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214-070
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: 1/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240116 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 09A 50133204450100 224113 10/26/2024 YELLOWJACKET SCBL BCU 12A 50133205300100 214070 8/21/2024 YELLOWJACKET GPT-PLUG-PERF BRU 233-23T 50283202000000 224088 12/28/2024 AK E-LINE PPROF BRU 233-27 50283100260000 163002 12/31/2024 AK E-LINE PPROF BRU 243-34 50283201240000 208079 12/27/2024 AK E-LINE PPROF GP 03-87 50733204370000 166052 12/25/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/16/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/21/2024 AK E-LINE Perf GP BR-03-87 50733204370000 166052 1/3/2025 AK E-LINE CBL IRU 44-36 50283200890000 193022 1/3/2024 AK E-LINE Depth Determination/Plug IRU 44-36 50283200890000 193022 12/26/2024 AK E-LINE DepthDetermination KU 31-07X 50133204950000 200148 12/3/2024 AK E-LINE Perf MPU B-21 50029215350000 186023 1/4/2025 AK E-LINE PlugSettingRecord MPU H-08B 50029228080200 201047 12/28/2024 AK E-LINE Welltech MRU G-01RD 50733200370100 191139 12/12/2024 AK E-LINE IPROF MRU G-01RD 50733200370100 191139 12/18/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/3/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/19/2024 AK E-LINE Perf PBU 01-37 50029236330000 219073 11/23/2024 HALLIBURTON PPROF PBU 06-05 50029202980000 178020 12/21/2024 HALLIBURTON RBT PBU 06-19B 50029207910200 224095 12/11/2024 HALLIBURTON RBT PBU 11-38A 50029227230100 198216 11/27/2024 HALLIBURTON TEMP PBU 14-31A 50029209890100 224090 11/11/2024 HALLIBURTON RBT PBU L-103 50029231010000 202139 11/25/2024 HALLIBURTON IPROF PBU M-207 50029238070000 224141 12/25/2024 HALLIBURTON RBT PBU P2-55 50029222830000 192082 12/5/2024 HALLIBURTON PPROF PBU S-15 50029211130000 184071 11/18/2024 HALLIBURTON RBT TBU M-25 50733203910000 187086 12/13/2024 AK E-LINE Perf T39958 T39959 T39960 T39961 T39962 T39963 T39964 T39964 T39965 T39966 T39966 T39967 T39968 T39969 T39970 T39970 T39971 T39971 T39972 T39973 T39974 T39975 T39976 T39977 T39978 T39979 T39980 T39981 BCU 12A 50133205300100 214070 8/21/2024 YELLOWJACKET GPT-PLUG-PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.16 13:56:40 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: 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 BCU 12A 50133205300100 214070 8/17/2024 YELLOWJACKET GPT-PERF 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: BCU-12A AOGCC 10-403 324-439 PTD 214-070 Approved 08-05-24 Date:Monday, August 19, 2024 7:17:00 PM Scott, Hilcorp has approval to add the additional perforations listed below. Report on the 10-404 for sundry 324-439. Regards 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: Monday, August 19, 2024 2:32 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: FW: BCU-12A AOGCC 10-403 324-439 PTD 214-070 Approved 08-05-24 Bryan, Over the weekend we set a plug to isolate the Beluga and perforated the Sterling A2 sand per Sundry from 5963’-5969’. The well was not producing prior to these perforations, and it is now making 40 mscfd at 63 psi FTP. There is one more sand in the Sterling formation, ST B6 from 5399-5409 that was not included in the original Sundry we are hoping to get approval to perforate that interval. This will be the last sand in the wellbore that is perforated and if unsuccessful we will plan to prep this well for sidetrack as it has no further utility. We would plan to add the ST B6 and keep the A2 open since it is flowing a little bit of gas and we are hoping the B6 will add incremental rate. Let me know if you have any questions. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Tuesday, August 6, 2024 7:37 AM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: BCU-12A AOGCC 10-403 324-439 PTD 214-070 Approved 08-05-24 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 theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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. 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: N2 Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,800 feet See Schematic feet true vertical 9,578 feet N/A feet Effective Depth measured 5,913 feet 4,209 feet true vertical 5,761 feet 4,149 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / L-80 7,664' MD 7,436' TVD Packers and SSSV (type, measured and true vertical depth) Swell Pkr; N/A 4,209; MD 4,149' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 1,950psi 7,460psi 3,060psi 3,450psi 10,640psi 2,087' 2,087' Burst Collapse 1,500psi Production Liner 4,765' 9,760' Casing Structural 4,673' 9,538' 4,765' 9,760' 103'Conductor Surface Intermediate 20" 13-3/8" 103' 2,087' measured TVD 9-5/8" 5-1/2" X 5" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-070 50-133-20530-00-00 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: FEDA28083 Beaver Creek / Beluga Gas, Sterling Gas Beaver Creek Unit (BCU) 12A 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 0 Size 103' 0 00 0 6538 178 Scott Warner, Operations Engineer 324-439 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 338 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A scott.warner@hilcorp.com 907-564-4506 p k ft t Fra O 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 8:11 am, Sep 13, 2024 Page 1/2 Well Name: BCU-012A Report Printed: 9/11/2024www.peloton.com Alaska Weekly Report - Operations Jobs Actual Start Date:8/9/2024 End Date: Report Number 1 Report Start Date 8/9/2024 Report End Date 8/10/2024 Last 24hr Summary PTW and PJSM w/ YJOS E-Line. MIRU. PT 250/2500 psi per Sundry. RIH w/ 2' and 10 guns. SITP 446 psi. Tag @ 6144' ELM. Perforate 2', 6117' to 6119' to equalize wellbore pressure with BEL_6 sands. Switch gun and perforate 10' BEL_6 sand. 6112' - 6122' . No pressure response. RIH. SITP 447 psi. Perforate 10' BEL_6 sands 6099 6109. Short flow test, ~355 mscf 60 psi. No change from recent production. RIH. SITP 345 psi. Perforate 2' BEL_5 sands 6074 - 6076'. Monitor pressure 5 mins SITP 347 psi. Perforate 10' BEL_5 sands 6070 - 6080'. SITP 421 psi @15 mins. RIH.Tag @ 6114' ELM. Log correlation pass. Confirm on depth. SITP 530 psi. Perforate 10 BEL_5 sands 6047 - 6057'. Final SITP 570 psi. Turn well over to OPS. RIg back for the night. **Perf Guns 2-3/8" GEO Razor 11 gms, 5 spf, 60* Phasing** Report Number 2 Report Start Date 8/10/2024 Report End Date 8/11/2024 Last 24hr Summary PTW and PJSM w/ YJOS E-Line. Standup crane and pick up lubricator. RIH and locate fluid level @ 3680'. POH. Close swab. MIRU Fox N2 pump. PT to 500/5000 psi. SITP 78 psi. Pumped 100,000 SCF @ 1000 scfm. Final pressure 3400 psi. Noted breakover @ 3550 psi and 91,000 scf away. RIH w/ GPT. Tag @ 6119'. Locate fluid level @ 6090'. RIH w/ 2.75" Legacy Big Boy CIBP on multistage setting tool. SITP 2113 psi. Set CIBP @ 6042' ELM. POH. Final SITP 2085 psi. Lay down crane / lubricator for the night. Report Number 3 Report Start Date 8/11/2024 Report End Date 8/12/2024 Last 24hr Summary PTW and PJSM w/ YJOS E-Line. Standup crane and pick up lubricator. SITP 2080 psi (lost 5 psi overnight) Good test on CIBP. RIH. Bled Tbg to 1800 psi. Tag CIBP on depth @ 6042'. SITP 1787 psi. Perforate 10' Upper Beluga 6011 - 6021'. RIH. SITP 1750 psi. Perforate 10' Upper Beluga 5999 - 6009'. Monitor pressure 15 mins. SITP 1723 psi. Switch guns. Shoot 10' upper Beluga 5986 - 5996'. POH. SITP 1711 psi after 15 mins. RD and move to BCU-14B. **Job Complete** **Perf Guns 2-3/8" GEO Razor 11 gms, 5 spf, 60* Phasing** Report Number 4 Report Start Date 8/17/2024 Report End Date 8/18/2024 Last 24hr Summary PTW and PJSM w/ YJOS E-Line and Fox N2 pump. MIRU. T/IA: 70/0 psi. PT 250/4500 psi. RIH locate fluid level @ 3805'. Depress fluid to 5990' w/ 107,000 scf N2. Final Tbg pressure 4500 psi. POH and RD Fox. MU and RIH w/ 2.75" OD Legacy CIBP. Set @ 5981' ELM. POH and bled Tbg from 3150 to 2000 psi. MU and RIH w/ 6' x 2-3/8" gun. SITP 1995 psi. Perforate the ST_A2 sand from 5963-5969. POH. SITP 1977 psi. RD YJ. Job complete. **Perf Guns 2-3/8" GEO Razor 11 gms, 5 spf, 60* Phasing** Report Number 5 Report Start Date 8/21/2024 Report End Date 8/21/2024 Last 24hr Summary PTW and PJSM w/ YJOS E-Line. PT 250/3500 PSI. Good. RIH w/ 2-3/8" x 10' gun. Wt. drop at 1480' indicates possible FL. POOH. RIH w/ GPT. Find FL at 1420'. SDFN. Plan forward: Will require 35' cement on top of existing 5981' CIBP - Set new CIBP at 5913' - Swab FL - Return to perforate. Report Number 6 Report Start Date 8/22/2024 Report End Date 8/23/2024 Last 24hr Summary PTW and PJSM w/ YJOS E-Line. TIO 152/0/100. Made 2 runs w/ 2-1/2" x 30' dump bailer to place 35' of cement on existing CIBP at 5981'. TOC at 5946'. Set CIBP at 5913' to isolate ST A2 perfs at 5963'. Plan forward: PW to swab FL down to be able to perf Sterling B6 zone at 5399' to 5409'. Report Number 7 Report Start Date 8/23/2024 Report End Date 8/23/2024 Last 24hr Summary Start Rig up , Find bad wire- Strip until Getting into Good wire, Plan Change to Move to BC-19 for Hydrate Issues Report Number 8 Report Start Date 8/24/2024 Report End Date 8/24/2024 Last 24hr Summary Move from BC-19, Drift to Verify no Cement Stringers in Hole , Swab out about 12.6 BBLS of Fluid Report Number 9 Report Start Date 8/25/2024 Report End Date 8/25/2024 Last 24hr Summary Swab out an additional 26.5 BBLs of Fluid - Making Both days Total 39BBLS Tag Fluid below Target depth at 5605' RKB (target was 5450') Report Number 10 Report Start Date 8/26/2024 Report End Date 8/26/2024 Last 24hr Summary PJSM, Crew travel to location, Spot in & rig, Pick up run #1, Pressure test 250/2500-good, Run in hole, Correlate, Perf ST B6 (5399-5409), Pull out of hole (lost tool string), Secure well, Rig down & release YJ. Report Number 11 Report Start Date 8/27/2024 Report End Date 8/28/2024 Last 24hr Summary PJSM, Crew travel to location, Spot in & rig up, Pick up lube & tool string, Pressure test 250/2500-good, Run in hole run #1 (LIB) tag @ 3904', Pull out of hole & inspect (cable imprints), Pick up Run #2 (tri-point even points), Run in hole & tag @ 3904', Jar & work till shear, Pull out of hole, Re-bait & run Run #3, Tag 3912' & work (fish off), Pull out of hole, Pick up run #4 (tri-point offset), Run in hole & tag 3912', Work till shear, Pull out of hole, Re-bait to shear down, Run in hole with run #5, Tag @ 3912', Work up to 1800 lbs & jar, Gain 350lbs of string weight, Pull out of hole, Secure well, Lay down lube in sections, Recovered 12 +/- ft eline cable, Rig down for the night Field: Beaver Creek Sundry #: 324-439 State: Alaska Rig/Service: YellowJacketPermit to Drill (PTD) #:214-070Permit to Drill (PTD) #:214-070 Wellbore API/UWI:50-133-20530-01-00 Page 2/2 Well Name: BCU-012A Report Printed: 9/11/2024www.peloton.com Alaska Weekly Report - Operations Report Number 12 Report Start Date 8/28/2024 Report End Date 8/29/2024 Last 24hr Summary PJSM, Crew travel to location, Rehead and pick up lube, Make up tool string (lib), Pressure test 250/2500-good, Run in hole to tag @ 3897', Engage, Jar up & shear off, Pull out of hole, Rebait & run in hole to tag & 4518', Pull out of hole with fish, Unable to close valves fish across valves, Run in hole & shear down/off @ 1696', Pull out of hole, PIck up 14' lube (99' total) Drop 5' of tools, Run in hole to engage fish @ 1704', Pull out of hole & secure well, Lay down fish & lube, Recovered 40' +/- line, 30' of eline tools, Pick up 2.82" LIB & run in hole, Fluid @ 3530', Tag @ 5583', Pull out of hole, Rig down & release slickline. Field: Beaver Creek Sundry #: 324-439 State: Alaska Rig/Service: YellowJacket State/Prov:Alaska Country:USA 150.0' 9/10/2024 Well Name & Number:Beaver Creek Unit #12A A - 028083 County or Parish:Kenai Peninsula Borough Lease: 20.3º @ 5,027' Date Completed:7/12/2014 Ground Level (above MSL):RKB (above GL): N/A 17.5' Revised By:Donna Ambruz Schematic Revision Date: 19.2º @ 4,769'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: BCU - 12A Pad 4 2,023 FNL, 482' FEL, Sec. 33, T7N, R10W, S.M. TD: 9,800' MD 9,578' TVD Permit #:214-070 API #:50-133-20530-01 Prop. Des:FED A-028083 KB elevation:167.5' (17.5' AGL) Lat:N60°39' 22.118" Long:W151°1' 45.593" Spud:6/29/2014 12:00 hrs TD:7/07/2014 07:00 hrs Rig Released:7/13/2014 6:00 hrs PBTD: 7,404' MD 7,181' TVD SCHEMATIC 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT 0' - 7,564' MD 0' - 7,348' TVD 5" L-80 18 ppf DWC/C-HT 7,564' - 9,760' MD 7,348' - 9,538' TVD Cmt w/ 248 bbls of 15.3 ppg Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Max Dogleg: 4.42°/100' @ 8,004' Max Inclination: 20.3°@ 5,027' Conductor 20" K-55 133 ppf Top Bottom MD 0' 103' Surface Casing 13-3/8" K-55 68 ppf BTC MD 0' 2,087' TVD 0' 2,087' 16" hole Cmt w/ 600 sks (271 bbl) of 12.0 ppg, Type 1 cmt, 18 sks (8 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 4,765' TVD 0' 4,673' 12-1/4" hole Lead Cmt w/ 833 sks (341 bbls) of 12.5 ppg, Class G, Tail Cmt w/ 327 sks (106 bbls) of 13.5 ppg, Class G, 12 sks (5 bbls) to surface Jewelry 1. Swell Packer (21' Long) 2. CIBP (Set 8/22/24) 3. CIBP w/35' Cement Set 8/22/24) TOC 5,946' 4. CIBP (Set 8/10/24) 5. CIBP w/35' Cement (2/18/23) TOC 6,169' 6. Wireline Retrievable Plug (2/1/23) 7. CIBP w/35' Cement (4/10/22) 8. CIBP (Set 11/18/14) Capped w/ 35' of cmt 9. CIBP (Set 11/02/14) 10. CIBP (Set 8/21/14) 11. CIBP (Set 8/09/14) 12. CIBP (Set 8/02/14) Depth 4,209' 5,3`9' 5,981' 6,042' 6,204' 6,210' 7,439' 7,820' 7,914' 8,125' 8,360' 8,475' 9-5/8 TOC 4375' - (USIT 7/21/14) 7820' CIBP w 35' cmt (11-18-14) 10 9 8 11 12 3-1/2" TOC @ ~3850' (9/29/21 CBL) 7564' 5 1/2" x 5" XO Liner/tubing (ran 9/27/21) 3-1/2" L-80 9.3ppf IBT SCC 0' - 7664' 0' - 7436' TVD Cmt w 250 sx 15.3 ppg cement, 1.23 yield 7764' 3-1/2 diverter sub on btm of tubing 7,439' CIBP w/35' Cement TOC @ 7,404 (04/10/22) 6,169'TOC (2/18/23)5/6 7 4 6,042' CIBP (08/10/24) Perforations: Zone MD TVD Size SPF Date Status ST B3 5,206'-5,211' 5,089'-5,093' 3-1/8" 6 01/07/15 Isolated ST B3L 5,279'-5,299' 5,158'-5,177' 3-1/8" 6 12/09/14 Isolated ST A2 5,963'-5,969' 5,811'-5,817' 3-1/8" 6 08/17/24 Isolated UB 5,986'-5,996' 5,833'-5,843' 3-1/8" 10 08/11/24 Isolated UB 5,999'-6,009' 5,846'-5,855' 3-1/8" 10 08/11/24 Isolated UB 6,011'-6,021' 5,857'-5,866' 3-1/8" 10 08/11/24 Isolated Bel 5 6,047'-6,057' 5,891'-5,901' 3-1/8" 10 08/09/24 Isolated Bel 5 6,070'-6,080' 5,913'-5,922' 3-1/8" 10 08/09/24 Isolated Bel 6 6,099'-6,109' 5,940'-5,950' 3-1/8" 10 08/09/24 Isolated Bel 6 6,112'-6,122' 5,953'-5,962' 2-3/8" 11 08/9/24 Isolated Bel 7 6,134'-6,145' 5,974'-5,984' 2-3/8" 11 04/10/22 Isolated Bel 8 6,176'-6,189 6,013'-6,026' 2-3/8" 13 04/10/22 Isolated Bel 8 6,219'-6,238' 6,054'-6,072' 2-3/8" 19 04/10/22 Isolated Bel 8 6,279'-6,291' 6,111'-6,122' 2-3/8" 12 04/10/22 Isolated Bel 11 6,545'-6,553' 6,365'-6,370' 2-3/8" 8 04/10/22 Isolated Bel 14 7,070'-7,078' 6,861'-6,869' 2-3/8" 8 04/10/22 Isolated Bel 17 7,489'-7,495' 7,264'-7,270' 10/16/21 Isolated Bel 18 7,517'-7,528' 7,291'-7,302' 10/16/21 Isolated Bel 18 7,555'-7,560' 7,329'-7,334' 10/15/21 Isolated Bel 19 7,566'-7,580' 7,340'-7,353' 10/15/21 Isolated Bel 19 7,594'-7,604' 7,367'-7,377' 10/14/21 Isolated Bel LWR 7,705'-7,721' 7,477'-7,493' 10/14/21 Isolated Bel 21 7,732'-7,742' 7,504'-7,514' 10/14/21 Isolated Bel LWR 7,741'-7,753' 7,513'-7,525' 10/13/21 Isolated LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-23 7,929'-7,941' 7,708'-7,720' 2-7/8" 6 09/03/14 Isolated LB-24 8,015'-8,028' 7,794'-7,807' 2-7/8" 6 09/03/14 Isolated LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 09/03/14 Isolated LB-26A 8,107'-8,117' 7,886'-7,896' 2-7/8" 6 09/03/14 Isolated LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 08/20/14 Isolated LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 08/20/14 Isolated LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 08/20/14 Isolated LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 08/04/14 Isolated LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 08/04/14 Isolated LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 08/04/14 Isolated LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 08/04/14 Isolated LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 07/30/14 Isolated LB-30 8,495'-8,510' 8,274'-8,289' 2-7/8" 6 07/30/14 Isolated LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 07/30/14 Isolated LB-31 8,600'-8,610' 8,379'-8,389' 2-7/8" 6 07/30/14 Isolated 35' Cmt - TOC 5,946' 3 5,913' CIBP (08/22/24)2 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): 9,800'N/A Casing Collapse Structural Conductor 1,500psi Surface 1,950psi Intermediate 3,090psi Production 7,460psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writte n approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028083 214-070 50-133-20530-01-00 Hilcorp Alaska, LLC Proposed Pools: 9.3# / L-80 TVD Burst 7,664' 10,640psi 2,087' Size 103' 9-5/8"4,765' 2,087' MD See Schematic 5,750psi 3,060psi 3,450psi 103' 4,673' 103' 2,087' August 7, 2024 3-1/2" 9,760' Perforation Depth MD (ft): 4,765' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beaver Creek Unit (BCU) 12ACO 237D Beluga Gas, Sterling Gas 9,538'5-1/2" X 5" ~2,032psi 9,760' See Schematic Length Swell Pkr and N/A 4,209 MD / 4,149 TVD & NA 9,578'7,704'7,181' Beaver Creek Beluga Gas 20" 13-3/8" See Schematic 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 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.07.30 08:30:59 - 08'00' Noel Nocas (4361) 324-439 By Grace Christianson at 11:09 am, Jul 30, 2024 Perforate DSR-7/31/24SFD 7/30/2024 10-404 BJM 8/5/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.05 15:16:56 -08'00'08/05/24 RBDMS JSB 080624 Well Prognosis Well: BCU-12A Well Name: BCU-12A API Number: 50-133-20530-01-00 Current Status: Producing Gas Well Permit to Drill Number: 214-070 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: 2629 psi @ 5974’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 2032 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.572 psi/ft using 11.0 ppg EMW FIT at the 9-5/8” int. casing shoe Shallowest Allowable Perf TVD: MPSP/(0.572-0.1) = 2032 psi / 0.472 = 4305‘ TVD (Will not perforate above applicable gas pool) Top of Applicable Gas Pool:4966’ MD/ 4861’ TVD (Sterling) 5973’ MD/5821’ TVD (Beluga) Well Status: Online Gas producer flowing at 326 mmscfd, 50 bwpd, 64 psi FTP Brief Well Summary BCU 12A was drilled in 2014 targeting Lower Beluga sands. Multiple Beluga sands were shot from the BEL 22-31 sands finding no commercial gas. In 2015 it was plugged back and completed in the Sterling, to water out one year later. In 2021 a liner was run and cemented to isolate the Beluga sands, and the Beluga 17-21 were tested unsuccessfully. In 2022 the Beluga 14-7 sands were perforated and was productive. The wet zones were plugged back in February of 2023 and a plug was set with cement on top with TOC @ 6,169’. The well has continued to decline since. The purpose of this sundry is to add additional perforations in the Beluga and Sterling sands to increase rate. Notes Regarding Wellbore Condition x Inclination o Max inclination = 20 degrees at 4965’ MD x Recent Tags o 5/20/23: SL tagged plug at 6,169’ w/ 2.5” DD bailer and GR and 2.81” GR to 6174’ Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /2,500 psi high 3. RIH and perforate ST A2 – Bel 6 sands from bottom up with 2-3/8” 60 deg phased perf guns: a. If the Beluga and Sterling formations are commingled, all conditions will be followed in accordance with CO 237D, rule 5 , equivalent to 4,374' MD SFD 't Well Prognosis Well: BCU-12A 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 ST A2 ±5,963' ±5,969' ±5,811' ±5,817' ±6' UBEL ±5,986' ±5,996' ±5,833' ±5,843' ±10' UBEL ±5,999' ±6,009' ±5,846' ±5,855' ±10' UBEL ±6,011' ±6,021' ±5,857' ±5,866' ±10' BEL 5 ±6,047' ±6,057' ±5,891' ±5,901' ±10' BEL 5 ±6,070' ±6,080' ±5,913' ±5,922' ±10' BEL 6 ±6,099' ±6,109' ±5,940' ±5,950' ±10' BEL 6 ±6,112' ±6,122' ±5,953' ±5,962' ±10' a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations i. Note: A CIBP may be used instead of WRP if it is determined that no cement is needed for operational purposes. 35ft will not be placed on each plug as these zones are close together. If possible, the CIBP will be set 50’ above of the top of the last perforated sand unless zones are too close together in which case the plug will be set within 50’. 