 36811.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 1264 @ 3932.00000 1 @ 4965.00000 146.8 AVG 0 PROPANE (C-3) 108 @ 3932.00000 0 @ 4770.00000 5.3 CURRENT 0 BUTANE (C-4) 22 @ 3932.00000 0 @ 3991.00000 0.5 CURRENT BACKGROUND/AVG 31 / 195 PENTANE (C-5) 0 @ 4990.00000 0 @ 4990.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Beluga PRESENT LITHOLOGY Carbonaceous shales 20% ; Coal 10%; Sand 30%; Tuffaceous Claystone 20%; Tuffaceous Siltstone 20% DAILY ACTIVITY SUMMARY Drill from 3616’ to 3997’; pull off bottom and flow check well; Begin wiper trip. POOH on elevators from 3990’ to 3614’.; continue with wiper trip from 3714’ to 3234’; washing and reaming from 3234’ to 2967’; rig service ; change our grabber dies on TDS; change out saver sub; run in hole from 2967’ to 3937’ and wash last stand to bottom; drill from 3997’ to 4114’; drill from 4114’ to 4568’. Drill from 4568’ to 4992’; prep for wiper trip take survey, stand back one stand, blow down top drive; flow check well; POOH. From 4992’ . High gas for this 24 hours was 1103 units. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2885.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 08, 2015 DEPTH 6060 PRESENT OPERATION Drilling ahead TIME 23:59 YESTERDAY 4990 24 HOUR FOOTAGE 1070 CASING INFORMATION 16" @ 120' ; 9 5/8" @ 2970' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5516.17 20.68 12.58 5226.80 5578.96 20.16 12.03 5285.64 5641.43 19.72 11.12 5344.36 5703.23 21.47 14.18 5402.21 5763.57 20.91 13.73 5458.48 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.50 Varel V513GN PDC 4008323 4x12; 1x10;1x11;1x14 2980 6060 3080 47.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 456.6 @ 5751 4.7 @ 5862 140.0 81.53 FT/HR SURFACE TORQUE 11240 @ 6005 250 @ 6059 8819.2 0.00 FT-LBS WEIGHT ON BIT 18 @ 5671 4 @ 4993 12.0 12.84 KLBS ROTARY RPM 89 @ 5741 0 @ 6059 63.3 0.00 RPM PUMP PRESSURE 2266 @ 5810 1710 @ 6000 2016.9 1924.36 PSI DRILLING MUD REPORT DEPTH 5985/5667 MW 9.40 VIS 47 PV 13 YP 20 FL 4.4 Gels 6/8/13 CL- 30500 FC 1/2 SOL 5.6 SD 0.15 OIL 0.5/91.5 MBT 3.3 pH 9.6 Ca+ 60 Alk 0.80 MWD SUMMARY INTERVAL 2980 TO 6060 TOOLS Directional and triple combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1132 @ 5802 41 @ 5430 217.1 TRIP GAS 1131 CUTTING GAS @ @ WIPER GAS -- CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) 229623 @ 5802 8205 @ 5430 42102.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 265 @ 5291 2 @ 5161 38.0 AVG 0 PROPANE (C-3) 11 @ 5619 0 @ 5614 0.1 CURRENT 0 BUTANE (C-4) 0 @ 6060 0 @ 6060 0.0 CURRENT BACKGROUND/AVG 96 / 217 PENTANE (C-5) 0 @ 6060 0 @ 6060 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek T-6 PRESENT LITHOLOGY @6070’ = Sand 20%; Tuffaceous Claystone 40%; Tuffaceous Siltstone 40% DAILY ACTIVITY SUMMARY @ 4992’ prep for wiper trip take survey, stand back one stand, blow down top drive; flow check well; POOH on elevators from 4992’ to 2944’ working through tight spots; flow check well; clean rig floor; clean crown depth sensor; re -calibrate depth sensor; re calibrate hook load; run in hole on elevators from 2944’ to 4939; wash down last stand drill from 4992’ to 5056’. Drill from 5056’ to 5490’; drill from5490’ to 5801’; circulate bottoms up; POOH from 5801’ to 4462’; continue to POOH from 4462’ to 3898’. Run in hole from 3898’ to 5790’; kelly up and wash down 10’ of fill; drill ahead from 5801’ to 6060’ midnight depth. Max gas this 24 hours was a wiper trip gas @ 5801' with 1132 units gas CANRIG PERSONNEL ON BOARD 4 DAILY COST $2885.00 REPORT BY Donna.New Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska. LLC DATE Dec 09, 2015 DEPTH 7412 PRESENT OPERATION Wiper trip TIME 23:26:49 YESTERDAY 6060 24 HOUR FOOTAGE 1352 CASING INFORMATION 16" @ 120'; 9 5/8" @ 2970' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7252.34' 19.89 8.54 6849.14' 7314.83' 20.67 12.28 6907.77' 7377.10' 19.51 12.42 6968.24' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" Varel VS13GN PDC 4008323 4x12;1x10;1x11; x14 2980' 4432' 59.1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 491.6 @ 6373 2.3 @ 6172 146.6 204.9 FT/HR SURFACE TORQUE 11567 @ 7313 102 @ 6239 9437.9 9984.7 FT-LBS WEIGHT ON BIT 17 @ 7127 3 @ 6235 12.7 12.4 KLBS ROTARY RPM 80 @ 6442 5 @ 6670 56.1 58.4 RPM PUMP PRESSURE 2379 @ 6701 1391 @ 6626 2159.7 2058.5 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 2980' TO 7412' TOOLS Directional and Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 953 @ 7088 49 @ 6242 323.0 TRIP GAS CUTTING GAS @ @ WIPER GAS 890 2 6606' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 188033 @ 6547 9791 @ 6242 63037.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 14237 @ 6540 1 @ 6107 477.1 AVG 0 PROPANE (C-3) 100 @ 7081 0 @ 6107 13.8 CURRENT 0 BUTANE (C-4) 25 @ 7081 0 @ 6434 1.7 CURRENT BACKGROUND/AVG 180/323 PENTANE (C-5) 0 @ 7412 0 @ 7412 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek T-17 PRESENT LITHOLOGY @ 7410' = Sand 50%; Tuffaceous Siltstone; 30% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Drill from 6060’ to 6606’, Pump high vis sweep and circulate bottoms up (w/50% increase in cuttings); perform short trip from 6606’ to 5046’ (tight spots at 5627’-5607’, 5305’, 5237’, and 5225’). RIH from 5046’ to 6527’ (tagged hole fill), wash and ream from 6527’ to 6606’ (had 25’ hole fill). Drill from 6606’ to 7412’. Pump high vis sweep and circulate bottoms. Begin short trip at 7412’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2885.00 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 10, 2015 DEPTH 8221 PRESENT OPERATION Wiper trip RIH TIME 24:00 YESTERDAY 7412 24 HOUR FOOTAGE 809 CASING INFORMATION 16" @ 120'; 9 5/8" @ 2970' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7997.87' 20.26 8.29 7544.49' 8061.78' 21.28 10.58 7604.25' 8123.84' 20.76 10.79 7662.18' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Varel VS13GN 4008323 4x12;1x10;1x11;1x14 2980' 5241' 66.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 454.9 @ 8084 3.9 @ 8097 129.5 74.2 FT/HR SURFACE TORQUE 11844 @ 8089 102 @ 7424 9198.8 10402.8 FT-LBS WEIGHT ON BIT 18 @ 8057 3 @ 7537 13.4 14.2 KLBS ROTARY RPM 69 @ 8211 0 @ 8051 43.3 68.9 RPM PUMP PRESSURE 2411 @ 8118 1843 @ 7785 2188.6 2240.1 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 2980' TO 8221' TOOLS Directional and Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1246 @ 8168 43 @ 8102 275.1 TRIP GAS CUTTING GAS @ @ WIPER GAS 842 @ 7412' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 273314 @ 8168 8013 @ 7537 52442.9 CONNECTION GAS HIGH 0 ETHANE (C-2) 1775 @ 8170 9 @ 7425 240.6 AVG 0 PROPANE (C-3) 99 @ 8168 0 @ 7426 14.9 CURRENT 0 BUTANE (C-4) 30 @ 8172 0 @ 7904 0.8 CURRENT BACKGROUND/AVG 190/275 PENTANE (C-5) 0 @ 8221 0 @ 8221 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY @ 8220' = Sandstone 20%; 60% Tuffaceous Siltstone; 20% Tuffaceous Claystone DAILY ACTIVITY SUMMARY Monitor well, well static. POOH on elevators from 7412’ to 5801’. 