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 State/Prov:Alaska Country:USA 150.0' 2/23/2023 Well Name & Number:Beaver Creek Unit #12A A - 028083 County or Parish:Kenai Peninsula Borough Lease: 20.3º @ 5,027' Date Completed:7/12/2014 Ground Level (above MSL):RKB (above GL): N/A 17.5' Revised By:D Ambruz Schematic Revision Date: 19.2º @ 4,769'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: BCU - 12A Pad 4 2,023 FNL, 482' FEL, Sec. 33, T7N, R10W, S.M. TD: 9,800' MD 9,578' TVD Permit #:214-070 API #:50-133-20530-01 Prop. Des:FED A-028083 KB elevation:167.5' (17.5' AGL) Lat:N60°39' 22.118" Long:W151°1' 45.593" Spud:6/29/2014 12:00 hrs TD:7/07/2014 07:00 hrs Rig Released:7/13/2014 6:00 hrs PBTD: 7,404' MD 7,181' TVD SCHEMATIC 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT 0' - 7,564' MD 0' - 7,348' TVD 5" L-80 18 ppf DWC/C-HT 7,564' - 9,760' MD 7,348' - 9,538' TVD Cmt w/ 248 bbls of 15.3 ppg Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Max Dogleg: 4.42°/100' @ 8,004' Max Inclination: 20.3°@ 5,027' Conductor 20" K-55 133 ppf Top Bottom MD 0' 103' Surface Casing 13-3/8" K-55 68 ppf BTC MD 0' 2,087' TVD 0' 2,087' 16" hole Cmt w/ 600 sks (271 bbl) of 12.0 ppg, Type 1 cmt, 18 sks (8 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 4,765' TVD 0' 4,673' 12-1/4" hole Lead Cmt w/ 833 sks (341 bbls) of 12.5 ppg, Class G, Tail Cmt w/ 327 sks (106 bbls) of 13.5 ppg, Class G, 12 sks (5 bbls) to surface Jewelry 1. Swell Packer (21' Long) 2. CIBP w/35' Cement (2/18/23) TOC 6,169' 3. Wireline Retrievable Plug (2/1/23) 4. CIBP w/35' Cement (4/10/22) 5. CIBP (Set 11/18/14) Capped w/ 35' of cmt 6. CIBP (Set 11/02/14) 7. CIBP (Set 8/21/14) 8. CIBP (Set 8/09/14) 9. CIBP (Set 8/02/14) Depth 4,209' 6,204' 6,210' 7,439' 7,820' 7,914' 8,125' 8,360' 8,475' 9-5/8 TOC 4375' - (USIT 7/21/14) 7820' CIBP w 35' cmt (11-18-14) 7 6 5 8 9 3-1/2" TOC @ ~3850' (9/29/21 CBL) 7564' 5 1/2" x 5" XO Liner/tubing (ran 9/27/21) 3-1/2" L-80 9.3ppf IBT SCC 0' - 7664' 0' - 7436' TVD Cmt w 250 sx 15.3 ppg cement, 1.23 yield 7764' 3-1/2 diverter sub on btm of tubing Perforations: Zone MD TVD Size SPF Date Status Sterling B3 5,206'-5,211' 5,089'-5,093' 3-1/8" 6 01/07/15 Isolated Sterling B3L 5,279'-5,299' 5,158'-5,177' 3-1/8" 6 12/09/14 Isolated Beluga 7 6,134'-6,145' 5,974'-5,984' 2-3/8" 11 04/10/22 Open Beluga 8 6,176'-6,189 6,013'-6,026' 2-3/8" 13 04/10/22 Isolated Beluga 8 6,219'-6,238' 6,054'-6,072' 2-3/8" 19 04/10/22 Isolated Beluga 8 6,279'-6,291' 6,111'-6,122' 2-3/8" 12 04/10/22 Isolated Beluga 11 6,545'-6,553' 6,365'-6,370' 2-3/8" 8 04/10/22 Isolated Beluga 14 7,070'-7,078' 6,861'-6,869' 2-3/8" 8 04/10/22 Isolated Beluga 17 7,489'-7,495' 7,264'-7,270' 10/16/21 Isolated Beluga 18 7,517'-7,528' 7,291'-7,302' 10/16/21 Isolated Beluga 18 7,555'-7,560' 7,329'-7,334' 10/15/21 Isolated Beluga 19 7,566'-7,580' 7,340'-7,353' 10/15/21 Isolated Beluga 19 7,594'-7,604' 7,367'-7,377' 10/14/21 Isolated Beluga LWR 7,705'-7,721' 7,477'-7,493' 10/14/21 Isolated Beluga 21 7,732'-7,742' 7,504'-7,514' 10/14/21 Isolated Beluga LWR 7,741'-7,753' 7,513'-7,525' 10/13/21 Isolated LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-23 7,929'-7,941' 7,708'-7,720' 2-7/8" 6 09/03/14 Isolated LB-24 8,015'-8,028' 7,794'-7,807' 2-7/8" 6 09/03/14 Isolated LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 09/03/14 Isolated LB-26A 8,107'-8,117' 7,886'-7,896' 2-7/8" 6 09/03/14 Isolated LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 08/20/14 Isolated LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 08/20/14 Isolated LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 08/20/14 Isolated LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 08/04/14 Isolated LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 08/04/14 Isolated LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 08/04/14 Isolated LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 08/04/14 Isolated LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 07/30/14 Isolated LB-30 8,495'-8,510' 8,274'-8,289' 2-7/8" 6 07/30/14 Isolated LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 07/30/14 Isolated LB-31 8,600'-8,610' 8,379'-8,389' 2-7/8" 6 07/30/14 Isolated 7,439' CIBP w/35' Cement TOC @ 7,404 (04/10/22) 6169' TOC 2/18/232/3 4 State/Prov:Alaska Country:USA 150.0' Schematic Revision Date: 19.2º @ 4,769'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: 7/24/2024 Well Name & Number:Beaver Creek Unit #12A A - 028083 County or Parish:Kenai Peninsula Borough Lease: 20.3º @ 5,027' Date Completed:7/12/2014 Ground Level (above MSL):RKB (above GL): N/A 17.5' Revised By:Donna Ambruz BCU - 12A Pad 4 2,023 FNL, 482' FEL, Sec. 33, T7N, R10W, S.M. TD: 9,800' MD 9,578' TVD Permit #:214-070 API #:50-133-20530-01 Prop. Des:FED A-028083 KB elevation:167.5' (17.5' AGL) Lat:N60°39' 22.118" Long:W151°1' 45.593" Spud:6/29/2014 12:00 hrs TD:7/07/2014 07:00 hrs Rig Released:7/13/2014 6:00 hrs PBTD: 7,404' MD 7,181' TVD PROPOSED 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT 0' - 7,564' MD 0' - 7,348' TVD 5" L-80 18 ppf DWC/C-HT 7,564' - 9,760' MD 7,348' - 9,538' TVD Cmt w/ 248 bbls of 15.3 ppg Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Max Dogleg: 4.42°/100' @ 8,004' Max Inclination: 20.3°@ 5,027' Conductor 20" K-55 133 ppf Top Bottom MD 0' 103' Surface Casing 13-3/8" K-55 68 ppf BTC MD 0' 2,087' TVD 0' 2,087' 16" hole Cmt w/ 600 sks (271 bbl) of 12.0 ppg, Type 1 cmt, 18 sks (8 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 4,765' TVD 0' 4,673' 12-1/4" hole Lead Cmt w/ 833 sks (341 bbls) of 12.5 ppg, Class G, Tail Cmt w/ 327 sks (106 bbls) of 13.5 ppg, Class G, 12 sks (5 bbls) to surface Jewelry 1. Swell Packer (21' Long) 2. CIBP w/35' Cement (2/18/23) TOC 6,169' 3. Wireline Retrievable Plug (2/1/23) 4. CIBP w/35' Cement (4/10/22) 5. CIBP (Set 11/18/14) Capped w/ 35' of cmt 6. CIBP (Set 11/02/14) 7. CIBP (Set 8/21/14) 8. CIBP (Set 8/09/14) 9. CIBP (Set 8/02/14) Depth 4,209' 6,204' 6,210' 7,439' 7,820' 7,914' 8,125' 8,360' 8,475' 9-5/8 TOC 4375' - (USIT 7/21/14) 7820' CIBP w 35' cmt (11-18-14) 7 6 5 8 9 3-1/2" TOC @ ~3850' (9/29/21 CBL) 7564' 5 1/2" x 5" XO Liner/tubing (ran 9/27/21) 3-1/2" L-80 9.3ppf IBT SCC 0' - 7664' 0' - 7436' TVD Cmt w 250 sx 15.3 ppg cement, 1.23 yield 7764' 3-1/2 diverter sub on btm of tubing Perforations: Zone MD TVD Size SPF Date Status ST B3 5,206'-5,211' 5,089'-5,093' 3-1/8" 6 01/07/15 Isolated ST B3L 5,279'-5,299' 5,158'-5,177' 3-1/8" 6 12/09/14 Isolated ST A2 ±5,963'-5,969' 5,811'-5,817' 3-1/8" 6 Proposed UB ±5,986'-5,996' 5,833'-5,843' 3-1/8" 10 Proposed UB ±5,999'-6,009' 5,846'-5,855' 3-1/8" 10 Proposed UB ±6,011'-6,021' 5,857'-5,866' 3-1/8" 10 Proposed Bel 5 ±6,047'-6,057' 5,891'-5,901' 3-1/8" 10 Proposed Bel 5 ±6,070'-6,080' 5,913'-5,922' 3-1/8" 10 Proposed Bel 6 ±6,099'-6,109' 5,940'-5,950' 3-1/8" 10 Proposed Bel 6 ±6,112'-6,122' 5,953'-5,962' 2-3/8" 11 Proposed Bel 7 6,134'-6,145' 5,974'-5,984' 2-3/8" 11 04/10/22 Open Bel 8 6,176'-6,189 6,013'-6,026' 2-3/8" 13 04/10/22 Isolated Bel 8 6,219'-6,238' 6,054'-6,072' 2-3/8" 19 04/10/22 Isolated Bel 8 6,279'-6,291' 6,111'-6,122' 2-3/8" 12 04/10/22 Isolated Bel 11 6,545'-6,553' 6,365'-6,370' 2-3/8" 8 04/10/22 Isolated Bel 14 7,070'-7,078' 6,861'-6,869' 2-3/8" 8 04/10/22 Isolated Bel 17 7,489'-7,495' 7,264'-7,270' 10/16/21 Isolated Bel 18 7,517'-7,528' 7,291'-7,302' 10/16/21 Isolated Bel 18 7,555'-7,560' 7,329'-7,334' 10/15/21 Isolated Bel 19 7,566'-7,580' 7,340'-7,353' 10/15/21 Isolated Bel 19 7,594'-7,604' 7,367'-7,377' 10/14/21 Isolated Bel LWR 7,705'-7,721' 7,477'-7,493' 10/14/21 Isolated Bel 21 7,732'-7,742' 7,504'-7,514' 10/14/21 Isolated Bel LWR 7,741'-7,753' 7,513'-7,525' 10/13/21 Isolated LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-23 7,929'-7,941' 7,708'-7,720' 2-7/8" 6 09/03/14 Isolated LB-24 8,015'-8,028' 7,794'-7,807' 2-7/8" 6 09/03/14 Isolated LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 09/03/14 Isolated LB-26A 8,107'-8,117' 7,886'-7,896' 2-7/8" 6 09/03/14 Isolated LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 08/20/14 Isolated LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 08/20/14 Isolated LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 08/20/14 Isolated LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 08/04/14 Isolated LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 08/04/14 Isolated LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 08/04/14 Isolated LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 08/04/14 Isolated LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 07/30/14 Isolated LB-30 8,495'-8,510' 8,274'-8,289' 2-7/8" 6 07/30/14 Isolated LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 07/30/14 Isolated LB-31 8,600'-8,610' 8,379'-8,389' 2-7/8" 6 07/30/14 Isolated 7,439' CIBP w/35' Cement TOC @ 7,404 (04/10/22) 6169' TOC 2/18/232/3 4 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 Re-Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,800'N/A Casing Collapse Structural Conductor 1,500psi Surface 1,950psi Intermediate 3,090psi Production 7,460psi 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Chad Helgeson, Operations Engineer chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: 9.3# / L-80 7,664' June 5, 2023 Swell Pkr and N/A 4,209 MD / 4,149 TVD & NA See Schematic See Schematic 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028083 214-070 50-133-20530-01-00 Beaver Creek Sterling Gas Same CO 237D Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beaver Creek Unit (BCU) 12A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 9,578'7,704'7,181'~2,103psi See Schematic MD 5,750psi 3,060psi 3,450psi 103' 2,087' 4,673' 103' 2,087' 4,765' Perforation Depth MD (ft): 9,760'5-1/2" X 5" 9-5/8"4,765' 20" 13-3/8" 103' 2,087' 10,640psi9,538'9,760' m n P s 66 t _ Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-305 By Kayla Junke at 11:42 am, May 24, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.05.24 10:38:53 - 08'00' Noel Nocas (4361) 10-404 DSR-5/24/23SFD 5/27/2023BJM 6/5/23GCW 06/05/2023 JLC 6/5/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.06.05 14:30:56 -08'00' 06/05/23 RBDMS JSB 060623 Well Prognosis Well Name:BCU-12A API Number:50-133-20530-01-00 Current Status:Gas Producer Permit to Drill Number:214-070 First Call Engineer:Chad Helgeson (907) 777-8405 (O)(907) 229-4824 (C) Second Call Engineer:Jake Flora (907) 777-8442 (O)(720) 988-5375 (C) Maximum Expected BHP (Beluga 7):2700 psi @ 5,974’ TVD (Based on 0.452 psi/ft gradient) Max. Potential Surface Pressure:2103 psi @ 5,974’TVD (Based on 0.1 psi/ft gas gradient to surface) Brief Well Summary: BCU 12A was drilled in 2014 targeting Lower Beluga sands. Multiple Beluga sands were shot from the BEL 22-31 sands finding no commercial gas. In 2015 it was plugged back and completed in the Sterling, to water out one year later. In 2021 a liner was run and cemented to isolate the Beluga sands, and the Beluga 17-21 were tested unsuccessfully. In 2022 the Beluga 14-7 sands were perforated and the Sterling was productive. The wet zones were plugged back in 2023 and a plug was set with cement on top with TOC @ 6,169’. The wells decline rate has drastically changed for the worse. The objective of this sundry is to reperf existing open Upper Beluga 7 sands. Wellbore Conditions: 5/20/23 – SL tagged plug at 6,169’ w/ 2.5” DD bailer and GR Current Flow rate – 1.3 mmscfd @ 338 psi Procedure: 1. MIRU E-line and pressure control equipment. PT lubricator to 250psi low / 2,500 psi High 2. PU and RIH with 2” HC gun 3. Perforate following sand Sand Perforation Top (MD) Perforation Bottom (MD) Perforation Top (TVD) Perforation Bottom (TVD) Total Footage (MD) Beluga 7 ±6,134’±6,145’±5,974’±5,984’±11 a. Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. b. Record initial and 5/10/15 minute tubing pressures after firing 4. RD E-Line Unit and turn well over to production 5. Operations to flow well Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic State/Prov:Alaska Country:USA 150.0' 2/23/2023 Well Name & Number:Beaver Creek Unit #12A A - 028083 County or Parish:Kenai Peninsula Borough Lease: 20.3º @ 5,027' Date Completed:7/12/2014 Ground Level (above MSL):RKB (above GL): N/A 17.5' Revised By:D Ambruz Schematic Revision Date: 19.2º @ 4,769'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: BCU - 12A Pad 4 2,023 FNL, 482' FEL, Sec. 33, T7N, R10W, S.M. TD: 9,800' MD 9,578' TVD Permit #:214-070 API #:50-133-20530-01 Prop. Des:FED A-028083 KB elevation:167.5' (17.5' AGL) Lat:N60°39' 22.118" Long:W151°1' 45.593" Spud:6/29/2014 12:00 hrs TD:7/07/2014 07:00 hrs Rig Released:7/13/2014 6:00 hrs PBTD: 7,404' MD 7,181' TVD SCHEMATIC 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT 0' - 7,564' MD 0' - 7,348' TVD 5" L-80 18 ppf DWC/C-HT 7,564' - 9,760' MD 7,348' - 9,538' TVD Cmt w/ 248 bbls of 15.3 ppg Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Max Dogleg: 4.42°/100' @ 8,004' Max Inclination: 20.3°@ 5,027' Conductor 20" K-55 133 ppf Top Bottom MD 0' 103' Surface Casing 13-3/8" K-55 68 ppf BTC MD 0' 2,087' TVD 0' 2,087' 16" hole Cmt w/ 600 sks (271 bbl) of 12.0 ppg, Type 1 cmt, 18 sks (8 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 4,765' TVD 0' 4,673' 12-1/4" hole Lead Cmt w/ 833 sks (341 bbls) of 12.5 ppg, Class G, Tail Cmt w/ 327 sks (106 bbls) of 13.5 ppg, Class G, 12 sks (5 bbls) to surface Jewelry 1. Swell Packer (21' Long) 2. CIBP w/35' Cement (2/18/23) TOC 6,169' 3. Wireline Retrievable Plug (2/1/23) 4. CIBP w/35' Cement (4/10/22) 5. CIBP (Set 11/18/14) Capped w/ 35' of cmt 6. CIBP (Set 11/02/14) 7. CIBP (Set 8/21/14) 8. CIBP (Set 8/09/14) 9. CIBP (Set 8/02/14) Depth 4,209' 6,204' 6,210' 7,439' 7,820' 7,914' 8,125' 8,360' 8,475' 9-5/8 TOC 4375' - (USIT 7/21/14) 7820' CIBP w 35' cmt (11-18-14) 7 6 5 8 9 3-1/2" TOC @ ~3850' (9/29/21 CBL) 7564' 5 1/2" x 5" XO Liner/tubing (ran 9/27/21) 3-1/2" L-80 9.3ppf IBT SCC 0' - 7664' 0' - 7436' TVD Cmt w 250 sx 15.3 ppg cement, 1.23 yield 7764' 3-1/2 diverter sub on btm of tubing Perforations: Zone MD TVD Size SPF Date Status Sterling B3 5,206'-5,211' 5,089'-5,093' 3-1/8" 6 01/07/15 Isolated Sterling B3L 5,279'-5,299' 5,158'-5,177' 3-1/8" 6 12/09/14 Isolated Beluga 7 6,134'-6,145' 5,974'-5,984' 2-3/8" 11 04/10/22 Open Beluga 8 6,176'-6,189 6,013'-6,026' 2-3/8" 13 04/10/22 Isolated Beluga 8 6,219'-6,238' 6,054'-6,072' 2-3/8" 19 04/10/22 Isolated Beluga 8 6,279'-6,291' 6,111'-6,122' 2-3/8" 12 04/10/22 Isolated Beluga 11 6,545'-6,553' 6,365'-6,370' 2-3/8" 8 04/10/22 Isolated Beluga 14 7,070'-7,078' 6,861'-6,869' 2-3/8" 8 04/10/22 Isolated Beluga 17 7,489'-7,495' 7,264'-7,270' 10/16/21 Isolated Beluga 18 7,517'-7,528' 7,291'-7,302' 10/16/21 Isolated Beluga 18 7,555'-7,560' 7,329'-7,334' 10/15/21 Isolated Beluga 19 7,566'-7,580' 7,340'-7,353' 10/15/21 Isolated Beluga 19 7,594'-7,604' 7,367'-7,377' 10/14/21 Isolated Beluga LWR 7,705'-7,721' 7,477'-7,493' 10/14/21 Isolated Beluga 21 7,732'-7,742' 7,504'-7,514' 10/14/21 Isolated Beluga LWR 7,741'-7,753' 7,513'-7,525' 10/13/21 Isolated LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-23 7,929'-7,941' 7,708'-7,720' 2-7/8" 6 09/03/14 Isolated LB-24 8,015'-8,028' 7,794'-7,807' 2-7/8" 6 09/03/14 Isolated LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 09/03/14 Isolated LB-26A 8,107'-8,117' 7,886'-7,896' 2-7/8" 6 09/03/14 Isolated LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 08/20/14 Isolated LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 08/20/14 Isolated LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 08/20/14 Isolated LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 08/04/14 Isolated LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 08/04/14 Isolated LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 08/04/14 Isolated LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 08/04/14 Isolated LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 07/30/14 Isolated LB-30 8,495'-8,510' 8,274'-8,289' 2-7/8" 6 07/30/14 Isolated LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 07/30/14 Isolated LB-31 8,600'-8,610' 8,379'-8,389' 2-7/8" 6 07/30/14 Isolated 7,439' CIBP w/35' Cement TOC @ 7,404 (04/10/22) 6169' TOC 2/18/232/3 4 State/Prov:Alaska Country:USA 150.0' 5/22/2023 Well Name & Number:Beaver Creek Unit #12A A - 028083 County or Parish:Kenai Peninsula Borough Lease: 20.3º @ 5,027' Date Completed:7/12/2014 Ground Level (above MSL):RKB (above GL): N/A 17.5' Revised By:C Helgeson Schematic Revision Date: 19.2º @ 4,769'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: BCU - 12A Pad 4 2,023 FNL, 482' FEL, Sec. 33, T7N, R10W, S.M. TD: 9,800' MD 9,578' TVD Permit #:214-070 API #:50-133-20530-01 Prop. Des:FED A-028083 KB elevation:167.5' (17.5' AGL) Lat:N60°39' 22.118" Long:W151°1' 45.593" Spud:6/29/2014 12:00 hrs TD:7/07/2014 07:00 hrs Rig Released:7/13/2014 6:00 hrs PBTD: 7,404' MD 7,181' TVD PROPOSED 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT 0' - 7,564' MD 0' - 7,348' TVD 5" L-80 18 ppf DWC/C-HT 7,564' - 9,760' MD 7,348' - 9,538' TVD Cmt w/ 248 bbls of 15.3 ppg Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Max Dogleg: 4.42°/100' @ 8,004' Max Inclination: 20.3°@ 5,027' Conductor 20" K-55 133 ppf Top Bottom MD 0' 103' Surface Casing 13-3/8" K-55 68 ppf BTC MD 0' 2,087' TVD 0' 2,087' 16" hole Cmt w/ 600 sks (271 bbl) of 12.0 ppg, Type 1 cmt, 18 sks (8 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 4,765' TVD 0' 4,673' 12-1/4" hole Lead Cmt w/ 833 sks (341 bbls) of 12.5 ppg, Class G, Tail Cmt w/ 327 sks (106 bbls) of 13.5 ppg, Class G, 12 sks (5 bbls) to surface Jewelry 1. Swell Packer (21' Long) 2. CIBP w/35' Cement (2/18/23) TOC 6,169' 3. Wireline Retrievable Plug (2/1/23) 4. CIBP w/35' Cement (4/10/22) 5. CIBP (Set 11/18/14) Capped w/ 35' of cmt 6. CIBP (Set 11/02/14) 7. CIBP (Set 8/21/14) 8. CIBP (Set 8/09/14) 9. CIBP (Set 8/02/14) Depth 4,209' 6,204' 6,210' 7,439' 7,820' 7,914' 8,125' 8,360' 8,475' 9-5/8 TOC 4375' - (USIT 7/21/14) 7820' CIBP w 35' cmt (11-18-14) 7 6 5 8 9 3-1/2" TOC @ ~3850' (9/29/21 CBL) 7564' 5 1/2" x 5" XO Liner/tubing (ran 9/27/21) 3-1/2" L-80 9.3ppf IBT SCC 0' - 7664' 0' - 7436' TVD Cmt w 250 sx 15.3 ppg cement, 1.23 yield 7764' 3-1/2 diverter sub on btm of tubing Perforations: Zone MD TVD Size SPF Date Status Sterling B3 5,206'-5,211' 5,089'-5,093' 3-1/8" 6 01/07/15 Isolated Sterling B3L 5,279'-5,299' 5,158'-5,177' 3-1/8" 6 12/09/14 Isolated Beluga 7 6,134'-6,145' 5,974'-5,984' 2-3/8" 11 Proposed Beluga 7 6,134'-6,145' 5,974'-5,984' 2-3/8" 11 04/10/22 Open Beluga 8 6,176'-6,189 6,013'-6,026' 2-3/8" 13 04/10/22 Isolated Beluga 8 6,219'-6,238' 6,054'-6,072' 2-3/8" 19 04/10/22 Isolated Beluga 8 6,279'-6,291' 6,111'-6,122' 2-3/8" 12 04/10/22 Isolated Beluga 11 6,545'-6,553' 6,365'-6,370' 2-3/8" 8 04/10/22 Isolated Beluga 14 7,070'-7,078' 6,861'-6,869' 2-3/8" 8 04/10/22 Isolated Beluga 17 7,489'-7,495' 7,264'-7,270' 10/16/21 Isolated Beluga 18 7,517'-7,528' 7,291'-7,302' 10/16/21 Isolated Beluga 18 7,555'-7,560' 7,329'-7,334' 10/15/21 Isolated Beluga 19 7,566'-7,580' 7,340'-7,353' 10/15/21 Isolated Beluga 19 7,594'-7,604' 7,367'-7,377' 10/14/21 Isolated Beluga LWR 7,705'-7,721' 7,477'-7,493' 10/14/21 Isolated Beluga 21 7,732'-7,742' 7,504'-7,514' 10/14/21 Isolated Beluga LWR 7,741'-7,753' 7,513'-7,525' 10/13/21 Isolated LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-23 7,929'-7,941' 7,708'-7,720' 2-7/8" 6 09/03/14 Isolated LB-24 8,015'-8,028' 7,794'-7,807' 2-7/8" 6 09/03/14 Isolated LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 09/03/14 Isolated LB-26A 8,107'-8,117' 7,886'-7,896' 2-7/8" 6 09/03/14 Isolated LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 08/20/14 Isolated LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 08/20/14 Isolated LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 08/20/14 Isolated LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 08/04/14 Isolated LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 08/04/14 Isolated LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 08/04/14 Isolated LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 08/04/14 Isolated LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 07/30/14 Isolated LB-30 8,495'-8,510' 8,274'-8,289' 2-7/8" 6 07/30/14 Isolated LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 07/30/14 Isolated LB-31 8,600'-8,610' 8,379'-8,389' 2-7/8" 6 07/30/14 Isolated 7,439' CIBP w/35' Cement TOC @ 7,404 (04/10/22) 6169' TOC 2/18/232/3 4 Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 03/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230328 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 2/18/2023 YELLOW JACKET PLUG BCU 18RD 50133205840100 222033 3/9/2023 YELLOW JACKET PERF CLU 10RD 50133205530100 222113 3/2/2023 YELLOW JACKET PERF-GPT-PLUG KBU 11-07 50133205560000 205165 3/3/2023 YELLOW JACKET PERF KBU 11-07 50133205560000 205165 3/1/2023 YELLOW JACKET PLUG KU 14X-6 50133203420000 181092 3/3/2023 YELLOW JACKET CALIPER-SCBL NCI B-02 50883200900100 197210 3/9/2023 AK E-LINE GPT Perf SRU 224-10 50133101380100 222124 2/15/2023 YELLOW JACKET PLUG TBU D-09RD 50733201310100 181080 2/27/2023 AK E-LINE Plug Punch Please include current contact information if different from above. BCU 12A 50133205300100 214070 2/18/2023 YELLOW JACKET PLUG 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 9,800 feet See Schematic feet true vertical 9,578 feet N/A feet Effective Depth measured 7,704 feet 4,209 feet true vertical 7,181 feet 4,149 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / L-80 7,664' MD 7,436' TVD Packers and SSSV (type, measured and true vertical depth) Swell Pkr; N/A 4,209; MD 4,149' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 1,950psi 7,460psi 3,060psi 3,450psi 10,640psi 2,087' 2,087' Burst Collapse 1,500psi Production Liner 4,765' 9,760' Casing Structural 4,673' 9,538' 4,765' 9,760' 103'Conductor Surface Intermediate 20" 13-3/8" 103' 2,087' measured TVD 9-5/8" 5-1/2" X 5" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-070 50-133-20530-00-00 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: FEDA28083 Beaver Creek / Sterling Gas Beaver Creek Unit (BCU) 12A 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 0 Size 103' 8 03336 0 340137 332 Chad Helgeson, Operations Engineer 323-071 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 2526 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 chelgeson@hilcorp.com 907-777-8405 N/A 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 Samantha Carlisle at 8:15 am, Feb 24, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2023.02.24 07:50:47 -09'00' Noel Nocas (4361) Rig Start Date End Date E-Line 2/18/23 2/18/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-12A 50-133-20530-01-00 214-070 02/18/2023 - Saturday Yellow Jacket E-line arrive on location. Hold TBT and approve PTW. Have snow cleared from around well. MIRU equipment. Stab wireline valves on tree and MU lubricator with 3.5" CIBP toolstring. PT lubricator to 250 psi low / 2500 psi high. Shut-in well and RIH. Correlate to Bel 8 perf log dated 10 April 2022. Tag WRP at 6206.5'. Set top of CIBP at 6204'. Dump bail 35' of cement (12.8 gallons) on top of CIBP. 2 runs with 2.5" x 30' cement bailer. TOC = 6169'. RDMO. Hand well back over to Operations to BOL. State/Prov:Alaska Country:USA 150.0' 2/23/2023 Well Name & Number:Beaver Creek Unit #12A A - 028083 County or Parish:Kenai Peninsula Borough Lease: 20.3º @ 5,027' Date Completed:7/12/2014 Ground Level (above MSL):RKB (above GL): N/A 17.5' Revised By:D Ambruz Schematic Revision Date: 19.2º @ 4,769'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: BCU - 12A Pad 4 2,023 FNL, 482' FEL, Sec. 33, T7N, R10W, S.M. TD: 9,800' MD 9,578' TVD Permit #:214-070 API #:50-133-20530-01 Prop. Des:FED A-028083 KB elevation:167.5' (17.5' AGL) Lat:N60°39' 22.118" Long:W151°1' 45.593" Spud:6/29/2014 12:00 hrs TD:7/07/2014 07:00 hrs Rig Released:7/13/2014 6:00 hrs PBTD: 7,404' MD 7,181' TVD SCHEMATIC 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT 0' - 7,564' MD 0' - 7,348' TVD 5" L-80 18 ppf DWC/C-HT 7,564' - 9,760' MD 7,348' - 9,538' TVD Cmt w/ 248 bbls of 15.3 ppg Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Max Dogleg: 4.42°/100' @ 8,004' Max Inclination: 20.3°@ 5,027' Conductor 20" K-55 133 ppf Top Bottom MD 0' 103' Surface Casing 13-3/8" K-55 68 ppf BTC MD 0' 2,087' TVD 0' 2,087' 16" hole Cmt w/ 600 sks (271 bbl) of 12.0 ppg, Type 1 cmt, 18 sks (8 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 4,765' TVD 0' 4,673' 12-1/4" hole Lead Cmt w/ 833 sks (341 bbls) of 12.5 ppg, Class G, Tail Cmt w/ 327 sks (106 bbls) of 13.5 ppg, Class G, 12 sks (5 bbls) to surface Jewelry 1. Swell Packer (21' Long) 2. CIBP w/35' Cement (2/18/23) TOC 6,169' 3. Wireline Retrievable Plug (2/1/23) 4. CIBP w/35' Cement (4/10/22) 5. CIBP (Set 11/18/14) Capped w/ 35' of cmt 6. CIBP (Set 11/02/14) 7. CIBP (Set 8/21/14) 8. CIBP (Set 8/09/14) 9. CIBP (Set 8/02/14) Depth 4,209' 6,204' 6,210' 7,439' 7,820' 7,914' 8,125' 8,360' 8,475' 9-5/8 TOC 4375' - (USIT 7/21/14) 7820' CIBP w 35' cmt (11-18-14) 7 6 5 8 9 3-1/2" TOC @ ~3850' (9/29/21 CBL) 7564' 5 1/2" x 5" XO Liner/tubing (ran 9/27/21) 3-1/2" L-80 9.3ppf IBT SCC 0' - 7664' 0' - 7436' TVD Cmt w 250 sx 15.3 ppg cement, 1.23 yield 7764' 3-1/2 diverter sub on btm of tubing Perforations: Zone MD TVD Size SPF Date Status Sterling B3 5,206'-5,211' 5,089'-5,093' 3-1/8" 6 01/07/15 Isolated Sterling B3L 5,279'-5,299' 5,158'-5,177' 3-1/8" 6 12/09/14 Isolated Beluga 7 6,134'-6,145' 5,974'-5,984' 2-3/8" 11 04/10/22 Open Beluga 8 6,176'-6,189 6,013'-6,026' 2-3/8" 13 04/10/22 Isolated Beluga 8 6,219'-6,238' 6,054'-6,072' 2-3/8" 19 04/10/22 Isolated Beluga 8 6,279'-6,291' 6,111'-6,122' 2-3/8" 12 04/10/22 Isolated Beluga 11 6,545'-6,553' 6,365'-6,370' 2-3/8" 8 04/10/22 Isolated Beluga 14 7,070'-7,078' 6,861'-6,869' 2-3/8" 8 04/10/22 Isolated Beluga 17 7,489'-7,495' 7,264'-7,270' 10/16/21 Isolated Beluga 18 7,517'-7,528' 7,291'-7,302' 10/16/21 Isolated Beluga 18 7,555'-7,560' 7,329'-7,334' 10/15/21 Isolated Beluga 19 7,566'-7,580' 7,340'-7,353' 10/15/21 Isolated Beluga 19 7,594'-7,604' 7,367'-7,377' 10/14/21 Isolated Beluga LWR 7,705'-7,721' 7,477'-7,493' 10/14/21 Isolated Beluga 21 7,732'-7,742' 7,504'-7,514' 10/14/21 Isolated Beluga LWR 7,741'-7,753' 7,513'-7,525' 10/13/21 Isolated LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-23 7,929'-7,941' 7,708'-7,720' 2-7/8" 6 09/03/14 Isolated LB-24 8,015'-8,028' 7,794'-7,807' 2-7/8" 6 09/03/14 Isolated LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 09/03/14 Isolated LB-26A 8,107'-8,117' 7,886'-7,896' 2-7/8" 6 09/03/14 Isolated LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 08/20/14 Isolated LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 08/20/14 Isolated LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 08/20/14 Isolated LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 08/04/14 Isolated LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 08/04/14 Isolated LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 08/04/14 Isolated LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 08/04/14 Isolated LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 07/30/14 Isolated LB-30 8,495'-8,510' 8,274'-8,289' 2-7/8" 6 07/30/14 Isolated LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 07/30/14 Isolated LB-31 8,600'-8,610' 8,379'-8,389' 2-7/8" 6 07/30/14 Isolated 7,439' CIBP w/35' Cement TOC @ 7,404 (04/10/22) 6169'TOC 2/18/232/3 4 Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 02/21/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230221 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 1/29/2023 HALLIBURTON PPROF END 1-69 50029220200000 190029 2/4/2023 HALLIBURTON COILFLAG END 1-69 50029220200000 190029 2/11/2023 HALLIBURTON PERF KU 14X-06 50133203420000 181092 1/27/2023 HALLIBURTON TEMP SRU 224-10 50133101380100 222124 2/3/2023 HALLIBURTON PPROF TBU D-09RD 50733201310100 181080 2/8/2023 READ LeakPointSurvey Please include current contact information if different from above. BCU 12A 50133205300100 214070 1/29/2023 HALLIBURTON PPROF Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 02/07/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230207 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPE-17 50029226870000 196115 1/17/2023 YELLOW JACKET LDL CLU 10RD 50133205530100 222113 2/3/2023 YELLOW JACKET GPT-PERF BCU 04RD 50133202390100 219011 1/27/2023 YELLOW JACKET PERF BCU 04RD 50133202390100 219011 2/2/2023 YELLOW JACKET PERF BCU 05RD2 50133202620200 218068 1/26/2023 YELLOW JACKET PERF BCU 12A 50133205300100 214070 2/1/2023 YELLOW JACKET PLUG Please include current contact information if different from above. By Meredith Guhl at 9:51 am, Feb 07, 2023 T37492 T37492 T37493 T37494 T37495 T37496 BCU 12A 50133205300100 214070 2/1/2023 YELLOW JACKET PLUG Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.02.07 10:08:10 -09'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,800'N/A Casing Collapse Structural Conductor 1,500psi Surface 1,950psi Intermediate 3,090psi Production 7,460psi 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 10,640psi9,538'9,760' 103' 2,087' 4,765' Perforation Depth MD (ft): 9,760'5-1/2" X 5" 9-5/8"4,765' 20" 13-3/8" 103' 2,087' 5,750psi 3,060psi 3,450psi 103' 2,087' 4,673' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 9,578'7,704'7,181'~2,418psi See Schematic MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028083 214-070 50-133-20530-01-00 Beaver Creek Sterling Gas NA CO 237D Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beaver Creek Unit (BCU) 12A Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: 9.3# / L-80 7,664' February 17, 2023 Swell Pkr and N/A 4,209 MD / 4,149 TVD & NA See Schematic See Schematic 3-1/2" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Chad Helgeson, Operations Engineer chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 m n P s 66 t _ Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 2:54 pm, Feb 03, 2023 323-071 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2023.02.03 14:49:22 -09'00' Noel Nocas (4361) DLB 02/06/2023 10-404 X DSR-2/3/23BJM 2/12/23GCW 02/13/23 JLC 2/13/2023 2/13/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.13 14:26:09 -09'00' RBDMS JSB 021423 Well Prognosis Well Name: BCU-12A API Number: 50-133-20530-01-00 Current Status: Gas Producer Permit to Drill Number: 214-070 First Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Maximum Expected BHP (Beluga 14): 3104 psi @ 6869’ TVD (Based on 0.452 psi/ft gradient) Max. Potential Surface Pressure: 2418 psi (Based on 0.1 psi/ft gas gradient to surface) Well Status: Flowing at 3.5 mmscfd and 0 bwpd at 345 psi. Brief Well Summary: BCU 12A was drilled in 2014 targeting Lower Beluga sands. Multiple Beluga sands were shot from the BEL 22- 31 sands finding no commercial gas. In 2015 it was plugged back and completed in the Sterling, to water out one year later. In 2021 a liner was run and cemented to isolate the Beluga sands, and the Beluga 17-21 were tested unsuccessfully. In 2022 the Beluga 14-7 sands were perforated and the Sterling was productive. The well was making 250bwpd and starting to impact gas production. A PLT was run indicating water was coming from Beluga 8 sand (6,219-6,238’) which was below the gas productive zone the Beluga 7. A retrievable plug was set at 6210’ to confirm the PLT was correct and isolated the water production. The objective of this sundry is to permanently plug back the Beluga 8-14 sands by adding cement on top of the retrievable plug. Procedure: 1. RU Eline, test lubricator to 2500 psi. 2. Dump bail 35’ cement on top of plug. 3. RD Eline Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic retrievable plug. The objective of this sundry is to permanently plug back the Beluga 8-14 sands by adding cement on top of the DLB State/Prov:Alaska Country:USA 150.0' 2/1/2023 Well Name & Number:Beaver Creek Unit #12A A - 028083 County or Parish:Kenai Peninsula Borough Lease: 20.3º @ 5,027' Date Completed:7/12/2014 Ground Level (above MSL):RKB (above GL): N/A 17.5' Revised By:C Helgeson Schematic Revision Date: 19.2º @ 4,769'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: BCU - 12A Pad 4 2,023 FNL, 482' FEL, Sec. 33, T7N, R10W, S.M. TD: 9,800' MD 9,578' TVD Permit #:214-070 API #:50-133-20530-01 Prop. Des:FED A-028083 KB elevation:167.5' (17.5' AGL) Lat:N60°39' 22.118" Long:W151°1' 45.593" Spud:6/29/2014 12:00 hrs TD:7/07/2014 07:00 hrs Rig Released:7/13/2014 6:00 hrs PBTD: 7,404' MD 7,181' TVD SCHEMATIC 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT 0' - 7,564' MD 0' - 7,348' TVD 5" L-80 18 ppf DWC/C-HT 7,564' - 9,760' MD 7,348' - 9,538' TVD Cmt w/ 248 bbls of 15.3 ppg Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Max Dogleg: 4.42°/100' @ 8,004' Max Inclination: 20.3°@ 5,027' Conductor 20" K-55 133 ppf Top Bottom MD 0' 103' Surface Casing 13-3/8" K-55 68 ppf BTC MD 0' 2,087' TVD 0' 2,087' 16" hole Cmt w/ 600 sks (271 bbl) of 12.0 ppg, Type 1 cmt, 18 sks (8 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 4,765' TVD 0' 4,673' 12-1/4" hole Lead Cmt w/ 833 sks (341 bbls) of 12.5 ppg, Class G, Tail Cmt w/ 327 sks (106 bbls) of 13.5 ppg, Class G, 12 sks (5 bbls) to surface Jewelry 1. Swell Packer (21' Long) 1A. Wireline Retrievable Plug 2. CIBP w/35' Cement (4/10/22) 3. CIBP (Set 11/18/14) Capped w/ 35' of cmt 4. CIBP (Set 11/02/14) 5. CIBP (Set 8/21/14) 6. CIBP (Set 8/09/14) 7. CIBP (Set 8/02/14) Depth 4,209' 6,210' 7,439' 7,820' 7,914' 8,125' 8,360' 8,475' 9-5/8 TOC 4375' - (USIT 7/21/14) 7820' CIBP w 35' cmt (11-18-14) 4 3 2 5 6 3-1/2" TOC @ ~3850' (9/29/21 CBL) 7564' 5 1/2" x 5" XO Liner/tubing (ran 9/27/21) 3-1/2" L-80 9.3ppf IBT SCC 0' - 7664' 0' - 7436' TVD Cmt w 250 sx 15.3 ppg cement, 1.23 yield 7764' 3-1/2 diverter sub on btm of tubing Perforations: Zone MD TVD Size SPF Date Status Sterling B3 5,206'-5,211' 5,089'-5,093' 3-1/8" 6 01/07/15 Isolated Sterling B3L 5,279'-5,299' 5,158'-5,177' 3-1/8" 6 12/09/14 Isolated Beluga 7 6,134'-6,145' 5,974'-5,984' 2-3/8" 11 04/10/22 Open Beluga 8 6,176'-6,189 6,013'-6,026' 2-3/8" 13 04/10/22 Open Beluga 8 6,219'-6,238' 6,054'-6,072' 2-3/8" 19 04/10/22 Open Beluga 8 6,279'-6,291' 6,111'-6,122' 2-3/8" 12 04/10/22 Open Beluga 11 6,545'-6,553' 6,365'-6,370' 2-3/8" 8 04/10/22 Open Beluga 14 7,070'-7,078' 6,861'-6,869' 2-3/8" 8 04/10/22 Open Beluga 17 7,489'-7,495' 7,264'-7,270' 10/16/21 Isolated Beluga 18 7,517'-7,528' 7,291'-7,302' 10/16/21 Isolated Beluga 18 7,555'-7,560' 7,329'-7,334' 10/15/21 Isolated Beluga 19 7,566'-7,580' 7,340'-7,353' 10/15/21 Isolated Beluga 19 7,594'-7,604' 7,367'-7,377' 10/14/21 Isolated Beluga LWR 7,705'-7,721' 7,477'-7,493' 10/14/21 Isolated Beluga 21 7,732'-7,742' 7,504'-7,514' 10/14/21 Isolated Beluga LWR 7,741'-7,753' 7,513'-7,525' 10/13/21 Isolated LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-23 7,929'-7,941' 7,708'-7,720' 2-7/8" 6 09/03/14 Isolated LB-24 8,015'-8,028' 7,794'-7,807' 2-7/8" 6 09/03/14 Isolated LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 09/03/14 Isolated LB-26A 8,107'-8,117' 7,886'-7,896' 2-7/8" 6 09/03/14 Isolated LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 08/20/14 Isolated LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 08/20/14 Isolated LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 08/20/14 Isolated LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 08/04/14 Isolated LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 08/04/14 Isolated LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 08/04/14 Isolated LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 08/04/14 Isolated LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 07/30/14 Isolated LB-30 8,495'-8,510' 8,274'-8,289' 2-7/8" 6 07/30/14 Isolated LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 07/30/14 Isolated LB-31 8,600'-8,610' 8,379'-8,389' 2-7/8" 6 07/30/14 Isolated 7,439' CIBP w/35' Cement TOC @ 7,404 (04/10/22) 6,210' WRP 02/1/23)1A State/Prov:Alaska Country:USA 150.0' 2/1/2023 Well Name & Number:Beaver Creek Unit #12A A - 028083 County or Parish:Kenai Peninsula Borough Lease: 20.3º @ 5,027' Date Completed:7/12/2014 Ground Level (above MSL):RKB (above GL): N/A 17.5' Revised By:C Helgeson Schematic Revision Date: 19.2º @ 4,769'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: BCU - 12A Pad 4 2,023 FNL, 482' FEL, Sec. 33, T7N, R10W, S.M. TD: 9,800' MD 9,578' TVD Permit #:214-070 API #:50-133-20530-01 Prop. Des:FED A-028083 KB elevation:167.5' (17.5' AGL) Lat:N60°39' 22.118" Long:W151°1' 45.593" Spud:6/29/2014 12:00 hrs TD:7/07/2014 07:00 hrs Rig Released:7/13/2014 6:00 hrs PBTD: 7,404' MD 7,181' TVD PROPOSED SCHEMATIC 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT 0' - 7,564' MD 0' - 7,348' TVD 5" L-80 18 ppf DWC/C-HT 7,564' - 9,760' MD 7,348' - 9,538' TVD Cmt w/ 248 bbls of 15.3 ppg Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Max Dogleg: 4.42°/100' @ 8,004' Max Inclination: 20.3°@ 5,027' Conductor 20" K-55 133 ppf Top Bottom MD 0' 103' Surface Casing 13-3/8" K-55 68 ppf BTC MD 0' 2,087' TVD 0' 2,087' 16" hole Cmt w/ 600 sks (271 bbl) of 12.0 ppg, Type 1 cmt, 18 sks (8 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 4,765' TVD 0' 4,673' 12-1/4" hole Lead Cmt w/ 833 sks (341 bbls) of 12.5 ppg, Class G, Tail Cmt w/ 327 sks (106 bbls) of 13.5 ppg, Class G, 12 sks (5 bbls) to surface Jewelry 1. Swell Packer (21' Long) 1A. Wireline Retrievable Plug 2. CIBP w/35' Cement (4/10/22) 3. CIBP (Set 11/18/14) Capped w/ 35' of cmt 4. CIBP (Set 11/02/14) 5. CIBP (Set 8/21/14) 6. CIBP (Set 8/09/14) 7. CIBP (Set 8/02/14) Depth 4,209' 6,210' 7,439' 7,820' 7,914' 8,125' 8,360' 8,475' 9-5/8 TOC 4375' - (USIT 7/21/14) 7820' CIBP w 35' cmt (11-18-14) 4 3 2 5 6 3-1/2" TOC @ ~3850' (9/29/21 CBL) 7564' 5 1/2" x 5" XO Liner/tubing (ran 9/27/21) 3-1/2" L-80 9.3ppf IBT SCC 0' - 7664' 0' - 7436' TVD Cmt w 250 sx 15.3 ppg cement, 1.23 yield 7764' 3-1/2 diverter sub on btm of tubing Perforations: Zone MD TVD Size SPF Date Status Sterling B3 5,206'-5,211' 5,089'-5,093' 3-1/8" 6 01/07/15 Isolated Sterling B3L 5,279'-5,299' 5,158'-5,177' 3-1/8" 6 12/09/14 Isolated Beluga 7 6,134'-6,145' 5,974'-5,984' 2-3/8" 11 04/10/22 Open Beluga 8 6,176'-6,189 6,013'-6,026' 2-3/8" 13 04/10/22 Open Beluga 8 6,219'-6,238' 6,054'-6,072' 2-3/8" 19 04/10/22 Open Beluga 8 6,279'-6,291' 6,111'-6,122' 2-3/8" 12 04/10/22 Open Beluga 11 6,545'-6,553' 6,365'-6,370' 2-3/8" 8 04/10/22 Open Beluga 14 7,070'-7,078' 6,861'-6,869' 2-3/8" 8 04/10/22 Open Beluga 17 7,489'-7,495' 7,264'-7,270' 10/16/21 Isolated Beluga 18 7,517'-7,528' 7,291'-7,302' 10/16/21 Isolated Beluga 18 7,555'-7,560' 7,329'-7,334' 10/15/21 Isolated Beluga 19 7,566'-7,580' 7,340'-7,353' 10/15/21 Isolated Beluga 19 7,594'-7,604' 7,367'-7,377' 10/14/21 Isolated Beluga LWR 7,705'-7,721' 7,477'-7,493' 10/14/21 Isolated Beluga 21 7,732'-7,742' 7,504'-7,514' 10/14/21 Isolated Beluga LWR 7,741'-7,753' 7,513'-7,525' 10/13/21 Isolated LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-23 7,929'-7,941' 7,708'-7,720' 2-7/8" 6 09/03/14 Isolated LB-24 8,015'-8,028' 7,794'-7,807' 2-7/8" 6 09/03/14 Isolated LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 09/03/14 Isolated LB-26A 8,107'-8,117' 7,886'-7,896' 2-7/8" 6 09/03/14 Isolated LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 08/20/14 Isolated LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 08/20/14 Isolated LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 08/20/14 Isolated LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 08/04/14 Isolated LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 08/04/14 Isolated LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 08/04/14 Isolated LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 08/04/14 Isolated LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 07/30/14 Isolated LB-30 8,495'-8,510' 8,274'-8,289' 2-7/8" 6 07/30/14 Isolated LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 07/30/14 Isolated LB-31 8,600'-8,610' 8,379'-8,389' 2-7/8" 6 07/30/14 Isolated 7,439' CIBP w/35' Cement TOC @ 7,404 (04/10/22) 6,210' WRP 02/1/23) with 35' of cement 1A David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/3/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221003 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 501332053001 214070 8/10/2022 Halliburton CH PPROF BRU 222-34 502832018600 222039 9/15/2022 Halliburton CH RBT BRU 244-27 502832018500 222038 9/13/2022 Halliburton CH RBT END 1-45 500292199100 189124 8/11/2022 Halliburton CH PERF KBU 22-06Y 501332065000 215044 8/22/2022 Halliburton CH PPROF KBU 43-07Y 501332062500 214019 9/7/2022 Halliburton CH PPROF MPU C-24A 500292302001 209134 8/3/2022 Halliburton CH COILFLAG MPU L-46 500292355100 215118 9/10/2022 Halliburton CH MFC24 MPU S-34 500292317100 203130 9/3/2022 Halliburton CH MFC24 NS-10 500292298500 200182 8/18/2022 Halliburton CH WFL- TMD3D NS-32 500292317900 203158 8/17/2022 Halliburton CH WFL- TMD3D PBU 04-30 500292134500 185089 9/17/2022 Halliburton CH RMT3D PBU 05-24A 500292220401 204218 9/12/2022 Halliburton CH CAST PBU 11-16 500292158100 186078 9/10/2022 Halliburton CH PPROF PBU 11-27A 500292163801 222036 8/20/2022 Halliburton CH RBT PBU C-24B 500292081602 212063 8/16/2022 Halliburton CH PPROF PBU E-100A 500292281901 218157 9/20/2022 Halliburton CH LDL PBU S-106 500292299900 201012 9/12/2022 Halliburton CH RBT Please include current contact information if different from above. T37103 T37104 T37105 T37106 T37107 T37108 T37109 T37110 T37111 T37112 T37113 T37114 T37115 T37116 T37117 T37118 T37119 T37120 BCU 12A 501332053001 214070 8/10/2022 Halliburton CH PPROF Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.05 11:39:32 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 5/10/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 12A (PTD 214-070) Plug/Perf/GPT 4/09/2022 Please include current contact information if different from above. 