2.5 barrels lost to hole. Tight spots at 7073’ (20k over), 7062’ (25k over), 6780’-6760’ (60k over), 6750’ (60k over), 6469’ (50k over), 6399’ (40k over), 6379’ (60k over), 6373’-6367’ (20k CANRIG PERSONNEL ON BOARD over), 6353’-6349’ (40k over), 6345’-6341’ (40k over), and 6266’ (20k over). Service rig. RIH on elevators from 5863’ to 7333’. Wash from 7333’ to 7412’. Drill from 7412’ to 8222’. Pump high vis DAILY COST le to break out connection, break out saver sub and inspect same. Rack back one stand, rig up headpine and circulate (inconclusive). Make up new saver sub, reset top drive torque to 4150 psi and 21504 ft lbs/torque. sweep, circulate bottoms up (60% increase in cuttings).Unab POOH from 8159’ to 6545’ (Backream 7165 REPORT BY ’-7034’). Service rig. RIH on elevators from 6604’. Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 11, 2015 DEPTH 9287 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 8221 24 HOUR FOOTAGE 1066 CASING INFORMATION 16" @ 120', 9 5/8" @ 2970' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9182.10' 16.78 24.89 8663.67' 9118.70' 15.71 27.52 8602.80' 9055.82' 14.90 29.52 8542.15 8992.96 16.07 28.82 8481.57' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Varel VS13GN 4008323 4x12,1x10,1x11,1x14 2980' 6307' 79 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 460.3 @ 9196 6.5 @ 8349 114.4 73.9 FT/HR SURFACE TORQUE 15566 @ 9231 402 @ 8353 9493.9 15566.9 FT-LBS WEIGHT ON BIT 18 @ 8668 1 @ 9029 13.1 17.9 KLBS ROTARY RPM 69 @ 8462 0 @ 8353 47.2 29.7 RPM PUMP PRESSURE 2570 @ 9220 1708 @ 9089 2283.4 2514.1 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 2980' TO 9287' TOOLS Directional and Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1098 @ 9013 30 @ 8656 239.7 TRIP GAS CUTTING GAS @ @ WIPER GAS 1009u @ 8221', 834u @9028' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 221306 @ 9197 6027 @ 8656 46717.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 1523 @ 9015 15 @ 8681 254.1 AVG 0 PROPANE (C-3) 115 @ 9059 0 @ 8663 21.2 CURRENT 0 BUTANE (C-4) 43 @ 8978 0 @ 8444 3.0 CURRENT BACKGROUND/AVG 200/240 PENTANE (C-5) 6 @ 9197 0 @ 9213 0.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek 80 PRESENT LITHOLOGY @ 9225' = Sandstone 40%; Sand 105; Tuffaceous Claystone 10%, Tuffaceous Siltstone 40% DAILY ACTIVITY SUMMARY Finish RIH on elevators from 6604’ (ream 8104’ to bottom), Drill from 8221’ to 9028’, pump high vis sweep and circulate bottoms up (150% increase in cuttings), wipe hole 9028’-7464’ (no tight spots), RIH from 7464’ to 8977’ (tagged at 8977’), wash down fr CANRIG PERSONNEL ON BOARD om 8977’ to 9028’, drill from 9028’ to 9287’ DAILY COST 4 REPORT BY $2885.00 Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 12, 2015 DEPTH 10295 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 9287 24 HOUR FOOTAGE 1008 CASING INFORMATION 16" @ 120', 9 5/8" @ 2970' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10197.27' 15.93 33.51 9636.33' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Varel VS13GN 4008323 4x12,1x10,1x11,1x14 2980' 7315' 91 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 438.3 @ 10134 2.0 @ 9611 105.7 96.6 FT/HR SURFACE TORQUE 16902 @ 9948 330 @ 9617 10969.9 12978.4 FT-LBS WEIGHT ON BIT 19 @ 9750 3 @ 9983 14.5 16.9 KLBS ROTARY RPM 69 @ 10046 1 @ 9617 48.1 48.7 RPM PUMP PRESSURE 2808 @ 9993 2006 @ 9880 2538.1 2644.4 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 2980' TO 10295' TOOLS Directional and Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1366 @ 9453 38 @ 9486 365.0 TRIP GAS CUTTING GAS @ @ WIPER GAS 620u @ 9851' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 262311 @ 9471 7712 @ 9288 71193.8 CONNECTION GAS HIGH 0 ETHANE (C-2) 1532 @ 9685 33 @ 9486 364.9 AVG 0 PROPANE (C-3) 171 @ 9685 0 @ 10065 29.2 CURRENT 0 BUTANE (C-4) 77 @ 9688 0 @ 9491 6.7 CURRENT BACKGROUND/AVG 450/365 PENTANE (C-5) 11 @ 9471 0 @ 9441 0.