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KŶĐĞLJŽƵŚĂǀĞĐŽŶĨŝƌŵĞĚůŝŶĞƐĂƌĞďůĞĚĚŽǁŶ͕ŶŽƚƌĂƉƉĞĚƉƌĞƐƐƵƌĞĞdžŝƐƚƐ͕ĂŶĚŶŽŶŝƚƌŽŐĞŶŚĂƐ ĂĐĐƵŵƵůĂƚĞĚďĞŐŝŶƌŝŐĚŽǁŶŽĨůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϳ͘Ϳ &ŝŶĂůŝnjĞũŽďůŽŐĂŶĚĚŝƐĐƵƐƐŽƉĞƌĂƚŝŽŶƐǁŝƚŚtĞůůƐŝƚĞDĂŶĂŐĞƌ͘ŽĐƵŵĞŶƚĂŶLJůĞƐƐŽŶƐůĞĂƌŶĞĚ ĂŶĚĐŽŶĨŝƌŵĨŝŶĂůƌĂƚĞƐͬƉƌĞƐƐƵƌĞͬǀŽůƵŵĞƐŽĨƚŚĞũŽďĂŶĚƌĞŵĂŝŶŝŶŐŶŝƚƌŽŐĞŶŝŶƚŚĞƚƌĂŶƐƉŽƌƚ͘ ϭϴ͘Ϳ ZDKEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/02/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 12A (PTD 214-070) Cement Bond Log 09/29/2021 Please include current contact information if different from above. 37' (6HW Received By: 12/09/2021 By Abby Bell at 4:29 pm, Dec 08, 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 Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,800 feet See schematic feet true vertical 9,578 feet N/A feet Effective Depth measured 7,764 feet 4,209 feet true vertical 7,436 feet 4,149 feet Perforation depth Measured depth 7,489 - 7,753 feet True Vertical depth 7,264 - 7,525 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 7,664 MD 7,436 TVD 4,209 MD Packers and SSSV (type, measured and true vertical depth)Swell Pkr 4,149 TVD SSSV: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Authorized Title:Contact Phone: 321-449 & 321-513 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 819 Jake Flora jake.flora@hilcorp.com (907) 777-8442Dan Marlowe - Operations Manager measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0400 0 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 103' 2,087' N/A 150 Structural TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-070 50-133-20530-01-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: A028083 Beaver Creek Field / Beluga Gas Pool 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Beaver Creek 12A Hilcorp Alaska, LLC Other: Cmt Liner / Coil Milling / N2 Operations measuredPlugs Junk measured N/A Length 103' 2,087' Size Conductor Surface Intermediate 20" 13-3/8" 9-5/8" Production Liner 4,765' 9,760' Casing 103' 2,087' 4,673' 9,538' 4,765' 9,760'5-1/2" X 5" 3,090psi 7,460psi 3,060psi 3,450psi 5,750psi 10,640psi Burst Collapse 1,500psi 1,950psi Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Samantha Carlisle at 9:05 am, Nov 16, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.11.15 16:33:00 -09'00' Dan Marlowe (1267) DSR-11/16/21 RBDMS HEW 11/17/2021 BJM 11/19/21 SFD 11/17/2021 1 Winston, Hugh E (CED) From:McLellan, Bryan J (CED) Sent:Thursday, September 30, 2021 3:49 PM To:Jacob Flora Cc:Regg, James B (CED) Subject:RE: BCU-12A CBL Jake, You have approval to begin the CT mill‐out operation tomorrow per the Sundry you submitted today on BCU ‐12A (PTD 214‐070), on the following conditions: ‐BOP test pressure is 3000 psi. ‐ provide opportunity for AOGCC to witness the BOP test. I recognize it may be less than 24 hrs from now, so you’ll need Jim Regg’s agreement. He’s copied on this email, but you should get his verbal or email approval. I have sent the sundry to commissioners for approval, so you will most likely have it tomorrow. You also have approval to proceed with the perfs listed in Sundry 321‐449 based on the 29‐Sep‐21 CBL results you sent today. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Thursday, September 30, 2021 2:09 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: FW: BCU‐12A CBL Hi Bryan, Here’s the CBL from BCU‐12A, done two days after cementing the 3‐1/2” tubing. It shows a clear top. The downfall here is that we left 200+’ of cement stringers and do t have access to most of the target sands. Today we submitted a sundry to do a coil mill out to the shoe. I should have left this in the original as a contingency but did not. Is this something we can get a Verbal approval on to do? We’ve got the Petrospec coil unit at the gas field today and could possibly head there tomorrow. Thanks, Jake Begin forwarded message: State/Prov:Alaska Country:USA 150.0' 11/12/2021 Well Name & Number:Beaver Creek Unit #12A A - 028083 County or Parish:Kenai Peninsula Borough Lease: 20.3º @ 5,027' Date Completed:7/12/2014 Ground Level (above MSL): RKB (above GL): N/A 17.5' Revised By:J Lovett Schematic Revision Date: 19.2º @ 4,769'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: BCU - 12A Pad 4 2,023 FNL, 482' FEL, Sec. 33, T7N, R10W, S.M. TD: 9,800' MD 9,578' TVD Permit #:214-070 API #:50-133-20530-01 Prop. Des:FED A-028083 KB elevation:167.5' (17.5' AGL) Lat:N60° 39' 22.118" Long:W151° 1' 45.593" Spud:6/29/2014 12:00 hrs TD:7/07/2014 07:00 hrs Rig Released:7/13/2014 6:00 hrs PBTD: 7,664' MD 7,436' TVD SCHEMATIC 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT 0' - 7,564' MD 0' - 7,348' TVD 5" L-80 18 ppf DWC/C-HT 7,564' - 9,760' MD 7,348' - 9,538' TVD Cmt w/ 248 bbls of 15.3 ppg Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Max Dogleg: 4.42°/100' @ 8,004' Max Inclination: 20.3° @ 5,027' Conductor 20" K-55 133 ppf Top Bottom MD 0' 103' Surface Casing 13-3/8" K-55 68 ppf BTC MD 0' 2,087' TVD 0' 2,087' 16" hole Cmt w/ 600 sks (271 bbl) of 12.0 ppg, Type 1 cmt, 18 sks (8 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 4,765' TVD 0' 4,673' 12-1/4" hole Lead Cmt w/ 833 sks (341 bbls) of 12.5 ppg, Class G, Tail Cmt w/ 327 sks (106 bbls) of 13.5 ppg, Class G, 12 sks (5 bbls) to surface Jewelry 1. Swell Packer (21' Long) 2. CIBP (Set 11/18/14) Capped w/ 35' of cmt 3. CIBP (Set 11/02/14) 4. CIBP (Set 8/21/14) 5. CIBP (Set 8/09/14) 6. CIBP (Set 8/02/14) Depth 4,209' 7,820' 7,914' 8,125' 8,360' 8,475' 9-5/8 TOC 4375' - (USIT 7/21/14) 7820' CIBP w 35' cmt (11-18-14) 4 3 2 5 6 3-1/2" TOC @ ~3850' (9/29/21 CBL) 7564' 5 1/2" x 5" XO Liner/tubing (ran 9/27/21) 3-1/2" L-80 9.3ppf IBT SCC 0' - 7664' 0' - 7436' TVD Cmt w 250 sx 15.3 ppg cement, 1.23 yield 7764' 3-1/2 diverter sub on btm of tubing Perforations: Zone MD TVD Size SPF Date Status Sterling B3 5,206'-5,211' 5,089'-5,093' 3-1/8" 6 01/07/15 Isolated Sterling B3L 5,279'-5,299' 5,158'-5,177' 3-1/8" 6 12/09/14 Isolated Beluga 17 7,489'-7,495' 7,264'-7,270' 10/16/21 Open Beluga 18 7,517'-7,528' 7,291'-7,302' 10/16/21 Open Beluga 18 7,555'-7,560' 7,329'-7,334' 10/15/21 Open Beluga 19 7,566'-7,580' 7,340'-7,353' 10/15/21 Open Beluga 19 7,594'-7,604' 7,367'-7,377' 10/14/21 Open Beluga LWR 7,705'-7,721' 7,477'-7,493' 10/14/21 Open Beluga 21 7,732'-7,742' 7,504'-7,514' 10/14/21 Open Beluga LWR 7,741'-7,753' 7,513'-7,525' 10/13/21 Open LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-23 7,929'-7,941' 7,708'-7,720' 2-7/8" 6 09/03/14 Isolated LB-24 8,015'-8,028' 7,794'-7,807' 2-7/8" 6 09/03/14 Isolated LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 09/03/14 Isolated LB-26A 8,107'-8,117' 7,886'-7,896' 2-7/8" 6 09/03/14 Isolated LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 08/20/14 Isolated LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 08/20/14 Isolated LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 08/20/14 Isolated LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 08/04/14 Isolated LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 08/04/14 Isolated LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 08/04/14 Isolated LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 08/04/14 Isolated LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 07/30/14 Isolated LB-30 8,495'-8,510' 8,274'-8,289' 2-7/8" 6 07/30/14 Isolated LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 07/30/14 Isolated LB-31 8,600'-8,610' 8,379'-8,389' 2-7/8" 6 07/30/14 Isolated 16/21 Open 10/1Beluga 17 7,489'-7,495' 7,264'-7,270' 1 16/21 Open 10/1Beluga 18 7,517'-7,528' 7,291'-7,302' 1 B l 18 7 517' 7 528' 7 291' 7 302' 10/16/21 O1B l 18 7 517' 7 528' 7 291' 7 302' 10/16/21 O1B l 18 7 517' 7 528' 7 291' 7 302' 10/16/21 O 15/21 Open 10/1Beluga 18 7,555 7,560 7,329 7,334 1 Beluga 18 7 555'-7 560' 7 329'-7 334' 10/15/21 Open1Beluga 18 7 555-7 560 7 329-7 334 10/15/21 Open Beluga 19 7,566'-7,580' 7,340'-7,353' 10/15/21 Open1 g,,,, p 14/21 Open 10/1Beluga 19 7,594'-7,604' 7,367'-7,377' 1 14/21 Open 10/1Beluga LWR 7,705'-7,721' 7,477'-7,493' 1 B l LWR 7 705' 7 721' 7 477' 7 493' 10/14/21 O1Beluga LWR 7 705' 7 721' 7 477' 7 493' 10/14/21 Open 14/21 Open 10/1Beluga 21 7,732 7,742 7,504 7,514 1 Beluga 21 7 732'-7 742' 7 504'-7 514' 10/14/21 Open1Beluga 21 7,732 7,742 7,504 7,514 10/14/21 Open 13/21 Open10/1Beluga LWR 7,741'-7,753'7,513'-7,525'1 gg,,,, 13/21 Open 10/1Beluga LWR 7,741 7,753 7,513 7,525 1 Rig Start Date End Date Rig 401 / CTU / Eline 9/14/21 10/26/21 Held PJSM, Check well for pressure "0" prep to pick up BHA. Make up BHA & RIH with same ( BIT Bit sub, (4) 3-1/8" drill collars, XO = 124.01 ft. RIH with 2-7/8" ph 6 work string f/ 124 ft.to 5,208 ft, tagging up at 5,208 ft. dpm, lay out single to 5,193 ft. pick up wt. 35k s/o wt. 32k. Move pipe handle, set up power swivel, unit change out handling equipment, R/up power swivel. Pump at 2 bpm at 160 psi, wash down from 5,193 ft. to 5,224 ft. pressure increased to 260 psi, saw returns after 18 bbls pumped, rotated down f/ 5,224 ft to 5,254 ft. pressure increased to 440 psi, rotating wt. 35 k. Circulate surface to surface, circulating out gas, sand & muddy water, at 2 bpm at 440 psi. Lay out two joints from 5,254 ft. to 5,193 ft. P/up wt 36k secure well for night. 09/17/2021- Friday Held PJSM , check well for pressure "0" prep to RIH using power swivel. RIH using swivel f/ 5,193 ft. to 5,265 ft., tagging up at 5,265 ft. S/O wt. 34k pick up wt. 37k. Drilling on CIBP at 5,265 ft. dpm pumping at 2.5 bpm at 440 psi, wob 2-4k Rt. wt. 35k, at 80 rpm, torque at 1,200 ft. lbs. at start of drilling on CIBP, Torque slowly decreased to 500 ft. lbs. Drilled total of 7" of CIBP Had no returns while drilling the CIBP lost total of 544 bbls 8.4 ppg water. Rig down power swivel and hang off same, change handling equipment to 2-7/8" pipe. Pooh with work string f/ 5,265 ft. dpm to 124 ft. BHA, Rack back 1 stand collars, break off bit, all 3 cones loose. Pick up junk mill & RIH with BHA # 2 to 129 ft. change out handling equipment. RIH with 2-7/8" ph 6 work string to 1,949 ft. secure well for night. 09/15/2021 - Wednesday Held PJSM set BPV and nipple down 5-1/8" 5m x 11"5m tree in sections and lay out same. Install Cactus 11" 5m x 7-1/16" 5m tubing head with 2-1/16" 5m SSO, 9-1/2" BG bottom, nipple up same and test void to 5,000 psi (good test) Nipple up 7-1/16" 5m BOPE, hook up Koomey lines and function test same. Install rig foor, railings, stairs, and racking matt, M/up 2-7/8" & 3- 1/2" test joints. Fill BOPE , function equipment to purge air. Test new rental 7-1/16" 5m BOPE (Annular, VBR's, Blinds & choke and kill lines to 250 low and 5,000 psi, with 2-7/8" & 3-1/2" pipe, test rigs choke manifold to 250 low and 3,000 psi, all test held 5 minutes on chart and test made with water, had one fail/ pass on annular increase regulator pressure to 1,500 psi to pass, and bump up choke manifold test #4 on low pressure to pass low test, preform Accumulator draw down. Pull test plug, lay out test joints, pull BPV, shut Blinds, and inside kill and choke , brk down test Equipment and joints, rig up floor with tong and handling equipment, load pipe racks with work string and strap same, finish installing berm, set Rain for Rent tank in containment. 09/16/2021 - Thursday 09/14/2021 - Tuesday Held PJSM, Lay down felt and liner, set base beam and carrier, pump, pits, & gas buster, install 90 on gas buster, set Accumulator & choke house, raise and scope up derrick. Rig up pits and pump hoses, flange up to tree wing , running Electric lines, & sensor equipment, burm around liner, & stage equipment around location, check well pressure "O" psi no blow or gas. Pump down tbg with 122 bbls of 8.4 ppg water at 3 bpm at 50 psi, shut down pump well on strong vacuum, secure well for night. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-12A 50-133-20530-01-00 214-070 Rig Start Date End Date Rig 401 / CTU / Eline 9/14/21 10/26/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-12A 50-133-20530-01-00 214-070 09/19/2021 - Sunday Held PJSM check well for pressure, lay out liner, set up mix pit, and rig up same , change out Battery out on Mix pit Generator. Fill mix pit with 80 bbls 8.4 ppg water & Mix (12) 5 gallons bucket of drill express with (25) 50# bags of NW 50. Pump 20 bbls 8.4 ppg HI vis pill at 2 bpm at 200 psi, displace with 17 bbls 8.4 ppg water at 2 bpm at 350 psi pump 10 bbls on back side shut down pump (no returns). RIH from 5,136 ft. to 6,045 ft. dpm P/up 36k s/o 33k. Pump 20 bbls 8.4 ppg Hi Vis pill, displace with 72 bbls of 8.4 ppg water at 2.5 bpm 600/800 psi with no returns, pump 10 bbls 8.4 ppg hi vis pill at 2.0 bpm 120 psi displace with 25 bbls 8.4 ppg water. at 2.5 bpm at 670 psi. RIH with 2-7/8 work string f/ 6,045 ft dpm to 6,593 ft. dpm. Pump 20 bbls 8.4 ppg Hi vis pill at 2.0 bpm at 330 psi, circ same around at 3.0 bpm at 950 psi got partial returns after displacing pill with 9 bbls continue circulating while mixing another pill pump 119 bbls shut down pump. Pooh f/ 6,593 ft. to 5,136 ft. dpm p/up 37k s/o 33k. Pump 50 bbls of 8.4 ppg. Drill express hi vis pill at 2.0 bpm at 440 psi displace with 15 bbls of 8.4 ppg.water after pumping 45 bbls got partial returns. shut down pump and secure well for night. 09/20/2021 - Monday Held PJSM, check well for pressure, m/up head pin and prime mud pump. Pump 20 bbls 8.4 ppg HI vis pill at 2 bpm at 420 psi had partial returns with 16 bbls pill pumped displacing pill, with 17 bbls 8.4 ppg water, at 2.0 bpm with 400 psi bull head remaining 10 bbls at 1.0 bpm at 130 psi at 5,136 ft. dpm fill mix pit with 80 bbls, water, and mix Drill express in pit. RIH from 5,136 ft. to 7,139 ft. with 2-7/8" work string p/up wt. 43k s/o wt. at 37k. R/up power swivel. Pump 5 bbls 8.4 ppg. hi vis pill getting returns with 8 bbls pumped away continue pumping at 2.5 bpm at 700 psi, rotating 80 rpm f/ 7,139 ft. to 7,230 ft. dpm p/up wt. 47k s/o wt. 40k,, torque at 1,000 to 2,000 ft. lbs. reaming and working down same. pump 5 bbls Hi vis pill started displacing same, swivel packing dripping , attempt to tighten got worse, call for new wash pipe and packing, lay out single and remove swivel packing work pipe while waiting on swivel packing, install new packing. Made connection attempted to wash at 7,230', swivel packing leaking, shut down same, lay out single , lower swivel and close TIW and test packing no good. hang off swivel in derrick, and rig up to pooh to above perfs. Pooh with work string to 5,236 ft. dpm to 5,136 ft. dpm. Pump 30 bbls hi vis sweep and displace same with 15 bbls. lay out power swivel. 09/18/2021 - Saturday Held PJSM, trip in hole f/ 1,949 ft. to 5,265 ft. with 2-7/8" ph 6 work string. P/up power swivel. Milling on 5-1/2" CIBP at 6,265 ft. pumping at 2.5 bpm at 400 psi, with 2/3k wt on bit, with 80 RPM, with 1,200 ft lbs torque, reduced pump rate to 1 bpm at "0" psi, continue to mill on plug with 4/6k wt on bit. broke thru plug at 1100 hr. ream 3 times from 5,255 to 5,287 ft. wash down f/ 5,287 ft. to 5,318 ft. with no problems shut down pump & monitor well ( no flow from well ) no returns while milling plug. Set up pipe skate, R/d power swivel, change out handling equipment, load pipe rack and strap pipe. TIH picking up 2- 7/8", ph 6 7.9# w/s from 5,318 ft. to 7,109 ft. taking wt. at 7,109 ft. dpm. pick wt. 40k and s/o wt. 34k. Pick up power swivel. Pick up to 7,079 ft. & Rotate & wash down f/ 7,079 ft. to 7,160 ft. pipe stalled out, work same free, circulate at 3 bpm at 900 psi working pipe f/ 7,160 ft. to 7,140 ft. torque at 1,000 to 1,700 ft. lbs. pump pressure down to 850 psi shut down pump lay out single and, rack back power swivel. Pooh with work string to 5,136 ft, secure well for night. Rig Start Date End Date Rig 401 / CTU / Eline 9/14/21 10/26/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-12A 50-133-20530-01-00 214-070 09/24/2021- Friday Held PJSM, check well for pressure, RIH f/ 7,533 ft. to 7,777 ft. dpm p/up 46k s/o 44k rig up head pin and Kelly hose. Pump 5 bbls hi vis pill and circulate surface to surface at 2.5 bpm at 780 psi, pump 10 bbs Hi vis pill and spot it on bottom covering 4- 1/2" pipe from 7,777 ft. to 7,564 and 5-1/2 pipe f/ 7,564 tol 7,285 ft. +/-. Pooh laying down 2-7/8" work string f/ 7,777 ft. to BHA. Change Elevators and Pooh laying down 3-1/8" drill collars and x/overs and mill ( note one piece of face of mill missing). Move pipe trailers around, rig down power swivel off rig floor and roll up hoses, change out pipe handling equipment, set up pipe racks, and load pipe racks with 3-1/2" IBT, Strap pipe and perp floor to pick up 3-1/2" IBT Tbg, secure well for night. Held PJSM, Check well for pressure, take power swivel off rig floor, pick up spare swivel hang off same in derrick. RIH f/ 5,136 ft. to 7,200 ft. p/up wt. 44k s/o wt. 38k. Rig up power swivel, hook up hydraulic hoses, had leaks on hydraulic block on swivel manifold, remove hose cover from swivel and make repairs to hoses & connections. Pump 5 bbls 8.4 ppg hi vis pill at 2 bpm at 500 psi rotate and wash down f/ 7,200 fto 7,230 ft. at 80 rpm with 1,000 to 2,500 ft, lbs pick up wt 44k s/o wt 38k. Switch hoses for drillers console for proper operation of swivel direction. Wash and ream f/ 7,230 to 7,564 ft at 2.5 bpm at 675 psi getting returns 19 bbls after started pumping p/up wt. 45k s/o wt 38k, reaming at 80 rpm with 1,000 to 2,500 ft./lbs pump 5 bbls hi vis pill every 3rd joint. Pump 10 bbls hi vis pill and Circulate around at 2.5 bpm at 925 psi getting back sand and muddy water. Hang off power swivel in derrick, rig up power tongs. Pooh racking back 3 jts 2-7/8" ph 6 work string. Blow down lines and secure well for night. 09/22/2021 - Wednesday Held PJSM, check well pressure, move pipe handler out of the way to rack pipe back, circulate pill in mix pit. Pooh f/ 7,442 ft. to BHA, change elevators and slips, rack back BHA Break off Mill 75% worn on face. make up 2-7/8" & 3.5" test joints, fill stack and purge air from system, land 2-7/8" test joint in hanger. Test 11" 5k BOPEs and related surface equipment to 250, 2,500 & 3,000 psi, with 2-7/8" & 3.5" pipe, test held on chart 5 minutes & test made with water, no failed test, test waived by Jim Regg with AOGCC, perform Koomey draw down. Pull test plug and lay out same. Make up 4-1/8" mill and TIH with same, on 2-7/8" work string. 09/23/2021 - Thursday Held PJSM, check well "0" circulate mix pit. RIH with 4-1/8" mill f/ 2,220 ft to 5,350 ft. s/o 30k s/o 27k. Pump 10 bbls of LCM pill at 2.5 bpm at 370 psi with returns at 17 bbls pumped away. Continue to RIH with mill f/ 5,350 ft. dpm to 7,533 dpm p/up wt. 47k s/o 42k tagging up on fill at 7,533 ft. Spot concrete blocks on racking mat spot pipe handler in place R/up power swivel. Pump 5 bbls Hi vis pill and wash & ream f/ 7,533 ft. dpm to 7,747 ft. dpm with 60/80 rpm with 2,500 to 3,000 ft lbs torque, wash down f/ 7,747 ft. dpm to 7,777 ft. dpm with no rotating pumping at 2.5 bpm at 850 psi back ream jts. Pump 5 bbls hi vis pill and circulate around same. at 2.5 bpm at 625 psi. Hang off power swivel and, move concrete blocks off racking mat, rack back 5 stds in derrick EOT at 7,473 ft. dpm. secure well for night. 09/21/2021 - Tuesday Rig Start Date End Date Rig 401 / CTU / Eline 9/14/21 10/26/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-12A 50-133-20530-01-00 214-070 09/29/2021 - Wednesday Finish mobe rig off BCU 12A pad. 10/05/2021 - Tuesday MIRU Petrospec CTU with 1.75" coil. TEST BOPE 250/3,500. MU YJOS Motor and mill. RIH mill cement and dart valve 7,580' to 7,686' CTMD. Held PJSM check well for pressure, purge all circulating lines to check for ice. Pooh f/l 7460 ft. dpm to surface lay out 10 jts of 3.5 IBT with 4.29 collars & load on trailers. Load pipe rack and strap 10 jts 3.5 IBT with 3.88 collars. TIH with 3.5 9.2# IBT out of derrick f/ 312 ft. t/ 6029 ft. Run centralizers every other joint from 3641' - 7423' (joints 11-133). Secure well for night. 09/27/2021 - Monday Held PJSM , Check well for pressure "0" TIH w/ 3.5 IBT 9.2 # L-80 tbg f/ 6,029 '. to 7,766' dpm tagging at 7,766' dpm, , l/out 2 jts, EOT at 7,726.97 ft. space out with pups 9.70, 8.00, 4.80, 2.07, hanger pup and hanger 4.0, + 8.75 elevation = EOT at 7,764.29 landing hanger with 43k down wt. pick up wt 52k. Rig up cementers, pump 5 bbls 8.4 ppg water, Test lines to 3482 psi, Break circulation pumping at 2.5 bpm at 180 psi. got returns at 15 bbls pumped, Mixed and pump 250 sxs Type 1//2 cmt 53 bbls slurry mixed at 15.3 ppg. with 1.23 yld with 1 p/lb. bridge maker maker on the first 25 bbls cmt mixed ,pumped cmt at 3 bpm at 81 psi displace cmt at 3 bpm at 59 psi at 40 bbls pumped pressure at 452 at 60 bbls pumped pressure at 1,687 psi, slowed rate & continue pumping at 1 bpm 1,347 psi, final pressure with 67.5 bbls pumped away 1632 psi. Shut down pump & shut in tbg with 1,330 psi on same, had full returns during the cmt job. shut down pump flow stopped 1 minute after stopped pumping. Materials used 5 gal D-Air, 5 Gal, - MMCR, 50 lbs of sodium Citrate, 25 bls Bridge maker II Lcm, CMT in plate at 13:37 hours, close in tbg with 1330 psi on same bleed off lines. Waiting on cmt cleaning up after cmt job, cleaning pits and mix pit. 09/28/2021 - Tuesday Held PJSM, checked well pressure at cmt head SITP 1,100 psi. Thaw lines and set up test pump, start cleaning pits. Rig up test pump to cmt head, open up and test tbg to 1,500 psi for 15 minutes on chart Good test, bleed off pressure. install back pressure valve nipple down BOPE and load out same on trailer nipple up tree, test void to 5,000 psi for 15 minutes, good test, pull BPV, finish cleaning, Scope down derrick and lay down same, rigging down rig for move, finish cleaning. Scope down derrick and lay down same, rigging down rig for move. 09/25/2021 - Saturday Held PJSM, PREP rig floor to RIH with 3.5" tbg. Pick up and RIH with 3.5 9.2 # IBT diverter sub with (16) 1/2" hole in same, on 3.5" 9.2# IBT tbg to 7,306 ' dpm, set down at 7,306' dpm, made several attempt to get deeper had no luck. Rack back two stands in derrick and secure well for night. 09/26/2021 - Sunday had full returns during the cmt job. TIH with 3.5 9.2# IBT out of derrick f/ 312 ft. t/ 6029 ft. Run centralizers every other joint from 3641' - 7423' Mixed and pump 250 sxs Type 1//2 cmt 53 bbls slurry mixed at 15.3 ppg. w test tbg to 1,500 psi for 15 minutes on chart Good test, TEST BOPE 250/3,500. M Ran CBL in 3-1/2" liner. TOC at 3850' MD. bjm TIH w/ 3.5 IBT 9.2 # L-80 tbg f/ 6,029 '. to 7,766' dpm tagging at 7,766' dpm, , l/out 2 jts, EOT at 7,726.97 ft. space out with pups 9.70, 8.00, 4.80, 2.07, hanger pup and hanger 4.0, + 8.75 elevation = EOT at 7,764.29 final pressure with 67.5 bbls pumped away 1632 psi. Rig Start Date End Date Rig 401 / CTU / Eline 9/14/21 10/26/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-12A 50-133-20530-01-00 214-070 PTW, JSA with crews. Pick injector head make up 20' of lubricator. Make up MHA . PT 250/3,500 psi. Make up motor and 2.80" 3 bladed junk mill. BHA nomenclature and dimensions listed on previous daily report. Stab on well. PT stack 250/3,500 psi. Open master and swab. 0 psi WHP. IA 0 psi. OA 220 psi. Dry tag cement at 7,692' CTMD. Pick up and establish parameters. UP weight 27K. RIH weight at 7,600' 12.5K. Online 1.4 bbls/min 3,200 psi. Start milling at 7,692' CTMD. Milled to 7,7056.7 with ROP of 30' per hour. Hard stalls at depth. 3 stalls and then good motor work. Milled down to 7,785' hard stall. 3 hard stalls at depth. On diverter sub. Fox energy N2 crew on location. Back ream and chase bottoms up from 7,785'-7,500' CTMD. N2 cooling down. RIH back to bottom. Drop circ sub ball and chase with 20 bbls of reel volume. Good indication of sheared circ sub. Online with N2 at 500 scf/min until temp was up. Increased N2 rate to 1,200 scf/min to blow well dry. Sat on bottom until N2 reached return tank. Start POOH to surface. 5,000' OOH all N2 at return tank. Close in choke and drop N2 rate to 500 scf/min. Coil tagged up at surface. Increase N2 rate to 1,100 scf/min to build WHP. Close in master and swab 23.5 turns. SITP 2,300 psi. RDMO . Supply tank and return tank emptied. Equipment off location. Location walk around completed. N2 pumped 1,840 gallons. 171,381 scf . 64 bbls of fluid removed from well. 10/13/2021 - Wednesday Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low to 2,500 psi high. TP - 2,317 psi. RIH w/ 2-3/8" x 12' HC, 6 spf, 60 deg phase #1 gun, tie into OHL and tag at 7,755' first tag. Run correlation log and send to town. Told to shift up 1'. Shifted up 1' and went down and tagged at 7,753'. Spot and fire gun from 7,741' to 7,753' w/2,317 psi. After 5 min - 2,315', 10 min - 2,312 psi and 15 min - 2,309 psi. POOH. All shots fired and gun was wet. Lay down lubricator and pull spent gun out and Change out shooting gama tool. The crew cross threaded the first shooting gama. Pick up lub and gun. RIH w/Gun #2, 2-3/8" x 10' HC, 6 spf, 60 deg phase and tie into OHL. The spare shooting gama quit working at 2,200'. Called town and discussed. Halliburton engr said he was 90% sure he can chase the threads on the first shooting gama. Also he going to see if they are using the spare shooting gama offshore. POOH. Rig lub off tree and secure well. Will be back in am. TP - 2,253 psi 10/14/2021 - Thursday Bleed TP down from 2,245 psi to 1,871 psi (field). Sign in. Mobe to location. PTW and JSA. Rig back lubricator. PT to 250 psi low and 2,500 psi high. RIH w/Gun #2, 2-3/8" x 10' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 7,732' to 7,742' w/1,878 psi. After 5 min - 1,880 psi, 10 min - 1,878 psi and 15 min - 1,876 psi. POOH. All shoots fired and gun was wet. (B21_2 sand). RIH w/Gun #3, 2-3/8" x 16' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 7,705' to 7,721' w/1,866 psi. Spot and fire gun. After 5 min - 1,866', 10 min - 1,865 psi and 15 min - 1,861 psi. POOH. All shots fired/Gun was wet. (LWR_ Beluga) Fired gun at 1320 hrs. RIH w/Gun #4, 2-3/8" x 10' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 7,594'' to 7,604' w/1,857 psi. Spot and fire gun. After 5 min - 1,856.4 psi, 10 min - 1,853.9 psi and 15 min - 1,851.2 psi. POOH. All shots fired/Gun was wet. (B19_Mid) Fired gun at 1701 hrs. Rig lubricator off well, secure well and will start again in morning. 10/06/2021 - Wednesday Dry tag cement at 7,692' CTMD. CBL? o perf from 7,732' to 7,742' w All shoots fired a Milled down to 7,785' hard stall. perf from 7,705' to 7,721' w/1,866 psi. Spot and fire gun. fire gun from 7,741' to 7,753' w o perf from 7,594'' to 7,604' w/1,857 psi. Spot and fire gun. Start milling at 7,692' CTMD. Milled to 7,7056.7 w Rig Start Date End Date Rig 401 / CTU / Eline 9/14/21 10/26/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-12A 50-133-20530-01-00 214-070 Sundry 321-449 MITIA to 2700 psi will not be performed due to the well failing to return to production. 10/15/2021- Friday PTW and JSA. Rig back up lubricator. Let truck regen again while rigging up. PT to 250 psi low and 2,500 psi high. TP 1,855 psi. RIH w/Gun #5, 2-3/8" x 14' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf (B19_Upper) from 7,566' to 7,580' w/1,877 psi. Spot and fire gun. After 5 min - 1,876 psi, 10 min - 1,875 psi and 15 min - 1,872 psi. POOH All shots fired/gun wet. Fired gun at 1111 hrs. RIH w/Gun #6, 2-3/8" x 14' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf (B18_Lower) from 7,555' to 7,560' w/1,855 psi. Spot and fire gun. After 5 min - 1,855 psi, 10 min - 1,853 psi and 15 min - 1,849 psi. POOH. All shots fired/Gun wet. Fired gun at 1421 hrs. Halliburton said it would be a safety concern to run the other 2 guns today. They said they have been working a 5 days straight and they were wore out. Rig down lubricator, secure well and SDFN. Be back in AM. 10/16/2021 - Saturday PTW and JSA. Rig back up lubricator. Let truck regen again while rigging up. PT to 250 psi low and 2,500 psi high. TP 1,862 psi. Arm Gun. RIH w/Gun #7, 2-3/8" x 11' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 7,517 to 7,528' (B18_Upper) w/1,866 psi. Spotted and fired gun. After 5 min - 1,865, 10 min - 1,863 psi and 15 min - 1,861 psi. POOH. All shots fired/Gun was wet. Shot at 1015 hrs. RIH w/Gun #8, 2-3/8" x 6' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 7,489' to 7,495' (B17_Lower) w/1,845 psi. After 5 min - 1,844 psi, 10 min - 1,843 psi and 15 min - 1,839 psi. POOH. All shots fired and gun wet. Fired at 1325. RIH w/Fluid Level log and tie into OHL. Found Fluid Level at 7,304'. Send log to town. Rig down off well, turn over to field and finish rigging down. 10/26/2021 - Tuesday MITIA will be required if the well is returned to production. bjm o perf from 7,489' to 7,495' (B17_Lower) w/ 7,555' to 7,560' w/1,855 psi. Spot and fire gun. perf from 7,517 to 7,528' (B18_Upper) w/1,866 psi. Spotted and fired gun. 7,566' to 7,580' w/1,877 psi. Spot and fire gun. All shots fired a Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/15/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 12A (PTD 214-070) Perf 10/13/2021 Please include current contact information if different from above. 37' (6HW Received By: d 11/17/2021 By Abby Bell at 4:02 pm, Nov 15, 2021 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 Coil Milling, 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? 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): 9800'NA Casing Collapse Structural Conductor 1,500 psi Surface 1,950 psi Intermediate 3,090 psi Production 7,460 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 Dan Marlowe 283-1329 Contact Name: Jake Flora Operations Manager Contact Email: Contact Phone: 777-8442 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 jake.flora@hilcorp.com 9578'9676'9454'2646 psi 5264', 7820', 7914', 8125', 8360', 8475' N/A; N/A N/A; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A028083 214-070 50-133-20530-01-00 Beaver Creek (BCU) 12A Beaver Creek / Beluga Gas Pool Length Size CO 237B Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY L-80 9.3# TVD Burst 7764' 10,640 psi MD 5,750 psi 3,060 psi 3,450 psi 103' 2,087' 4,673' 103' 2,087' 9,538'5-1/2" x 5" 20" 13-3/8" 103' 9-5/8"4,765' 2,087' 9,760' Perforation Depth MD (ft): 4,765' See Attached Schematic 9,760' 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: October 5, 2021 3-1/2" Perforate Repair Wepair Well Exploratory BOP TestMechanical Integrity Test Location Clearance No No Wellbore schematic13. Well Class after proposed work: Development ServiceStratigraphic Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. 321-513 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.09.30 06:17:50 -08'00' Dan Marlowe (1267) CT BOP test to 3000 psi. X 10-404 DSR-9/30/21 X DLB 09/30/2021BJM 9/30/21 dts 9/30/2021 JLC 10/1/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.01 11:22:12 -08'00' RBDMS HEW 10/1/2021 Well Prognosis Well: BCU-12A Date: 9-29-2021 Well Name: BCU-12A API Number: 50-133-20530-01 Current Status: SI Leg: NA Estimated Start Date: 10/05/21 Rig: NA Reg. Approval Req’d? 10-403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-070 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) AFE Number: Max. Expected BHP: ~3402 psi @ 7562’ TVD (Based upon 0.45 psi/ft gradient) Max. Potential Surface Pressure: ~2646 psi (Based upon BHP minus 0.1 psi/ft gas gradient) Well Status: Gas producer SI since March 2016. Brief Well Summary BCU-12A recently worked over drilling out the CIBP and cementing in 3-1/2” tubing to isolate the deeper Beluga from the open Sterling perforations. 200’ of cement stringers were left in the tubing and do not allow access to the target Beluga sands. The objective of this procedure is to use coil tubing to mill out the cement stringers and regain access to the original sundried Beluga perforations. Notes Regarding Wellbore Condition: 9/29/21 Logged CBL, found PBTD at 7510’ (the shoe sub on the 3-1/2” tubing is at 7764’) Procedure: 1. MIRU CTU, 24hr notice for BOP test 2. Conduct BOP test 250psi low, 3000psi high 3. RIH w milling BHA, mill out cement to 3-1/2” shoe at 7764’. 4. Blow down well with nitrogen, trap pressure for perforating, RDMO CTU. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Diagram 4. Nitrogen SOP -00 DLB State/Prov:Alaska Country:USA 150.0' Schematic Revision Date: 19.2º @ 4,769'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: 9/29/2021 Well Name & Number:Beaver Creek Unit #12A A - 028083 County or Parish:Kenai Peninsula Borough Lease: 20.3º @ 5,027' Date Completed:7/12/2014 Ground Level (above MSL): RKB (above GL): N/A 17.5' Revised By:Jake Flora BCU - 12A Pad 4 2,023 FNL, 482' FEL, Sec. 33, T7N, R10W, S.M. TD: 9,800' MD 9,578' TVD Permit #:214-070 API #:50-133-20530-01 Prop. Des:FED A-028083 KB elevation:167.5' (17.5' AGL) Lat:N60° 39' 22.118" Long:W151° 1' 45.593" Spud:6/29/2014 12:00 hrs TD:7/07/2014 07:00 hrs Rig Released:7/13/2014 6:00 hrs PBTD: 9,676' MD 9,454' TVD SCHEMATIC 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT 0' - 7,564' MD 0' - 7,348' TVD 5" L-80 18 ppf DWC/C-HT 7,564' - 9,760' MD 7,348' - 9,538' TVD Cmt w/ 248 bbls of 15.3 ppg Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Max Dogleg: 4.42°/100' @ 8,004' Max Inclination: 20.3° @ 5,027' Conductor 20" K-55 133 ppf Top Bottom MD 0' 103' Surface Casing 13-3/8" K-55 68 ppf BTC MD 0' 2,087' TVD 0' 2,087' 16" hole Cmt w/ 600 sks (271 bbl) of 12.0 ppg, Type 1 cmt, 18 sks (8 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 4,765' TVD 0' 4,673' 12-1/4" hole Lead Cmt w/ 833 sks (341 bbls) of 12.5 ppg, Class G, Tail Cmt w/ 327 sks (106 bbls) of 13.5 ppg, Class G, 12 sks (5 bbls) to surface Jewelry 1. Swell Packer (21' Long) 2. CIBP (Set 11/18/14) Capped w/ 35' of cmt 3. CIBP (Set 11/02/14) 4. CIBP (Set 8/21/14) 5. CIBP (Set 8/09/14) 6. CIBP (Set 8/02/14) Marker Joints: 4967', 5325', 6094', 6235', 7564', 8054', 8500' (RA) Depth 4,209' 7,820' 7,914' 8,125' 8,360' 8,475' Perforations: Zone MD TVD Size SPF Date Status Sterling B3 5,206'-5,211' 5,089'-5,093' 3-1/8" 6 1/07/15 Open Sterling B3L 5,279'-5,299' 5,158'-5,177' 3-1/8" 6 12/09/14 Isolated LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-23 7,929'-7,941' 7,708'-7,720' 2-7/8" 6 9/03/14 Isolated LB-24 8,015'-8,028' 7,794'-7,807' 2-7/8" 6 9/03/14 Isolated LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 9/03/14 Isolated LB-26A 8,107'-8,117' 7,886'-7,896' 2-7/8" 6 9/03/14 Isolated LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 8/20/14 Isolated LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 8/20/14 Isolated LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 8/20/14 Isolated LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 8/04/14 Isolated LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 8/04/14 Isolated LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 8/04/14 Isolated LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 8/04/14 Isolated LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 7/30/14 Isolated LB-30 8,495'-8,510' 8,274'-8,289' 2-7/8" 6 7/30/14 Isolated LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 7/30/14 Isolated 9-5/8 TOC 4375' - (USIT 7/21/14) 5206-5211' perfs (1-8-15) 5279-5299' perfs 12-9-14) 7820' CIBP w 35' cmt (11-18-14) 4 3 2 5 6 3-1/2" TOC @ ~3850' (9/29/21 CBL) Proposed Beluga Perforations ~7234 - 7791'7564' 5 1/2" x 5" XO Liner/tubing 3-1/2" L-80 9.3ppf IBT SCC 0' - 7664' Cmt w 250 sx 15.3 ppg cement, 1.23 yield 7764' 3-1/2 diverter sub on btm of tubing 7510' cement stringers State/Prov:Alaska Country:USA 150.0' 9/29/2021 Well Name & Number:Beaver Creek Unit #12A A - 028083 County or Parish:Kenai Peninsula Borough Lease: 20.3º @ 5,027' Date Completed:7/12/2014 Ground Level (above MSL): RKB (above GL): N/A 17.5' Revised By:Jake Flora Schematic Revision Date: 19.2º @ 4,769'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: BCU - 12A Pad 4 2,023 FNL, 482' FEL, Sec. 33, T7N, R10W, S.M. TD: 9,800' MD 9,578' TVD Permit #:214-070 API #:50-133-20530-01 Prop. Des:FED A-028083 KB elevation:167.5' (17.5' AGL) Lat:N60° 39' 22.118" Long:W151° 1' 45.593" Spud:6/29/2014 12:00 hrs TD:7/07/2014 07:00 hrs Rig Released:7/13/2014 6:00 hrs PBTD: 9,676' MD 9,454' TVD PROPOSED 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT 0' - 7,564' MD 0' - 7,348' TVD 5" L-80 18 ppf DWC/C-HT 7,564' - 9,760' MD 7,348' - 9,538' TVD Cmt w/ 248 bbls of 15.3 ppg Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Max Dogleg: 4.42°/100' @ 8,004' Max Inclination: 20.3° @ 5,027' Conductor 20" K-55 133 ppf Top Bottom MD 0' 103' Surface Casing 13-3/8" K-55 68 ppf BTC MD 0' 2,087' TVD 0' 2,087' 16" hole Cmt w/ 600 sks (271 bbl) of 12.0 ppg, Type 1 cmt, 18 sks (8 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 4,765' TVD 0' 4,673' 12-1/4" hole Lead Cmt w/ 833 sks (341 bbls) of 12.5 ppg, Class G, Tail Cmt w/ 327 sks (106 bbls) of 13.5 ppg, Class G, 12 sks (5 bbls) to surface Jewelry 1. Swell Packer (21' Long) 2. CIBP (Set 11/18/14) Capped w/ 35' of cmt 3. CIBP (Set 11/02/14) 4. CIBP (Set 8/21/14) 5. CIBP (Set 8/09/14) 6. CIBP (Set 8/02/14) Marker Joints: 4967', 5325', 6094', 6235', 7564', 8054', 8500' (RA) Depth 4,209' 7,820' 7,914' 8,125' 8,360' 8,475' Perforations: Zone MD TVD Size SPF Date Status Sterling B3 5,206'-5,211' 5,089'-5,093' 3-1/8" 6 1/07/15 Open Sterling B3L 5,279'-5,299' 5,158'-5,177' 3-1/8" 6 12/09/14 Isolated LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-23 7,929'-7,941' 7,708'-7,720' 2-7/8" 6 9/03/14 Isolated LB-24 8,015'-8,028' 7,794'-7,807' 2-7/8" 6 9/03/14 Isolated LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 9/03/14 Isolated LB-26A 8,107'-8,117' 7,886'-7,896' 2-7/8" 6 9/03/14 Isolated LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 8/20/14 Isolated LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 8/20/14 Isolated LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 8/20/14 Isolated LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 8/04/14 Isolated LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 8/04/14 Isolated LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 8/04/14 Isolated LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 8/04/14 Isolated LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 7/30/14 Isolated LB-30 8,495'-8,510' 8,274'-8,289' 2-7/8" 6 7/30/14 Isolated LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 7/30/14 Isolated 9-5/8 TOC 4375' - (USIT 7/21/14) 5206-5211' perfs (1-8-15) 5279-5299' perfs 12-9-14) 7820' CIBP w 35' cmt (11-18-14) 4 3 2 5 6 3-1/2" TOC @ ~3850' (9/29/21 CBL) Proposed Beluga Perforations ~7234 - 7791'7564' 5 1/2" x 5" XO Liner/tubing 3-1/2" L-80 9.3ppf IBT SCC 0' - 7664' Cmt w 250 sx 15.3 ppg cement, 1.23 yield 7764' 3-1/2 diverter sub on btm of tubing Mill cement stringers to the diverter sub (shoe) Coiled Tubing Services Pressure Category 1 BOP Configuration (0-3,500 psi) Client: Hilcorp Date: April 3rd, 2017 Drawn: Chad Barrett Revision: 0 Well Category: CAT I 4-1/16" 10K Combi BOP Top Set: Blind/Shear Second Set: Pipe/Slip Wellhead 4-1/16" 10K Conventional Stripper 4-1/16" 10K x Wellhead Adapter Flange 5K CO62 x 4-1/16" 10K Flange 5K CO62 Lubricator 4-1/16" 10K Flow Cross Manual 2x2 Valve 1: 2" 1502 x 2-1/16" 10K Flange Manual 2x2 Valve 2: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 3: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 4: 2" 1502 x 2-1/16" 10K Flange 21 3 4 WH PSI 2" 1502 x 2-1/16 10K Flanged Valve (Manual) 2-1/16 10K x 2-1/16 10K Flanged Valve (Manual) Kill Port Coiled Tubing HR580 Injector Head & Gooseneck Weight = 12,850 lbs Swanson River Field SRU 34A-33 10/20/2020 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 Guhl, Meredith D (CED) From:McLellan, Bryan J (CED) Sent:Thursday, September 30, 2021 3:49 PM To:Jacob Flora Cc:Regg, James B (CED) Subject:RE: BCU-12A CBL Jake, You have approval to begin the CT mill‐out operation tomorrow per the Sundry you submitted today on BCU ‐12A (PTD 214‐070), on the following conditions: ‐BOP test pressure is 3000 psi. ‐ provide opportunity for AOGCC to witness the BOP test. I recognize it may be less than 24 hrs from now, so you’ll need Jim Regg’s agreement. He’s copied on this email, but you should get his verbal or email approval. I have sent the sundry to commissioners for approval, so you will most likely have it tomorrow. You also have approval to proceed with the perfs listed in Sundry 321‐449 based on the 29‐Sep‐21 CBL results you sent today. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Thursday, September 30, 2021 2:09 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: FW: BCU‐12A CBL Hi Bryan, Here’s the CBL from BCU‐12A, done two days after cementing the 3‐1/2” tubing. It shows a clear top. The downfall here is that we left 200+’ of cement stringers and do t have access to most of the target sands. Today we submitted a sundry to do a coil mill out to the shoe. I should have left this in the original as a contingency but did not. Is this something we can get a Verbal approval on to do? We’ve got the Petrospec coil unit at the gas field today and could possibly head there tomorrow. Thanks, Jake Begin forwarded message: 2 From: Roy Wright <rwright@yjosllc.com> Date: September 29, 2021 at 6:38:09 PM AKDT To: Jacob Flora <Jake.Flora@hilcorp.com>, "Jeff Nelson ‐ (C)" <Jeff.Nelson@hilcorp.com> Subject: [EXTERNAL] FW: BCU‐12A CBL The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA Reviewed By:— OIL AND GAS CONSERVATION COMMISSION P.I. Supry Iv 11 wl? j BOPE Test Report for: BEAVER CK UNIT 12A ' Comm Contractor/Rig No.: Hilcorp 401 ' PTD#: 2140700 ' DATE: 9/15/2021 / Inspector Austin McLeod Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: Ed Hooter Rig Rep: Kevin Reed Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopSAM210916113927 Rams: Annular: Valves: MASP: Type Test: INIT 321-449 _ 250/5000 • 250/5000 ' 250/3000 ' 2646 v Related Insp No: M ISC. INSPECTIONS: FLOOR SAFTY VALVES: P/F Location Gen.: -P -. Housekeeping: P PTD On Location P_ " Standing Order Posted P Well Sign P " Drl. Rig P ' Hazard Sec. NA Misc NA FLOOR SAFTY VALVES: ACCUMULATOR SYSTEM: Quantity P/F Upper Kelly 0 NA - Lower Kelly 0 NA Ball Type 1 ----------- P ----- Inside BOP 1 P FSV Misc 0 NA TEST DATA MUD SYSTEM: ACCUMULATOR SYSTEM: Visual Alarm Time/Pressure P/F Trip Tank NA NA _ System Pressure 3025 P ' Pit Level Indicators P - P " Pressure After Closure 2550 P Flow Indicator NA - NA 200 PSI Attained 22 P Meth Gas Detector P_ P ' Full Pressure Attained 45 - _ P H2S Gas Detector P " P Blind Switch Covers: All stations -P ' MS Misc NA NA Nitgn. Bottles (avg): 6(x,2200 _ P ACC Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 0 NA No. Valves 8 FP ✓ Annular Preventer 1 7-1/16 - FP Manual Chokes 2 P- "#1 #1 Rams 1 '2-3/8_0-1/2 P Hydraulic Chokes 0 NA #2 Rams 1 'Blinds P CH Misc 0 NA #3 Rams 0 NA #4 Rams 0 NA - #5 Rams _0- -- -_ NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 - 2-1/16 - P , Quantity P/F HCR Valves 1 24/16 - P- Inside Reel Valves __-0 NA Kill Line Valves 3 2-1/16 ' P ' Check Valve 0 NA BOP Misc 0 NA Number of Failures: 2 ✓ Test Results f Test Time 3.5 Remarks: 2-7/8 & 3-1/2 joints. Annular on 2-7/8. Fresh 7-1/16 stack & mud cross valves. All CMVs and outermost kill line valve tested to 3k. Remaining components to 5k. Annular FP -manifold psi adjusted & cycled for a pass. Low test with 3 CMVs bumped x2 for a pass. 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 cement liner 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): 9800'NA Casing Collapse Structural Conductor 1,500 psi Surface 1,950 psi Intermediate 3,090 psi Production 7,460 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: Jake Flora Operations Manager Contact Email: Contact Phone: 777-8442 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 jake.flora@hilcorp.com 9578'9676'9454'2646 psi 5264', 7820', 7914', 8125', 8360', 8475' N/A; N/A N/A; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A028083 214-070 50-133-20530-01 Beaver Creek (BCU) 12A Beaver Creek / Beluga Gas Pool Length Size CO 237A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY N/A TVD Burst N/A 10,640 psi MD 5,750 psi 3,060 psi 3,450 psi 103' 2,087' 4,673' 103' 2,087' 9,538'5-1/2" x 5" 20" 13-3/8" 103' 9-5/8"4,765' 2,087' 9,760' Perforation Depth MD (ft): 4,765' See Attached Schematic 9,760' 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: September 10, 2021 N/A Perforate Repair Wepair Well Exploratory BOP TestMechanical Integrity Test Location Clearance No No Wellbore schematic13. Well Class after proposed work: Development ServiceStratigraphic Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:58 am, Sep 07, 2021 321-449 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.07 09:26:28 -08'00' Taylor Wellman (2143) Perforate New Pool 10-404 X Annular test to 2500 psi. X Beluga Gas Pool DSR-9/7/21 Review 3.5" CBL with AOGCC prior to perforating. -00 DLB SFD 9/7/2021 X CO 237B DLB 09/07/2021BJM 9/9/21 BOP test to 3000 psi. MITIA to 2700 psi within 10 days of return to production after perforating. Provide 24 hrs notice for AOGCC witness. dts 9/9/2021 JLC 9/10/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.10 14:15:22 -08'00' RBDMS HEW 9/13/2021 Well Prognosis Well: BCU-12A Date: 9-02-2021 Well Name: BCU-12A API Number: 50-133-20530-01 Current Status: SI Leg: NA Estimated Start Date: 9/10/21 Rig: NA Reg. Approval Req’d? 10-403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-070 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) AFE Number: Max. Expected BHP: ~3402 psi @ 7562’ TVD (Based upon 0.45 psi/ft gradient) Max. Potential Surface Pressure: ~2646 psi (Based upon BHP minus 0.1 psi/ft gas gradient) Well Status: Gas producer SI since March 2016. Brief Well Summary BCU-12A was drilled in 2014 targeting Beluga gas sands and was completed in the Sterling shortly after. Both completions were unsuccessful. The purpose of this work/sundry is to remove/push down the existing CIBP, isolate the Sterling with two permanent patches, and perforate multiple Beluga targets. The purpose of this sundry is to re-access the Beluga sands, isolate the Sterling sands with a cemented 3.5” liner, and recomplete the well in the Beluga sands below. Notes Regarding Wellbore Condition: 2/11/2016 Slickline bailed sandy mud from 5194’ Procedure: 1. MIRU 401. 2. Notify AOGCC 24hrs in advance of BOP test. 3. Bullhead tubing with water, Set BPV, ND Tree. 4. NU tubing head for 3-1/2 tubing. 5. NU BOP and test to 250 psi low & 2,500 psi high, annular to 250 psi low & 2,000 psi high. Record accumulator pre-charge pressures and chart tests. a. Perform Test. b. Test rams on 2-7/8” & 3-1/2” test joints. c. Submit completed form 10-424 to AOGCC within 5 days of BOPE test. 6. Pull BPV 7. MU milling BHA. PU 2-7/8” workstring. 8. TIH to CIBP at 5264’, drill and push to TD at ~7800’. It may be necessary to make a separate run with a smaller bit to push into the 5” casing below 7564’. 9. Run 3-1/2” tubing to ~7800’, land and test hanger. 10. Install floor valve on landing joint. 11. MU cement head, RU cement truck. isolate the Sterling with two permanent patches, Bullhead with >8.8 ppg brine. bjm Include centralizers on cemented liner section. BJM. -00 DLB DLB 3000 psi high 2500 psi high Well Prognosis Well: BCU-12A Date: 9-02-2021 12. Mix and pump 84 bbls of 15.3 ppg cement, drop wiper plug, displace to float collar. (planned 3-1/2 x 5- 1/2 TOC is 3000’). Choke returns thru annulus valve while pumping, no cement is being returned to surface. 13. Close floor valve, trap displacement pressure. 14. WOC overnight. 15. MIT tubing to 1500 psi. 16. Bleed off pressure, ND landing joint, ND BOP, NU tree, RDMO Rig 401. 17. RU E-line, log CBL, submit results to AOGCC. 18. MITIA to 1500 psi for 30 minutes. 19. Swab well down. Pressure up with well gas. 20. Perforate the below sands from the bottom up. 21. RD E-Line. Sand TOP MD BOT MD Total TOP TVD BOT TVD B15 ±7,234’ ±7,275’ ±41’ ±7,017’ ±7,056’ B17_Upper ±7,473’ ±7,478’ ±5’ ±7,249’ ±7,253’ B17_Lower ±7,489’ ±7,498’ ±9’ ±7,264’ ±7,273’ B18_Upper ±7,516’ ±7,528’ ±12’ ±7,290’ ±7,302’ B18_Lower ±7,554’ ±7,560’ ±6’ ±7,327’ ±7,334’ B19_Upper ±7,565’ ±7,580’ ±15’ ±7,337’ ±7,353’ B19_Mid ±7,594’ ±7,604’ ±10’ ±7,367’ ±7,377’ B19_Lower ±7,622’ ±7,629’ ±7’ ±7,395’ ±7,402’ B20_Upper ±7,634’ ±7,642’ ±8’ ±7,406’ ±7,414’ B20_Middle ±7,656’ ±7,670’ ±14’ ±7,428’ ±7,442’ B20_Lower ±7,676’ ±7,687’ ±11’ ±7,448’ ±7,459’ LWR_BELUGA ±7,704’ ±7,721’ ±17’ ±7,476’ ±7,493’ B21 ±7,730’ ±7,761’ ±31’ ±7,502’ ±7,534’ B21_LWR ±7,775’ ±7,791’ ±16’ ±7,545’ ±7,562’ 22. Return to production. Nitrogen (Contingency) 1. If Nitrogen is required to pressure up well prior to perforating: 2. MIRU Nitrogen Unit, review Nitrogen SOP, pressure well to desired perforating pressure. E-line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: 2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High. 3. RIH and set plug 50’ above the perforations, dump 35’ cement on plug. Note: all zones lie in the Beaver Creek Beluga Gas Pool. Attachments: 53 bbls - see correction in email attached - bjm Wait for AOGCC approval before perforating. MITIA to 2700 psi within 10 days after returning to production. all zones lie in the Beaver Creek Beluga Gas Pool. Well Prognosis Well: BCU-12A Date: 9-02-2021 1. Actual Schematic 2. Proposed Schematic 3. Rig 401 BOP Diagram 4. Nitrogen SOP State/Prov:Alaska Country:USA 150.0' 1/7/2015 1/8/2015 Well Name & Number:Beaver Creek Unit #12A A - 028083 County or Parish:Kenai Peninsula Borough Lease: 20.3º @ 5,027' Date Completed:7/12/2014 Ground Level (above MSL): RKB (above GL): N/A 17.5' Revised By:Stan Porhola Downhole Revision Date: Schematic Revision Date: 19.2º @ 4,769'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: BCU - 12A Pad 4 2,023 FNL, 482' FEL, Sec. 33, T7N, R10W, S.M. TD: 9,800' MD 9,578' TVD Permit #:214-070 API #:50-133-20530-01 Prop. Des:FED A-028083 KB elevation:167.5' (17.5' AGL) Lat:N60° 39' 22.118" Long:W151° 1' 45.593" Spud:6/29/2014 12:00 hrs TD:7/07/2014 07:00 hrs Rig Released:7/13/2014 6:00 hrs PBTD: 9,676' MD 9,454' TVD ACTUAL SCHEMATIC 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom MD 0' 7,564' TVD 0' 7,348' 5" L-80 18 ppf DWC/C-HT Top Bottom MD 7,564' 9,760' TVD 7,348' 9,538' 8-1/2" hole Cmt w/ 1030 sks ( 248 bbls) of 15.3 ppg, Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Casing/Cementing Detail - 9.4 ppg Mud - 10.5 ppg Mud Push (38 bbl) - 15.3 ppg Cement (248 bbl) - 8.4 ppg Fresh Water (215 bbl) Max Dogleg: 4.42°/100' @ 8,004' Max Inclination: 20.3° @ 5,027' RA Mkr Jt 8,054' RA Mkr Jt 8,500' Openhole Casing 40' off bottom Casing Shoe @ 9,760' Conductor 20" K-55 133 ppf Top Bottom MD 0' 103' TVD 0' 103' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,087' TVD 0' 2,087' 16" hole Cmt w/ 600 sks (271 bbl) of 12.0 ppg, Type 1 cmt, 18 sks (8 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 4,765' TVD 0' 4,673' 12-1/4" hole Lead Cmt w/ 833 sks (341 bbls) of 12.5 ppg, Class G, Tail Cmt w/ 327 sks (106 bbls) of 13.5 ppg, Class G, 12 sks (5 bbls) to surface XO Jt 7,564' Jewelry 1. Swell Packer (21' Long) 2. CIBP (Set 11/18/14) Capped w/ 35' of cmt 3. CIBP (Set 11/02/14) 4. CIBP (Set 8/21/14) 5. CIBP (Set 8/09/14) 6. CIBP (Set 8/02/14) Depth 4,209' 7,820' 7,914' 8,125' 8,360' 8,475' Perforations: Zone MD TVD Size SPF Date Status Sterling B3 5,206'-5,211' 5,089'-5,093' 3-1/8" 6 1/07/15 Open Sterling B3L 5,279'-5,299' 5,158'-5,177' 3-1/8" 6 12/09/14 Isolated LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-23 7,929'-7,941' 7,708'-7,720' 2-7/8" 6 9/03/14 Isolated LB-24 8,015'-8,028' 7,794'-7,807' 2-7/8" 6 9/03/14 Isolated LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 9/03/14 Isolated LB-26A 8,107'-8,117' 7,886'-7,896' 2-7/8" 6 9/03/14 Isolated LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 8/20/14 Isolated LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 8/20/14 Isolated LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 8/20/14 Isolated LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 8/04/14 Isolated LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 8/04/14 Isolated LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 8/04/14 Isolated LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 8/04/14 Isolated LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 7/30/14 Isolated LB-30 8,495'-8,510' 8,274'-8,289' 2-7/8" 6 7/30/14 Isolated LB-31 LB-31 LB-30 LB-30 Tag (unset cement) @ 9,464' SLM w/ 3.84" GR (7/16/14) TOC (USIT 7/21/14) - 4,375' 6LB-29B LB-29B LB-29 LB-29 LB-28 LB-28 LB-27 5 4 LB-23LB-24 LB-24 LB-26A Cap w/ 35' of Cement 26 gal of cement 3 LB-22 2 Sterling B3LCIBP @ 5,264' RKB Sterling B3 State/Prov:Alaska Country:USA 150.0' 7/29/2021 Well Name & Number:Beaver Creek Unit #12A A - 028083 County or Parish:Kenai Peninsula Borough Lease: 20.3º @ 5,027' Date Completed:7/12/2014 Ground Level (above MSL): RKB (above GL): N/A 17.5' Revised By:Jake Flora Schematic Revision Date: 19.2º @ 4,769'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: BCU - 12A Pad 4 2,023 FNL, 482' FEL, Sec. 33, T7N, R10W, S.M. TD: 9,800' MD 9,578' TVD Permit #:214-070 API #:50-133-20530-01 Prop. Des:FED A-028083 KB elevation:167.5' (17.5' AGL) Lat:N60° 39' 22.118" Long:W151° 1' 45.593" Spud:6/29/2014 12:00 hrs TD:7/07/2014 07:00 hrs Rig Released:7/13/2014 6:00 hrs PBTD: 9,676' MD 9,454' TVD PROPOSED 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT 0' - 7,564' MD 0' - 7,348' TVD 5" L-80 18 ppf DWC/C-HT 7,564' - 9,760' MD 7,348' - 9,538' TVD Cmt w/ 248 bbls of 15.3 ppg Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Max Dogleg: 4.42°/100' @ 8,004' Max Inclination: 20.3° @ 5,027' Conductor 20" K-55 133 ppf Top Bottom MD 0' 103' Surface Casing 13-3/8" K-55 68 ppf BTC MD 0' 2,087' TVD 0' 2,087' 16" hole Cmt w/ 600 sks (271 bbl) of 12.0 ppg, Type 1 cmt, 18 sks (8 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 4,765' TVD 0' 4,673' 12-1/4" hole Lead Cmt w/ 833 sks (341 bbls) of 12.5 ppg, Class G, Tail Cmt w/ 327 sks (106 bbls) of 13.5 ppg, Class G, 12 sks (5 bbls) to surface Jewelry 1. Swell Packer (21' Long) 2. CIBP (Set 11/18/14) Capped w/ 35' of cmt 3. CIBP (Set 11/02/14) 4. CIBP (Set 8/21/14) 5. CIBP (Set 8/09/14) 6. CIBP (Set 8/02/14) Marker Joints: 4967', 5325', 6094', 6235', 7564', 8054', 8500' (RA) Depth 4,209' 7,820' 7,914' 8,125' 8,360' 8,475' Perforations: Zone MD TVD Size SPF Date Status Sterling B3 5,206'-5,211' 5,089'-5,093' 3-1/8" 6 1/07/15 Open Sterling B3L 5,279'-5,299' 5,158'-5,177' 3-1/8" 6 12/09/14 Isolated LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-23 7,929'-7,941' 7,708'-7,720' 2-7/8" 6 9/03/14 Isolated LB-24 8,015'-8,028' 7,794'-7,807' 2-7/8" 6 9/03/14 Isolated LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 9/03/14 Isolated LB-26A 8,107'-8,117' 7,886'-7,896' 2-7/8" 6 9/03/14 Isolated LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 8/20/14 Isolated LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 8/20/14 Isolated LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 8/20/14 Isolated LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 8/04/14 Isolated LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 8/04/14 Isolated LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 8/04/14 Isolated LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 8/04/14 Isolated LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 7/30/14 Isolated LB-30 8,495'-8,510' 8,274'-8,289' 2-7/8" 6 7/30/14 Isolated LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 7/30/14 Isolated 9-5/8 TOC 4375' - (USIT 7/21/14) 5206-5211' perfs (1-8-15) 5279-5299' perfs 12-9-14) 7820' CIBP w 35' cmt (11-18-14) 4 3 2 5 6 Planned TOC @ 3000' Proposed Beluga Perforations ~7234 - 7791' 7564' 5 1/2" x 5" XO Liner (proposed) 3-1/2" IBT SCC 0' - 7800 (+ / - ) ϭϯͲϱͬϴΗϱDKW ,<ϰϬϭZ/' ϭϯͲϱͬϴΗϱD^,&& Z^W, Z/>EEh>Z ϰϱΗd>> ϭϯͲϱͬϴΗϱDEKs>yd>'d ͕ϯϭΗd>> Z ^^ tͬϮͲϳͬϴΗͲϱͲϭͬϮΗDh>d/ZD^/EdKW Z ^^ tͬ>/EZD^/EKddKD ϭϯͲϱͬϴΗϱDDhZK^^͕ϮϰΗd>> tͬϯ ,ϮͲϭͬϭϲΗϱDD's Θϭ ,ϮͲϭͬϭϲΗϱD,Z ϭϯͲϱͬϴΗϱD^W Z^WKK>͕ϮϰΗd>> ,<KtE ϭϯͲϱͬϴΗϱD^W Z^WKK>͕ϮϰΗd>> ,<KtE ΕϭϰϴΗdKd>^d<, /',d EEh>Z^dz> KW&>h/^W ^͗ ͲϮϯ͘ϱϴŐĂůůŽŶĐůŽƐĞĐŚĂŵďĞƌǀŽůƵŵĞ Ͳϭϳ͘ϰϭŐĂůůŽŶŽƉĞŶĐŚĂŵďĞƌǀŽůƵŵĞ >ydKW&>h/^W ^͗ Ͳϱ͘ϭϰŐĂůůŽŶƐƚŽĐůŽƐĞƉĞƌŐĂƚĞ Ͳϰ͘ϴϲŐĂůůŽŶƐƚŽŽƉĞŶƉĞƌŐĂƚĞ Ͳϲ͘ϰϳ͗ϭĐůŽƐŝŶŐƌĂƚŝŽ t d, Z&KZ Beaver Creek BC # 12A Current 08/28/2021 20'͛ 13 3/8'͛ 9.625'͛ Starting head, Vetco MB-196, 13 5/8 3M X 13 3/8 VG-Loc bottom, w/ 2- 2'͛LPO Multibowl, Vetco MB-196, 13 5/8 3M stdd bottom X 13 5/8 5M FE top, w/ 2- 2 1/16 5M SSO Valve, VG-200, 2 1/16 5M FE, HWO, AA trim Valve, Master, CIW-FC, 5 1/8 10M FE, HWO, EE trim Valve, Upper Master, WKM-M, 5 1/8 5M FE, HWO, DD trim Valve, Swab, WKM-M, 5 1/8 5M FE, HWO, DD trim Valve, Wing, WKM-M, 3 1/8 5M FE, HWO, DD trim Tree cap, Otis, 5 1/8 5M FE X 9 ½ Otis Quick Union Beaver Creek BC# 14 20 X 13 3/8 X 9 5/8 X 5 ½ Grade Level Completion spool, Cactus, 13 5/8 5M X 11 5M Tubing hanger, CXS, 11 X 5 ¾ left hand stub acme lift X 5 ½ DWC-C susp, w/ 5'͛Type H BPV profile 5½͛͛ Crossover spool, 5 1/8 5M FE X 5 1/8 10M FE Beaver Creek BC # 12A Proposed 08/28/2021 20'’ 13 3/8'’ 9.625'’ Starting head, Vetco MB-196, 13 5/8 3M X 13 3/8 VG-Loc bottom, w/ 2- 2'’ LPO Multibowl, Vetco MB-196, 13 5/8 3M stdd bottom X 13 5/8 5M FE top, w/ 2- 2 1/16 5M SSO Valve, VG-200, 2 1/16 5M FE, HWO, AA trim Beaver Creek BC # 14 20 X 13 3/8 X 9 5/8 X 5 ½ x 2 7/8 or 2 3/8 Grade Level Completion spool, Cactus, 13 5/8 5M X 11 5M Tubing hanger, CXS, 11 X 5 ¾ left hand stub acme lift X 5 ½ DWC-C susp, w/ 5'’ Type H BPV profile 5 ½’’ Valve, Master, CIW-FLS, 3 1/8 5M FE, HWO, EE trim Valve, Upper master, CIW-FLS, 3 1/8 5M FE, HWO, EE trim Valve, Swab, CIW-FLS 3 1/8 5M FE, HWO, EE trim Valve, Wing, CIW-FC, 3 1/8 5M FE, HWO, EE trim BHTA, Otis, 3 1/8 5M FE x 6.5 Otis quick union top Valve, Wing, SSV, WKM-M, 3 1/8 5M FE, w/ 15'’ air operator Tubing hanger, Cactus-EN- CL, 7 x 3 ½’’ EUE 8rd lift and susp, w/ 3 type H BPV profile, 1- ¼npt control line port Adapter, Cactus-EN, 7 1/16 5M Stdd x 3 1/8 5M prepped for 5 ½ extended neck hanger Optional 2 1/16 5M SSV for Velocity stringTubing head, Cactus, 11 5M x 7 1/16 5M, w/ 2- 2 1/16 5M SSO, 9 ½ BG bottom 2 7/8 or 2 3/8 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. BCU 12A SHLBEAVERCREEK UNITS007N010WBCU Pad 43433Beaver Creek UnitBCU 12A660 ft Radius from SHL0 150 300FeetBCU 12A 660ft Radius BufferOil and Gas Unit BoundaryBCU Pad 3BCU Pad 1ABCU Pad 7BCU Pad 4BCU Pad 2BEAVER CREEK UNITBCU 12A SHL1 inch = 150 feetMap Date: 9/9/2021 1 Carlisle, Samantha J (CED) From:Jacob Flora <Jake.Flora@hilcorp.com> Sent:Thursday, September 9, 2021 11:04 AM To:McLellan, Bryan J (CED) Cc:Donna Ambruz Subject:RE: [EXTERNAL] BCU 12A (PTD 214-070) cement Attachments:BCU_12A_Well_660ftRadius_11x17_v01.pdf GoodMorningBryan, Ͳ Youarecorrect,itshouldbe53bblsforcementvolume(myrigsupervisorRobO’Nealcaughtthisalso) Ͳ CurrentlytherearenoSSSVsatBeaverCreek.Arielradiusmapattached.Thegateis~3milesfromthepadwith nopublicaccess. Ͳ Completiondetails: o runningcentralizersacrossthepayzonesinthe5Ͳ1/2”casingabovethe5”XO(~7200’–7564’) o I’mcurrentlysourcingaflushjointfloatshoeandfloatcollar.Floatcollartoberun1jointoffbottom.If unabletoobtaintheseweplanonstoppingthewiperdartdisplacementtoleave30’ofcementinthe bottomofthe3Ͳ1/2.Ourdeepesttargetis7775Ͳ7791’sotheclearancesarefairlytightandwewillbe settingthe3Ͳ1/2asclosetothecurrentTDaspossible.d Letmeknowifyouneedmoredetailonanything, Thanks, Jake From:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Sent:Wednesday,September8,20215:48PM To:JacobFlora<Jake.Flora@hilcorp.com> Subject:[EXTERNAL]BCU12A(PTD214Ͳ070)cement Jake, x Couldyoudoublecheckyourcementcalcs?UnlessI’mmissingsomething,Ithinkyouarepumpingtoomuchfor yourdesiredTOC. x DoesthiswellrequireaSSSV?Couldyousendmethe660’radiusaerialphoto? x Also,couldyousendmealistofcompletioncomponents,includingthefloatshoe? BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission 333W7thAve Anchorage,AK99501 Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 REC'EWED • STATE OF ALASKA JUL ;3 ZC1� • AL .A OIL AND GAS CONSERVATION COR SION GAS WELL OPEN FLOW POTENTIAL TEST REPOR pr, la Test: U Initial Li Annual U Special 1b.Type Test: U Stabilized Non Sta i PG.Itipoint ❑Constant Time ❑laochronal Q Other: Nodal Analysis 2.Operator Name: 5.Date Completed: 11.Permit to Drill Number: Hilcorp Alaska,LLC 9/3/2014 214-070 3.Address: 6.Date TD Reached: 12.