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek 120 PRESENT LITHOLOGY @ 10230' = Sandstone10%; Sand 10%; Tuffaceous Sandstone 70%; Tuffaceous Siltstone 10% DAILY ACTIVITY SUMMARY Drill from 9287’ to 9484’. Rack back one stand, condition mud and circulate, change out swab in mud pump #2. RTB. Drill from 9484’ to 9851’. Pump high vis sweep and circulate bottoms (200% increase in cuttings). Wipe hole frim 9851’ to 8275’ (no tight spots). RIH from 8275’ to 9826’ (tagged up). Ream to bottom. Drill from 9851’ to 10232’. Pump high vis sweep, circulate ~37 minutes (150% increase in cuttings). Drill from 10232’ to 10295'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2885.00 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 13, 2015 DEPTH 10695 PRESENT OPERATION POOH at TD TIME 24:00 YESTERDAY 10232 24 HOUR FOOTAGE 463 CASING INFORMATION 16" @ 138', 9 5/8" @ 2970' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10695' Projected 12.58 38.25 10117.52' 10641.17' 12.58 38.25 10064.98' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Varel VS13GN 4008323 4x12,1x10,1x11,1x14 2980' 10695' 7715' 97.06 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 421.4 @ 10580 4.1 @ 10244 91.8 61.5 FT/HR SURFACE TORQUE 15492 @ 10545 506 @ 10234 12637.3 13054.2 FT-LBS WEIGHT ON BIT 22 @ 10505 4 @ 10234 16.8 14.7 KLBS ROTARY RPM 77 @ 10581 0 @ 10234 56.9 73.5 RPM PUMP PRESSURE 2966 @ 10437 2226 @ 10398 2662.1 2550.4 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 2980' TO 10695' TOOLS Directional and Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 761 @ 10589 35 @ 10464 165.5 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 136040 @ 10587 5923 @ 10464 29911.8 CONNECTION GAS HIGH 0 ETHANE (C-2) 1338 @ 10587 30 @ 10393 207.3 AVG 0 PROPANE (C-3) 158 @ 10587 1 @ 10400 26.2 CURRENT 0 BUTANE (C-4) 49 @ 10632 0 @ 10531 5.1 CURRENT BACKGROUND/AVG 15/166 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek 155 PRESENT LITHOLOGY @ 10695': Carbonaceous Shale 10%; Coal 40%; Tuffaceous Claystone 10%; Tuffaceous Siltstone 20%; sandstone 10%; Tuffaceous Sandstone DAILY ACTIVITY SUMMARY Drill from 10295’ to 10397’, pumped walnut sweep with 50% increase in cuttings. Drill from 10397’ to 10695’. Circulate bottoms up at TD. Pump 18 barrel high vis sweep and circulate out same (75% increase in cuttings). POOH from 10695’ to 9115’. Pump dry job. POOH on elevators from 9115’ to about 4815’. Encounter tight hole, backream to about 4628. POOH on elevators from ~4628’ to ~4560’. Backream from ~4560’ to ~3465’. POOH on elevators from ~3465’ to 3087’. Break circulation. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2885.00 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 14, 2015 DEPTH 10695 TD PRESENT OPERATION POOH at TD after Wiper Trip TIME 24:00 YESTERDAY 10695 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 138', 9 5/8" @ 2970' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10695' Projected 12.58 38.25 10117.52' 10641.17' 12.58 38.25 10064.98' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Varel VS13GN 4008323 4x12,1x10,1x11,1x14 2980' 10695' 7715' 97.06 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 2980' TO 10695' TOOLS Directional and Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 83 @ 28 @ 49 TRIP GAS CUTTING GAS @ @ WIPER GAS 1300u @ 10695' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 30/49 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek 155 PRESENT LITHOLOGY @ 10695': Carbonaceous Shale 10%; Coal 40%; Tuffaceous Claystone 10%; Tuffaceous Siltstone 20%; sandstone 10%; Tuffaceous Sandstone DAILY ACTIVITY SUMMARY Break circulation. Pump high sweep at 3091’. Pump high vis sweep (100% increase in cuttings). POOH on elevators from 3091’ to 2941’. Slip and cut drill line. Service rig. Lay down bad pipe joints. RIH on elevators from 3941’ to 8472’. Circulate while cooling down rad cooling fan for Eaton brake and hydraulics. RIH from 8472’ to 10649’ (tagged on hole fill), wash to bottom; Pump high vis sweep and circulate out; Continue circulate high vis sweep out; Pumped second high vis sweep and circulate out, weight up to 9.7 ppg; POOH on elevators from 10695’ to 2944’. Flow check well. Check TDS, tong, iron wrench (all good). POOH on elevators from 2944’ to 2547’. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2025 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 15, 2015 DEPTH 10695 TD PRESENT OPERATION RIH after logs with clean out BHA TIME 24:00 YESTERDAY 10695 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 138', 9 5/8" @ 2970' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10695' Projected 12.58 38.25 10117.52' 10641.17' 12.58 38.25 10064.98' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Varel VS13GN 4008323 4x12,1x10,1x11,1x14 2980' 10695' 7715' 97.06 3-2-BT-A-X-2-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL TO TOOLS Dumb iron clean out BHA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 21 @ 2 @ 12 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 2/12 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek 155 PRESENT LITHOLOGY @ 10695': Carbonaceous Shale 10%; Coal 40%; Tuffaceous Claystone 10%; Tuffaceous Siltstone 20%; sandstone 10%; Tuffaceous Sandstone DAILY ACTIVITY SUMMARY POOH on elevators from 2547’ to 166’. Handle and lay down BHA. Change out rubber air bag on bell nipple/clean off rig floor. Hold JSA meeting with rig and Schlumberger wireline crew. Rig up wireline equipment. RIH with RFT logging tools (took 5 impressions 3096’-3265’). RIH with RFT logging tools (took 8 impressions 3940’-4424’). RIH with RFT logging tools to 6724’, to 7910’. Tagged up on bridge at 7910’ and could not RIH further. Took a total of 45 impressions with 32 good impressions. POOH withRFT wireline tools. Rig down Sclumberger wireline equipment. Clear rig floor, stage dumb iron assembly. Pick up and make up BHA. Pick up 2 joints from catwalk. RIH on elevators to 2903’. Fill pipe, circulate and warm mud at shoe. Service rig. RIH on elevators from 2909’ to 5147’. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2025.00 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 16, 2015 DEPTH 10695 TD PRESENT OPERATION POOH, laying down drill pipe TIME 24:00 YESTERDAY 10695 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 138', 9 5/8" @ 2970' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10695' Projected 12.58 38.25 10117.52' 10641.17' 12.58 38.25 10064.98' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL TO TOOLS Dumb iron clean out BHA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 76 @ 29 @ 50 TRIP GAS 385u @ 10695' CUTTING GAS @ @ WIPER GAS 228u @ 10695' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 35/50 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek 155 PRESENT LITHOLOGY @ 10695': Carbonaceous Shale 10%; Coal 40%; Tuffaceous Claystone 10%; Tuffaceous Siltstone 20%; sandstone 10%; Tuffaceous Sandstone DAILY ACTIVITY SUMMARY RIH on elevators from 5147’ to 9294’ (tight spots 7920’, 8296’, 8427’, wash and ream from 9035’ to 9050’ and from 9166’ to 9183’). RIH (tight 9294’, 9370’, 9555’ with spot washing and reaming required). Wash and ream from 9555’ to 10695’. Pump sweep, rotate and reciprocate out sweep. POOH from 10695’ to 8990’ (tight spots at 9952’, 9940’, 9885’, and 9683’). RIH from 8990’ to 10170’. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2025.00 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 17, 2015 DEPTH 10695 TD PRESENT OPERATION Running 5 1/2" liner TIME 24:00 YESTERDAY 10695 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 138', 9 5/8" @ 2970' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10695' Projected 12.58 38.25 10117.52' 10641.17' 12.58 38.25 10064.98' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek 155 PRESENT LITHOLOGY @ 10695': Carbonaceous Shale 10%; Coal 40%; Tuffaceous Claystone 10%; Tuffaceous Siltstone 20%; sandstone 10%; Tuffaceous Sandstone DAILY ACTIVITY SUMMARY POOH, laying down drill pipe from 8741’ to 2860’ (encounter 15k overpull at 6450’ and 6098’, hole taking 9 barrels over calculated hole fill). Cut and slip 110’ drill line. Lay down drill pipe from 2860’ to bit (hole 10.3 barrels over calculated fill volume for entire trip). Pull wear bushing and install test plug. Change upper pipe rams to 5 ½”. Test upper rams 250 psi for 5 minutes / 4500 psi for 10 minutes. Dummy run hanger = good land. Clear rig floor, stage casing centralizers. Rig up Weatherford power tongs, air slips, spider. Fill up line stage shoe track. Hold JSA. Run 5 ½” liner to about 1750’. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2025.00 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Borough, Alaska DAILY WELLSITE REPORT HVB-17 REPORT FOR Hilcorp Alaska, LLC DATE Dec 18, 2015 DEPTH 10695 TD PRESENT OPERATION Circulating 5.5" casing TIME 24:00 YESTERDAY 10695 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 138', 9 5/8" @ 2970' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10695' Projected 12.58 38.25 10117.52' 10641.17' 12.58 38.25 10064.98' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 63 @ 49 @ 55 TRIP GAS Casing TG = 441u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 50/55 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek 155 PRESENT LITHOLOGY @ 10695': Carbonaceous Shale 10%; Coal 40%; Tuffaceous Claystone 10%; Tuffaceous Siltstone 20%; sandstone 10%; Tuffaceous Sandstone DAILY ACTIVITY SUMMARY Run 5 ½” casing from about 1750’ to 5950’. Reciprocate and circulate to turn mud over (Max Gas = 110u). RIH with 5 ½” casing from 5950’ to 8585’. Reciprocate and circulate to turn mud over (Max Gas = 318u). Make up swell packer. RIH with 5 ½” casing from 8585’ to 10608’. Pick up and make landing. RIH and land out at 10631.58’. Condition and circulate mud (Max Gas = 441u). Pick up and rig up Weatherford equipment. Circulate and condition mud. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2025.00 REPORT BY Paul Webster