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 7/8/2014 50-133-20530-01 4a.Location of Well(Governmental Section): 7.KB Elevation above MSL(feet): 13.Well Name and Number: Surface: 2024'FNL,481'FEL,Sec 33,T7N,R1 OW,SM,AK 167.5 Beaver Creek(BCU)12A Top of Productive Horizon: 8.Plug Back Depth(MD+TVD): 14.Field/Pool(s): 1900'FNL,796'FWL,Sec 34,T7N,R1OW,SM,AK 9,676'MD/9,454'ND Total Depth: 9.Total Depth(MD+ND): Beaver Creek/Sterling Gas Pool 1915 FNL,842'FWL,Sec 34,T7N,R1OW,SM,AK 9,800'MD/9,578'ND 4b.Location of Well(State Base Plane Coordinates NAD 27): 10.Land Use Permit: 15.Property Designation: Surface: x- 315325.75 y-2433191.53 Zone- 4 N/A FEDA028083 TPI: x- 316600.15 y-2433303.891 Zone- 4 16.Type of Completion(Describe): Total Depth: x- 316646.16 y-2433288.1 Zone- 4 5-1/2"Production String,Perforate 17.Casing Size Weight per foot,lb. I.D.in inches Set at ft. 19.Perforations: From To 5-1/2" 17 4.892 7,564 18.Tubing Size Weight per foot,lb. I.D.in inches Set at ft. Sterling B3 5,206'-5,211 N/A SCANNED 20.Packer set at ft: 21.GOR cf/bbl: 22.API Liquid Hydrocardbons: 23.Specific Gravity Flowing Fluid(G): N/A 0 N/A 0.57 24a.Producing through: 24b.Reservoir Temp: 24c.Reservoir Pressure 24d.Barometric Pressure(Pa): ❑Tubing Q Casing 105 F° 1,895 psia @ Datum NDSS psia 25.Length of Flow Channel(L): Vertical Depth(H): Gg: %CO2. %N2: %H2S: Prover: Meter Run: Taps: N/A N/A 0.57 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice psig Hw F° psig F° psig F° Hr. Size(in.) Size(in.) 1. X 1,005 1,005 60 24 2. X 3. X 4. X 5. X Basic Coefficient Flow Temp. Super Comp. Pressure Gravity Factor Rate of Flow No. (24-Hour) -1 wPmPm Factor F Factor Ql Mcfd Fb or Fp Ft 9 Fpv 1. 2,390 2. 3. . 4. 5. for Separator for Flowing Temperature No. PrT Tr z Gas Fluid Gg G 1 2. 3. Critical Pressure 4. Critical Temperature 5. I - , Form 10-421 Rev. 7/2009 ORIG110 NATLUED ON REVERSE SOD' -du •'Li 1 56115 Submit in Duplicate Pc Pc2 'f 1,895 Pf2 No. Pt Pt2 Pc2-Pt2 Pw Pw2 Pc2-Pw2 Ps Pse Pf2-Ps2 1. 1,005 1,629 2. 3. 4. 5. 25. AOF (Mcfd) 7,060 n 0.80 Remarks: The BCU 12A is a high water rate well('-960 BWPD @ 2.39 MMscf/d)that is on the verge of loading up.Attempts to choke this well back will result in non-steady state flow conditions(slugging)and poor FBHP calculation.For this reason,a static pressure was calculated and nodal analysis used to calculated both"n"and the"AOF"of the well. Please see attached for an export of the System Calculation(IPR&VLP)from the commercial nodal analysis program Prosper. I hereby certify that the foregoing is true and correct to the best of my knowledge. k Signed J Title Reservoir Engineer Date Z3-/`.- 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/ -I hwPm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= -dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas(air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas(14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet(ND) 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 ___ N N a F- i 0 F- 4. Fu , E .4 JJ TI N \1 N v � O a ❑ Ct O. m CZ f.) N 3 �U Q ti N CN r. i • r - p 0 C. 0 0 0 C. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C. C. C. In o 10 o VS o to o to o in o 1.11 o in o N o N o N o N o in o N o 1.0o in o in o in o in Os CO CO N N LO tO In ll1 f M M N N O O OA O. CO CO N N tO t0 1f1 1n K M M N N .+ .-4 H H .1 H .-/ H H N N rl N 1,21 N .21 H BCu12A_B3_Nodal Report Produced on 07/23/2015 - 07:47: 58 - File : 0:\Alaska\Fields\Beaver Creek\Regulatory\State AOF Testing\BCU 12A\BCU12A_B3_Nodal_1-14-15.0ut . SYSTEM SENSITIVITY ANALYSIS - Input Data . Top Node Pressure : 1005.00 (psig) water Gas Ratio : 401.00 (STB/MMscf) Condensate Gas Ratio : 0 (STB/MMscf) Surface Equipment Correlation : Beggs and Brill vertical Lift Correlation : Petroleum Experts 2 Solution Node : Bottom Node Rate Method : Automatic - Linear Left-Hand Intersection : DisAllow ########################################### # SYSTEM SENSITIVITY ANALYSIS - Results # ########################################### dP First Total Maximum Maximum Maximum Erosional Hydrate Maximum Liquid Gas Oil water Liquid VLP IPR Total dP dP dP Completion Total WellHead wellHead Node dP dP NoSlip Erosional C Grain Velocity Formation Turner Loading Rate Rate Rate Rate Pressure Pressure Skin Perforation Damage Completion Skin Skin Pressure Temperature Temperature Friction Gravity Velocity Velocity Factor Diameter Flag Flag Velocity Flag (MMscf/day) (STB/day) (STB/day) (STB/day) (psig) (psig) (psi) (psi) (psi) (psi) (psig) (deg F) (deg F) (psi) (psi) (ft/sec) (ft/sec) (inches) (ft/sec) 0.0070597 0 2.8 2.8 3207. 52 1894.33 0 0 0 0 0 0 1005.00 40.06 40.06 0.00019433 2202. 52 0.0082787 107.399 0.030833 0.0001 No Yes 7.583 Yes 0.37796 0 151.6 151.6 2670.14 1869.61 0 0 0 0 0 0 1005.00 43.12 43.12 0.037143 1665.10 0.45558 108.886 1.67359 0.0025412 No Yes 7.734 Yes 0.74885 0 300.3 300.3 1848.24 1835. 54 0 0 0 0 0 0 1005.00 46.18 46.18 5. 52 837.73 0.92485 110.455 3.34925 0.012672 No Yes 7.869 Yes 1.120 0 449.0 449.0 1699.46 1796.06 0 0 0 0 0 0 1005.00 49.24 49.24 6.92 687.54 1.396 110.966 5.03317 0.030004 No No 7.921 Yes 1.491 0 597.7 597.7 1670.06 1752.13 0 0 0 0 0 0 1005.00 52.24 52.24 8.02 657.05 1.876 111.446 6.73174 0.053806 No No 7.968 Yes 1.862 0 746.5 746.5 1649.57 1704.16 0 0 0 0 0 0 1005.00 55.14 55.14 9.50 635.06 2.362 111.893 8.44345 0.084808 No No 8.013 Yes 2.232 0 895.2 895.2 1634.52 1652.25 0 0 0 0 0 0 1005.00 57.89 57.89 11.22 618.30 2.854 112.306 10.1665 0.12265 No No 8.054 Yes 2.603 0 1043.9 1043.9 1623.14 1596.37 0 0 0 0 0 0 1005.00 60.45 60.45 13.11 605.03 3.352 112.684 11.8991 0.16781 No No 8.091 Yes Page 1 BCU 12A_B3_Nodal 2.974 0 1192.7 1192.7 1614.40 1536.35 0 0 0 0 0 0 1005.00 62.81 62.81 15.14 594.26 3.854 113.028 13.6396 0.2198 No No 8.125 Yes 3.345 0 1341.4 1341.4 1607.64 1471.91 0 0 0 0 0 0 1005.00 64.99 64.99 17.29 585.35 4.360 113.339 15.3868 0.27888 No No 8.156 Yes 3.716 0 1490.1 1490.1 1602.43 1402.61 0 0 0 0 0 0 1005.00 66.99 66.99 19.57 577.86 4.868 113.621 17.1394 0.34528 No No 8.183 Yes 4.087 0 1638.9 1638.9 1598.45 1327.87 0 0 0 0 0 0 1005.00 68.82 68.82 21.96 571.50 5.380 113.876 18.8966 0.41852 No No 8.208 Yes 4.458 0 1787.6 1787.6 1595.49 1246.86 0 0 0 0 0 0 1005.00 70. 51 70. 51 24.45 566.04 5.893 114.109 20.6576 0.49859 No No 8.231 Yes 4.829 0 1936.3 1936.3 1593.37 1158.39 0 0 0 0 0 0 1005.00 72.06 72.06 27.05 561.32 6.408 114.320 22.4218 0. 58549 No No 8.252 Yes 5.200 0 2085.0 2085.0 1591.96 1060.77 0 0 0 0 0 0 1005.00 73.48 73.48 29.74 557.22 6.925 114. 512 24.1888 0.67923 No No 8.270 Yes 5. 570 0 2233.8 2233.8 1591.16 951.32 0 0 0 0 0 0 1005.00 74.80 74.80 32. 53 553.63 7.443 114.689 25.9581 0.77981 No No 8.287 Yes 5.941 0 2382. 5 2382. 5 1590.89 825.56 0 0 0 0 0 0 1005.00 76.01 76.01 35.40 550.49 7.962 114.850 27.7293 0.88722 No No 8.303 Yes 6.312 0 2531.2 2531.2 1591.09 674.74 0 0 0 0 0 0 1005.00 77.14 77.14 38.37 547.73 8.482 114.998 29. 5023 1.00000 No No 8.318 Yes 6.683 0 2680.0 2680.0 1591.71 476.45 0 0 0 0 0 0 1005.00 78.19 78.19 41.42 545.29 9.003 115.135 31.2767 1.00000 No No 8.331 No 7.054 0 2828.7 2828.7 1592.69 47.65 0 0 0 0 0 0 1005.00 79.16 79.16 44.55 543.14 9.524 115.261 33.0523 1.00000 No No 8.343 No . Solution Point . Gas Rate : 2.380 (MMscf/day) Oil Rate : 0 (STB/day) Water Rate : 954. 5 (STB/day) Liquid Rate : 954. 5 (STB/day) Solution Node Pressure : 1629.98 (psig) dP Friction : 11.97 (psi) dP Gravity : 613.01 (psi) dP Total Skin : 0 (psi) dP Perforation : 0 (psi) dP Damage : 0 (psi) dP Completion : 0 (psi) Completion Skin : 0 Total Skin : 0 Wellhead Liquid Density : 62.430 (lb/ft3) wellhead Gas Density : 3.462 (lb/ft3) Wellhead Liquid viscosity : 1.0785 (centipoise) Wellhead Gas viscosity : 0.012691 (centipoise) Wellhead Superficial Liquid velocity : 0.47401 (ft/sec) Wellhead superficial Gas velocity : 2.604 (ft/sec) wellhead Z Factor : 0.85664 wellhead Interfacial Tension : (dyne/cm) wellhead Pressure : 1005.00 (psig) Page 2 BCu12A_B3_Nodal wellhead Temperature : 58.91 (deg F) First Node Liquid Density : 62.430 (lb/ft3) First Node Gas Density : 3.462 (lb/ft3) First Node Liquid viscosity : 1.0785 (centipoise) First Node Gas viscosity : 0.012691 (centipoise) First Node Superficial Liquid velocity : 0.47401 (ft/sec) First Node Superficial Gas velocity : 2.604 (ft/sec) First Node z Factor : 0.85664 First Node Interfacial Tension : (dyne/cm) First Node Pressure : 1005.00 (psig) First Node Temperature : 58.91 (deg F) Page 3 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. cC J 14_ - 0 070 Well History Ile Identifier Organizing (done) wo-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: '5 for Items: ❑ Mas: Grayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: , BY: 71:). Maria Date: C(cIS /s/ u Project Proofing 7/a/icyvfBY: Maria Date: /s/ ...._.___ Scanning Preparation5 x 30 = ISD + j = TOTAL PAGES / 5 I (Count does not include cover sheet) a BY: Maria Date: • g 5' /s/ Production Scanning Stage 1 Page Count from Scanned File: / 61 (Count does include cove eet) Page Count Matches Number in Scanning Preparation: YES NO BY: 42) Date: r7 a g r- lsl ivif Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: `/s/ Stage 2 Additional Well Reports: 0 NO TOTAL PAGES' J Digital version appended by: Meredith Michal Date: 7/31, (,(,s" /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: /70 Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc 0 v, • E C. 1 9 W W N O r X M o _ • • < < a) >. 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N .1- ,— I— I— O • Z N CO • Cr) 111 Y N- M0 U) > oco0 ii QW ° r m a) Q ° a Z o G E U m 2 m v v • ao 0 0 n N N 10 0)) M - h. o o m ti c ~ 1 -co a) Na) N f0 re 'C 0 u, C G o c C13 O iii c0) .. .°. co oa c C , E d h a f0 o E (13 ci) E E a 2 v a C.) 0 STATE OF ALASKA RECEIVED ALA _OIL AND GAS CONSERVATION COMMIT. iN REPORT OF SUNDRY WELL OPERATIONS JAN 12 2015 1.Operations Abandon U Repair Well LJ Plug Perforations Lf Perforate Lf OtherL4cGCC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension v�..1 Change Approved Program ❑ Operat.Shutdown 0 Stimulate-Other 0 Re-enter Suspended Well 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑., Exploratory ❑ 214-070 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20530-01 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)12A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Sterling Gas Pool 11.Present Well Condition Summary: 7,820; 7,914;8,125; Total Depth measured 9,800 feet Plugs measured 8,360'8,475 feet true vertical 9,578 feet Junk measured N/A feet Effective Depth measured 9,676 feet Packer measured N/A feet true vertical 9,454 feet true vertical N/A feet Casing Length Size MD ND Burst Collapse Structural Conductor 103' 20" 103' 103' 3,060 psi 1,500 psi Surface 2,087' 13-3/8" 2,087' 2,087' 3,450 psi 1,950 psi Intermediate 4,765' 9-5/8" 4,765' 4,673' 5,750 psi 3,090 psi Production 9,760' 5-1/2"X 5" 9,760' 9,538' 10,640 psi 7,460 psi Liner 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) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 300 10 Subsequent to operation: 0 5430 0 800 1610 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas E WDSPL❑ GSTOR p WINJ 0 WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-671 Contact Stan Porhola Email sporholatahilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature . A rt�c__ Phone 907-777-8412 Date VI L/I 5 RBDMS ( JAN 1 3 2015 1.246pc Form 10-404 Revised 1012012 ;1- 00(5---- Submit Original Only Hilcorp Alaska, LLC Weekly Operations Summary 11 Well Name API Number Well Permit Number Start Date End Date BCU-12A 50-133-20530-01 214-070 1/2/15 1/7/15 Daily Operations: 01/02/2015 - Friday Held PJSM and obtained permit. MIRU Priority E-line. Spot equipment, MU lubricator and tool string w/5.5" CIBP. Stab on well. PT lubricator to 250 psi low/3,000 psi high. Good test. RIH w/5.5" CIBP and correlate to SLB RST log dated 7/21/14 from 5,400'-4,950'. Saw fluid level 3,600'. Send in correlation log for verification. Set CIBP @ 5,250' RKB (5,257' ELM) and confirm set w/tag. Good set. POOH w/setting tool. LD lubricator and setting tool. Secure well and RD Priority. 01/05/2015 - Monday Obtain PTW. Hold safety meeting and JSA. MIRU SLB CTU 12. Rig up 1.75 in CT. ASRC crane arrived at 10:00 hrs. Start BOP test. Valves and rams 250 low/4,500 psi high. State notification witness waived by Jim Regg, AOGCC. Fuel equipment. Secure location. Confirmed by walk around that all ground valves are closed. 01/06/2015 -Tuesday Obtain PTW. Hold safety meeting and discuss job procedures/steps and best practices. Fuel equipment. Fire equipment. Plck injector head/10ft stick of lubricator/ make up tools. 2in CT connector/2in Dual Flapper check valve/2in x 4ft stinger x 2/2in Ball drop nozzle. Injector head on well. Fluid pack to tank. Close in and test stack. Low pt 250 psi/ high pt 4,500 psi. Blow back Iron and change out 1502 chiksan. Fluid pack and re test. Hold low pt and high for 5 minutes. Good test. Open well and RIH. Initial WHP was 550 psi. RIH with coil/crack open choke to bleed off whp. Cooling down n2 at 11:00 hrs. Online with n2 at 1,500 scf/min. Tag CIBP at 5,239 Ft CTMD . Returns to surface. Previous wire line saw fluid at 3,600 ft. Pumping n2 at 1,800 scf/min. Well dry. Begin POOH. Choke closed while POOH. Isolate CT and pump n2 down CTxcasing annulus to pressure up well to 1,000 psi. Currently 568 psi on WH. Offline with n2. 1,000 psi on Wellhead. Continue POOH. At surface. Close in wellhead with 1,032 psi. Total N2 pumped. 128,000 scf or 1,375 Gallons. Bleed off coil and check for no flow. Pop off well. Break down tools. Stack lubricator. Set injector head on back deck of CT unit. CT 12 rigged down and moving equipment to BCU 2. 01/07/2015-Wednesday Obtain permit and held PJSM. RU Schlumberger E-line. MU lubricator and tool string, stab on well. PT lubricator to 250 psi low/3,000 psi high -tighten hammer union, good test. MU 3-1/8" x 5'gun. RIH w/5'gun and correlate to SLB RST dated 7/21/14. Verify correlation. Bleed pressure from 1,085 psi to 1,000 psi. Perforate Sterling B3 sands 5,206'-5,211' RKB (5,199'-5,204' WLM)w/3-1/8" PJN 6 SPF 60 deg HC guns. Positive indication of firing, pressure built from 1,000 psi to 1,600 psi in 2 min. POOH. OOH - guns swollen. LD spent guns and lubricator. RD SLB. BCU - 12A ACTUAL Pad 4 2,023 FNL, 482'FEL, SCHEMATIC Sec.33, T7N, R10W, S.M. Ilile•oi'p Alaska. LAA: Permit#: 214-070 9. 20"Conductor K-55 133 ppf API#: 50-133-20530-01 Top Bottom Prop.Des: FED A-028083 j j 11: MD 0' 103' KB elevation: 167.5' (17.5'AGL) ND 0' 103' Let: N60° 39' 22.118" Long: W151° 1' 45.593" Spud: 6/29/2014 12:00 hrs Surface Casing TD: 7/07/2014 07:00 hrs 13-318" K-55 68 ppf BTC Rig Released: 7/13/2014 6:00 hrs T� Bo0' om MD2,087' ND 0' 2,087' 1 16"hole Cmt w/600 sks(271 bbl)of 12.0 ppg, Tree cxn=9-1/2"Otis Type 1 cmt, 18 sks(8 bbls)to surface 8.0"Seal Diameter 5-1/8"Modified ID Bore Intermediate Casing 9-5/8" L-80 40 ppf BTC TOC(USIT 7/21/14)-4,375' Lap Bottom I Mkr Jt 4,967' MD 0' 4,765' ND 0' 4,673' 12-1/4"hole Lead Cmt w/833 sks(341 bbls)of 12.5 ppg,Class G, Tail Cmt w/327 sks(106 bbls) Sterling B3 of 13.5 ppg,Class G, 12 sks(5 bbls)to surface CIBP @ 5,264'RKB , Production Casing Sterling B3L 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom Mkr Jt 5,325' MD 0' 7,564' ND 0' 7,348' 5" L-80 18 ppf DWC/C-HT Top Bottom MD 7,564' 9,760' ND 7,348' 9,538' 8-1/2"hole Cmt w/1030 sks(248 bbls)of 15.3 ppg, Mkr Jt 6,094' Class G cmt w/EASYBLOK Casing/Cementing Detail Mud Cap w/35'of Cement - 10.5 ppg Mud Push(38 bbl) 26 gal of cement - 15.3 ppg Cement(248 bbl) Mkr Jt 6,235' - 8.4 ppg Fresh Water(215 bbl) XO Jt 7,564' 2 LB-22 Perforations: 3 Zone MD ND Size SPF Date Status LB-23 - Sterling B3 5,206'-5,211' 5,089'-5,093' 3-1/8"6 1/07/15 Open LB-24 Sterling B3L 5,279'-5,299' 5,158'5,177' 3-1/8"6 12/09/14 Isolated LB-24 IRA MkrJt8,054' LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-26A LB-23 7,926-7,941' 7,706-7,720' 2-7/8" 6 9/03/14 Isolated 4 LB-24 8,015'-8,028' 7,794-7,807' 2-7/8" 6 9/03/14 Isolated LB-27 - - -- -11" LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 9/03/14 Isolated LB-28 - LB-26A 8,107-8,117' 7,886-7,896' 2-7/8" 6 9/03/14 Isolated Jewelry Death LB-28 = 5 LB-27 8,135'-8,155' 7,914-7,934' 2-7/8" 6 8/20/14 Isolated 1.Swell Packer(21'Long) 4,209' LB_P9 LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 8/20/14 Isolated 2.CIBP(Set 11/18/14)Capped w/35'of cmt 7,820' LB-29 - == LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 8/20/14 Isolated 3.CIBP(Set 11/02/14) 7,914' LB-29B -_ s LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 8/04/14 Isolated 4.CIBP(Set 8/21/14) 8,125' LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 8/04/14 Isolated LB-29B 5.CIBP(Set 8/09/14) 8,360' 6 LB-29B 8,435'-8,450' 8,214-8,229' 2-7/8" 6 8/04/14 Isolated 6.CIBP(Set 8/02/14) 8,475' LB-30 - '.= LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 8/04/14 Isolated LB-30 ERA Mkr Jt 8,500' LB-30 8,480'-8,490' 8,256-8,269' 2-7/8" 6 7/30/14 Isolated LB-30 8,495'-8,510' 8,274-8,289' 2-7/8" 6 7/30/14 Isolated LB-31 LB-31 8,546-8,553' 8,322'-8,332' 2-7/8" 6 7/30/14 Isolated LB-31 •;" /: Casing Shoe @ 9,760' Tag(unset cement)@ 9,464'SLM Open hole Max Dogleg: w/3.84"GR(7/16/14) Casing 40'off bottom 4.42°/100'@ 8,004' TD: PBTD: 9,800'MD 9,676'MD Max Inclination: 9,578'ND 9,454 ND 20.3°@ 5,027' Well Name&Number: Beaver Creek Unit#12A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska _ Country:IUSA Angle @KOP and Depth. 19.2°@ 4,769' Angle/Perfs,I N/A Maximum Deviation 20.3°@ 5,027' Date Completed: 7/12/2014 Ground Level(above MSL). 150.0' RKB(above GL):. 17.5' Revised By: Stan Porhola Downhole Revision Date. 1/7/2015 Schematic Revision Date. 1/8/2015 2\4- 010 pF k1t T + ��\\\� THE STATE Alaska Oil and Gas OfALASI(:A Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ' \TM. Main: 907.279.1433 ALAS— Fax: 907.276 7542 www aogcc.alaska.gov Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Sterling Gas Pool, BCU 12A Sundry Number: 314-671 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this) q day of December, 2014. Encl. RECEIVED w STATE OF ALASKA DEC 16 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION 0(1� �►� APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril El Perforate New Pod❑ Repair Well El Change Approved Program❑ Suspend El Plug Perforations Q Perforate[] Pull Tubing❑ Time Extension El Operations Shutdowl❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other:❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development 2 • 214-070 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20530-01 - 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 237A Beaver Creek(BCU)12A Will planned perforations require a spacing exception? Yes ❑ No ❑., 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083• Beaver Creek/Sterling Gas Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9,800 • 9,578 • 9,676 9,454 7,820/7,914/8,125/8,360/8,475 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 103' 20" 103' 103' 3,060 psi 1,500 psi Surface 2,087' 13-3/8" 2,087' 2,087' 3,450 psi 1,950 psi Intermediate 4,765' 9-5/8" 4,765' 4,673 5,750 psi 3,090 psi Production 9,760' 5-1/2"x 5" 9,760' 9,538' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth ND(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(t)and ND(R): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphic El Development n Service n 14.Estimated Date for 15.Well Status after proposed work: 12/22/14 Commencing Operations: Oil ❑ Gas ❑✓ WDSPL ❑ Suspended El 16.Verbal Approval: Date: WINJ El GINJ El WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Pothole Phone: 907-777-8412 Email soorholaOhilcorD.com Printed Name Stan Porhola Title Operations Engineer / Signature !DPhone 907-777-8412 Date 1L�3/A( COMMISSION USE ONLY ((( Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3<<{— 62-1L Plug Integrity El BOP Test El Mechanical Integrity Test El Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: /G —4/C.(f APPROVEDMM S �L I ,I I 1 Approved by: COMMISSIONER THE COMMISSION Date: / ` ti-- /Z-11) A ' A �J A N Pp4 2515 Submrt Form and Form 10-403(Revised /2012r d itI sAit� o.r 1 ate of approval. �,� Attach is in Duplicate v L ,0 -/P- eC,4 z /6- '1 /I , , ,.. Well Prognosis Well: BCU-12A Hi[cora Alaska,LI) Date: 12/15/2014 Well Name: ' BCU-12A API Number: 50-133-20530-01 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: December 22nd, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-070 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228(M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1423513 Current Bottom Hole Pressure: — 1,410 psi @ 5,158' TVD (Based on SITP and Fluid Level) Maximum Expected BHP: —2,100 psi @ 5,089' TVD (Based on offset wells of Sterling) Max. Allowable Surface Pressure: — 1,591 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#12 was drilled as a Grass roots EXCAPE monobore completion in 2004 to target gas sands in the lower Beluga formation.All 12 EXCAPE modules were perforated and fracture stimulated.A capillary string ' was installed to deliver foamer to alleviate liquid loading in 2009.The capillary string was pulled in Sep 2010 but a fish was left in the well.The capillary string was re-ran to a shallower depth in Oct 2010.The capillary string was pulled in Feb 2014 and soap sticks have been dropped in place of the foamer. The well was sidetracked with Saxon#169 as Beaver Creek Unit#12A and the 5-1/2"x5" production longstring was cemented in mid July 2014.The first 4 perforated intervals were perforated at the end of July and were shown to be non- productive.The next set of 4 perforated intervals were perforated at the beginning of August and were shown to be non-productive.The next set of 3 perforated intervals were perforated in the middle of August and were shown to be non-productive.The next set of 4 perforated intervals were perforated at the beginning of September and produced gas with water briefly before watering out at the end of September 2014.The next interval (LB-22)was perforated in November 2014 and found to be non-productive. Bridge plugs have been placed between these intervals with the last plug set above the LB-22. Cement was dumped on that plug and the well was perforated in the Sterling in December 2014. The purpose of this work/sundry is to plugback the Sterling B3L and add perforations in the Sterling. Notes Regarding Wellbore Condition • Will swab down fluid level with slickline and apply N2 or jet dry with N2 before RU E-line. • Well will be displaced with Nitrogen before initial perforating at+/- 1,000 psi SITP. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 1,000 psi (Nitrogen pressure). 2. RIH and set 5-1/2" CIBP at 5,250'. 3. RU 3-1/8" 6 spf Connex HC wireline guns. 4. RIH and perforate the following intervals: Well Prognosis Well: BCU-12A Hilcorp Alaska,Lb Date: 12/15/2014 Zone Sands Top (MD) Btm (MD) FT SPF Sterling B3 5,206' 5,211' 5' 6 a. Bleed tubing pressure to 1,000 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using SLB Cement USIT Log(dated 7/21/14) (Tie-in log). e. Use Gamma/CCL/to correlate. f. Record tubing pressures before and after each perforating run. g. Spacing allowance is based on CO 237A, no restrictions in Sterling Gas Pool. 5. RD E-line. 6. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic • BCU - 12A ACTUAL Pad 4 2,023 FNL, 482'FEL, SCHEMATIC Sec.33, T7N, R10W, S.M. IIilvorp Alaska.LI.0 _. --- Conductor Permit#: 214-070 20" K-55 133 ppf API#: 50-133-20530-01Top Bottom Prop.Des: FED A-028083LL MD 0' 103' Al KB elevation: 167.5' (17.5'AGL) TVD 0' 103' Lat: N60° 39' 22.118" Long: W1 51° 1' 45.593" Spud: 6/29/2014 12:00 hrs Surface Casing TD: 7/07/2014 07:00 hrs 13-3/8" K-55 68 ppf BTC "Ipa Bottom Rio Released: 7/13/2014 6:00 hrs MD 0' 2,087' _ ND 0' 2,087'L.__ 1 16"hole Cmt w/600 sks(271 bbl)of 12.0 ppg, Tree cxn=9-1/2"Otis Type 1 cmt, 18 sks(8 bbls)to surface 8.0"Seal Diameter 5.118"Modified ID Bore Intermediate Casing 9-5/8" L-80 40 ppf BTC TOC(USIT 7/21/14)-4,375' 'op Bottom I I Mkr Jt 4,967' MD 0' 4,765' ND 0' 4,673' 12-1/4"hole Lead Cmt wl 833 sks(341 bbls)of 12.5 ppg,Class G, Tail Cmt w/327 sks(106 bbls) of 13.5 ppg,Class G, 12 sks(5 bbls)to surface . Production Casinq Sterling B3L = 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom Mkr Jt 5,325' MD 0' 7,564' ND 0' 7,348' • 5" L-80 18 ppf DWC/C-HT • Top Bottom MD 7,564' 9,760' ND 7,348' 9,538' ' Mkr Jt 6,094' 8-1/2"hole Cmt w/1030 sks(248 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK Casing/Cementing Detail - 9.4 ppg Mud Cap w/35'of Cement - 10.5 ppg Mud Push(38 bbl) 26al of cement 9 - 15.3 ppg Cement(248 bbl) Mkr Jt 6,235' - 8.4 ppg Fresh Water(215 bbl) , XO Jt 7,564' 2 LB-22 Perforations: 3 Zone MD TVD Size SPF Date Status LB-23 Sterling B3L 5,279'-5,299' 5,158'-5,177' 3-1/8"6 12/09/14 Open LB-24= LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-24 i Mkr Jt 8,054' LB-23 7,923-7,941' 7,706-7,720' 2-7/8" 6 9/03/14 Isolated LB-26ALB-24 8,015-8,028' 7,794'-7,807' 2-7/8" 6 9/03/14 Isolated _ 4 LB-24 8,031'-8,050' 7,813-7,829' 2-7/8" 6 9/03/14 Isolated LB-27 = LB-26A 8,107'-8,117' 7,886-7,896' 2-7/8" 6 9/03/14 Isolated LB-28 = LB-27 8,135-8,155' 7,914'-7,934' 2-7/8" 6 8/20/14 Isolated Jewelry Depth LB-28 LB-28 8,262'-8,292' 8,041'-8,071 2-7/8" 6 8/20/14 Isolated 1.Swell Packer(21'Long) 4,209' LB_29 LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 8/20/14 Isolated 2.CIBP(Set 11/18/14)Capped w/35'of cmt 7,820' LB-29 - LB-29 8,374'-8,384' 8,153-8,163' 2-7/8" 6 8/04/14 Isolated 3.CIBP(Set 11/02/14) 7,914' LB-296 T LB-29 8,393-8,403' 8,172'-8,182' 2-7/8" 6 8/04/14 Isolated 4.CIBP(Set 8/21/14) 8,125' = LB-29B 8,435-8,450' 8,214'-8,229' 2-7/8" 6 8/04/14 Isolated 5.CIBP(Set 8/09/14) 8,360' LB-29B LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 8/04/14 Isolated 6,CIBP(Set 8/02/14) 8,475' LB-30 = ''- - 6 LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 7/30/14 Isolated LB-30 a Z2A Mkr Jt 8,500' LB-30 8,495-8,510' 8,274'-8,289' 2-7/8" 6 7/30/14 Isolated S LB-31 8,543-8,553' 8,322'-8,332' 2-7/8" 6 7/30/14 Isolated LB-31 LB-31 8,603-8,610' 8,373-8,389' 2-7/8" 6 7/30/14 Isolated LB-31 7 -.. Casing Shoe @ 9,760' Tag(unset cement)@ 9,464'SLM Open hole Max Dogleg: w/3.84"GR(7/16/14) Casing 40'off bottom 4.42°/100'@ 8,004' TD: PBTD: 9,800'MD 9,676'MD Max Inclination: 9,578'TVD 9,454'ND 20.3°@ 5,027' Well Name&Number. Beaver Creek Unit#12A Lease:_ A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth. 19.2°@ 4,769' Angle/Perfs.I N/A Maximum Deviation 20.3°@ 5,027' Date Completed: 7/12/2014 _ Ground Level(above MSL)._ 150.0' RKB(above GL). 17.5' Revised By Stan Porhola Downhole Revision Date. 12/9/2014 Schematic Revision Date: 12/15/2014 . • BCU - 12A PROPOSED Pad 4 2,023 FNL, 482'FEL, SCHEMATIC Sec.33, T7N, R10W, S.M. IIilc•orp_alaska. I.LC Permit#: 214-070 Conductor API#: 50-133-20530-01 20" K-55 133 ppf Top Bottom Prop.Des: FED A-028083 MD 0' 103' KB elevation: 167.5' (17.5'AGL) ND 0' 103' Lat: N60° 39' 22.118" Long: W151" 1' 45.593" Spud: 6/29/2014 12:00 hrs Surface Casing TD: 7/07/2014 07:00 hrs 13-3/8" K-55 68 ppf BTC Rio Released: 7/13/2014 6:00 hrs T� Bottom MD 0' 2,087' ND 0' 2,087' 1 16"hole Cmt w/600 sks(271 bbl)of 12.0 ppg, Tree cxn=9-1/2"Otis Type 1 cmt, 18 sks(8 bbls)to surface 8.0"Seal Diameter 5-1/8"Modified ID Bore ' Intermediate Casing 40 pf TOC(USIT 7/21/14)-4,375' 9-5/8 Top Bottom BTC Mkr Jt 4,967' MD 0' 4,765' ND 0' 4,673' 12-1/4"hole Lead Cmt w/833 sks(341 bbls)of 12.5 ppg,Class G, Tail Cmt w/327 sks(106 bbls) • Sterling B3 _ of 13.5 ppg,Class G, 12 sks(5 bbls)to surface CIBP @ 5,250' Production Casing Sterling B3L 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom Mkr Jt 5,325' MD 0' 7,564' ND 0' 7,348' 5" L-80 18 ppf DWC/C-HT • Top Bottom • MD 7,564' 9,760' • ND 7,348' 9,538' 8-1/2"hole Cmt w/1030 sks(248 bbls)of 15.3 ppg, Mkr Jt 6,094' Class G cmt w/EASYBLOK Casing/Cementing Detail 9.4 Cap w/35'of Cement - 10..ppg Mud - 105 ppg Mud Push(38 bbl) 26al of cement g - 15.3 ppg Cement(248 bbl) Mkr Jt 6,235' - 8.4 ppg Fresh Water(215 bbl) XO Jt 7,564' g-- _ 2 LB-22 = Perforations: p,, y - 3 Zone MD ND Size SPF Date Status LB-23= Sterling B3 5,206'-5,211' 5,089'-5,093' 3-1/8" 6 Proposed LB-24 Sterling B3L 5,279'-5,299' 5,158'-5,177' 3-1/8"6 12/09/14 Open LB-24 AMkrJt8,054' LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-26A LB-23 7,929'-7,941' 7,705-7,720' 2-7/8" 6 9/03/14 Isolated 4 LB-24 8,015-8,028' 7,794'-7,807' 2-7/8" 6 9/03/14 Isolated LB-27 LB-24 8,031'-8,050' 7,815-7,829' 2-7/8" 6 9/03/14 Isolated LB-28 LB-26A 8,107'-8,117' 7,886-7,896' 2-7/8" 6 9/03/14 Isolated LB-28 s Jewelry Death. LB-27 8,135-8,155' 7,914'-7,934' 2-7/8" 6 8/20/14 Isolated 1.Swell Packer(21'Long) 4,209' LB-29 5 LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 8/20/14 Isolated 2.CIBP(Set 11/18/14)Capped w/35'of cmt 7,820' LB-29 = LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 8/20/14 Isolated 3.CIBP(Set 11/02/14) 7,914' LB-29B • LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 8/04/14 Isolated 4.CIBP(Set 8/21/14) 8,125' LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 8/04/14 Isolated LB-29B 5.CIBP(Set 8/09/14) 8,360' LB-29B 8,435-8,450' 8,214'-8,229' 2-7/8" 6 8/04/14 Isolated 6.CIBP(Set 8/02/14) 8,475' LB-30 = -= 6 LB-29B 8,460-8,470' 8,239'-8,249' 2-7/8" 6 8/04/14 Isolated LB-30 a ZAMkr Jt8,500' LB-30 8,485-8,490' 8,259'-8,269' 2-7/8" 6 7/30/14 Isolated LB-30 8,495'-8,510' 8,274'-8,289' 2-7/8" 6 7/30/14 Isolated LB-31 = LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 7/30/14 Isolated LB-31 Area,}Yrnii Casing Shoe @ 9,760' • Tag(unset cement)@ 9,464'SLM Openhole Max Do le w/3.84"GR(7/16/14) Casing 40'off bottom 4.42'/100'@ 8,004' TD: PBTD: 9,800'MD 9,676'MD Max Inclination: 9,578'ND 9,454'ND 20.3°@ 5,027' Well Name&Number: Beaver Creek Unit#12A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth: 19.2°@ 4,769' Angle/Perfs:I N/A Maximum Deviation:_ 20.3°@ 5,027' Date Completed: 7/12/2014 Ground Level(above MSL):_ 150.0' RKB(above GL): 17.5' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 12/15/2014 ' STATE OF ALASKA RECEIVED AL A OIL AND GAS CONSERVATION COMM.__.ON DEC 16 2014 REPORT OF SUNDRY WELL OPERATIONS �),/'� (/�� 1.Operations Abandon U Repair Well L Plug Perforations U Perforate U Other Li A()GCC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown E Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory D 214-070 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20530-01 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)12A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Sterling Gas Pool 11.Present Well Condition Summary: 7,820; 7,914;8,125; Total Depth measured 9,800 feet Plugs measured 8,360'8,475 feet true vertical 9,578 feet Junk measured N/A feet Effective Depth measured 9,676 feet Packer measured N/A feet true vertical 9,454 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 103' 20" 103' 103' 3,060 psi 1,500 psi Surface 2,087' 13-3/8" 2,087' 2,087' 3,450 psi 1,950 psi Intermediate 4,765' 9-5/8" 4,765' 4,673' 5,750 psi 3,090 psi Production 9,760' 5-1/2"X 5" 9,760' 9,538' 10,640 psi 7,460 psi Liner 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) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 490 1784 Subsequent to operation: 0 0 0 340 226 • 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development[] Service ❑ Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas El WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-633 Contact Stan Porhola Email sporhoIacS�l.hiIcorp.com Printed Name Stan Porhola Title Operations Engineer Signature 44- r Phone 907-777-8412 Date 1.215//V- el' 2IIS /V- Y,t< RBC MS DEC 16 26 Form 10-404 Revised 10/2012 /�� Submit Original Only Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-12A 50-133-20530-01 214-070 12/9/14 12/9/14 Daily Operations: 12/09/2014-Tuesday PTW and JSA. Mobe to location and spot equipment. Rig up lubricator and PT to 250 psi low and 3,000 psi high.TP-1,050 psi. MU and RIH w/3" x 30' dump bailer loaded with cement and tag plus at 7,820'. Pick up 10' and dump cement. Make 2 more runs with bailer which puts 35' cement on top of plug (26 gals). Fluid level was looking like around 6,500'. Had one misrun due to bad detonator. RIH with GPT tool and found fluid level at 6,488'. RIH with 3-3/813-1/8" charges) x 20' Connex HC, 6 spf, 60 deg phase and tied into SLB RST log dated 21-Jul-14. After tieing into RST log we dropped the log down 7'to match open hole log. Sent correlation log to town and got ok.Spotted shot from 5,279'to 5,299'.TP was 1,000 psi. Fired gun and TP went to 1,050 psi in 2 min, 1,060 psi in 4 min and 1,100 psi in 8 min. POOH and TP 1,150 psi. RIH with GPT tool and found fluid level at 5,450'. POOH. Rig down lubricator and turn well over to field. r BCU - 12A ACTUAL Pad 4 2,023 FNL, 482'FEL, SCHEMATIC Sec. 33, T7N, R10W, S.M. 1111(•nrp Alaska. IAA: Permit#: 214-070 Conductor 20" K-55 133 ppf API#: 50-133-20530-01 Top Bottom Prop.Des: FED A-028083LL MD 0' 103' I] KB elevation: 167.5' (17.5'AGL) TVD 0' 103' Lat: N60° 39' 22.118" Long: W151° 1' 45.593" Spud: 6/29/2014 12:00 hrs Surface Casing 13-3/8" K-55 68 ppf BTC TD: 7/07/2014 07:00 hrs T Rio Released: 7/13/2014 6:00 hrs MD 0' Bottom,087 ' _ TVD 0' 2,087' 1 16"hole Cmt w/600 sks(271 bbl)of 12.0 ppg, Tree cxn=9-1/2"Otis Type 1 cmt, 18 sks(8 bbls)to surface 8.0"Seal Diameter 5-1/8"Modified ID Bore ----- '' Intermediate Casing 9-5/8" L-80 40 ppf BTC TOC(USIT 7/21/14)-4,375' T� Bottom 'Mkr Jt 4,967' MD 0' 4,765' ND 0' 4,673' 12-1/4"hole Lead Cmt wl 833 sks(341 bbls)of 12.5 ppg,Class G, Tail Cmt wl 327 sks(106 bbls) of 13.5 ppg,Class G, 12 sks(5 bbls)to surface . Production Casing Sterling B3L 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom ' 'Mkr Jt 5,325' MD 0' 7,564' TVD 0' 7,348' 5" L-80 18 ppf DWC/C-HT • Top Bottom MD 7,564' 9,760' TVD 7,348' 9,538' ' 'Mkr Jt 6,094' 8-1/2"hole Cmt w/1030 sks(248 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK Casing/Cementing Detail - 9.4 ppg Mud Cap w/35'of Cement - 10.5 ppg Mud Push(38 bbl) 26 gal of cement - 15.3 ppg Cement(248 bbl) IMkr Jt 6,235' - 8.4 ppg Fresh Water(215 bbl) XO Jt 7,564' 2 LB-22 Perforations: - 3 ' Zone MD TVD Size SPF Date Status LB-23 - -" - • Sterling B3L 5,279-5,299 5,158'-5,177' 3-1/8"6 12/09/14 Open LB-24= LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Isolated LB-24 3 DA MkrJt 8,054' LB-23 7,926-7,941' 7,706-7,720' 2-7/8" 6 9/03/14 Isolated LB-26A LB-24 8,015-8,028' 7,794'-7,807' 2-7/8" 6 9/03/14 Isolated 4 LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 9/03/14 Isolated LB-27 LB-26A 8,107'-8,117' 7,886-7,896' 2-7/8" 6 9/03/14 Isolated LB-28 = - LB-27 8,135-8,155' 7,914'-7,934' 2-7/8" 6 8/20/14 Isolated Jewelry Depth LB-28 = = LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 8/20/14 Isolated 1.Swell Packer(21'Long) 4,209' LB-Y9 • + 5 LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 8/20/14 Isolated 2.CIBP(Set 11/18/14)Capped w!35'of cmt 7,820' LB-29 = LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 8/04/14 Isolated 3.CIBP(Set 11/02/14) 7,914' LB-29B s LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 8/04/14 Isolated 4.CIBP(Set 8/21/14) 8,125' LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 8/04/14 Isolated LB-29B- = LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 8/04/14 Isolated 5.CIBP(Set 8/09/14) 8,360' - 6.CIBP(Set 8/02/14) 8,475' LB-30 6 r LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 7/30/14 Isolated LB-30 ��A MkrJt 8,500' LB-30 8,495'-8,510' 8,274'-8,289' 2-7/8" 6 7/30/14 Isolated LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 7/30/14 Isolated LB-31 = = LB-31 8,600'-8,610' 8,379'-8,389' 2-7/8" 6 7/30/14 Isolated LB-31 = I } 77.70,11r61 Casing Shoe @ 9,760' Tag(unset cement)@ 9,464'SLM Openhole Max Dogleg: w/3.84"GR(7/16/14) Casing 40'off bottom 4.42°/100'@ 8,004' TD: PBTD: Max Inclination: 9,800'MD 9,676'MD 9,578'TVD 9,454'ND 20.3°@ 5,027' Well Name&Number:_ Beaver Creek Unit#12A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth. 19.2°@ 4,769' Angle/Perfs.I N/A Maximum Deviation: 20.3°@ 5,027' Date Completed: 7/12/2014 Ground Level(above MSL): 150.0' RKB(above GL):_ 17.5' Revised By: Stan Porhola Downhole Revision Date: 12/9/2014 Schematic Revision Date. 12/15/2014 011 r" •1111: 1'.x'1 1' Alaska Oil and Gas �,� Conservation Commission . -ALASKA f . .. 333 West Seventh Avenue Anchorage,Alaska 99501-3572 ` 1 k ++ t.a;�: +:z t.i! 1 f.i is Main:907.279.1433 Op n L^s*P. Fax:907.276.7542 www.aogcc.alaska.gov Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek 12A Sundry Number: 314-633 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, L-44141. Cathy P. oerster Chair DATED this D day of December, 2014. Encl. RE EIVED r ,aim/ i STATE OF ALASKA NOV 2 5 2014 A ALASKA OIL AND GAS CONSERVATION COMMISSION 1)-I49 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑, ' Repair Wenn Change Approved Program 0 Suspend❑ Plug Perforations 2 . Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ After Casing❑ Other.❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number. Exploratory ❑ Development Q 214-070 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ • 6.API Number. Anchorage,Alaska 99503 50-133-20530-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 237A Beaver Creek(BCU)12A• Will planned perforations require a spacing exception? Yes ❑ No ❑, 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 Beaver Creek I Beluga Gas Pool i 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9,800 ' 9,578 - 9,676 . 9,454 7,820/7,914/8,125/8,360/8,475 WA Casing Length Size MD TVD Burst Collapse Structural Conductor 103' 20" 103' 103' 3,060 psi 1,500 psi Surface 2,087' 13-3/8" 2,087' 2,08T 3,450 psi 1,950 psi Intermediate 4,765' 9-5/8" 4,765' 4,673' 5,750 psi 3,090 psi Production 9,760' 5-1/2"x 5" 9,760' 9,538' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth ND(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(t)and ND(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n 1 Service n 14.Estimated Date for 15.Well Status after proposed work: 12/03/14 Commencing Operations: Oil El Gas ❑✓ . WDSPL ❑ Suspended El 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Portrola Phone: 907-777-8412 Email soorhola( hilcoro.com Printed Name tan Porhola Title Operations Engineer Signature v_ (laPhone 907-777-8412 Date l,k Z VAt COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test p Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ NoII Subsequent Form Required: / Li (/ APPROVED BY Approved by: (AV/47 7;1COMMISSIONER THE COMMISSION Date: /2 — 8 -/ Submit Form and Form 10-403(Revised 10/2012) ApaRLGINAILI2 months from the dte of pproval. Attachments in Duplicate ' zf1 RBCMS DEC 1 201 . . II Well Prognosis Well: BCU-12A Hilcorp Alaska,LI) Date: 11/25/2014 Well Name: BCU-12A API Number: 50-133-20530-01 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: December 3rd, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-070 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1423513 Current Bottom Hole Pressure: - 2,320 psi @ 7,600' TVD (Applied N2 press; No open perfs) Maximum Expected BHP: - 2,320 psi @ 7,600' TVD (Based on current BHP) Max. Allowable Surface Pressure: - 1,560 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#12 was drilled as a Grass roots EXCAPE monobore completion in 2004 to target gas sands in the lower Beluga formation. All 12 EXCAPE modules were perforated and fracture stimulated.A capillary string was installed to deliver foamer to alleviate liquid loading in 2009.The capillary string was pulled in Sep 2010 but a fish was left in the well.The capillary string was re-ran to a shallower depth in Oct 2010. The capillary string was pulled in Feb 2014 and soap sticks have been dropped in place of the foamer. The well was sidetracked with Saxon #169 as Beaver Creek Unit#12A and the 5-1/2"x5" production longstring was cemented in mid July 2014.The first 4 perforated intervals were perforated at the end of July and were shown to be non-, _productive.The next set o 4 per orate• interva s were perforated at the beginning o L ugust and were s own Labe non-pmcucti4e.The next set of 3 perforated intervals were per orate in the mie oAugust and-were ' shown to be non-praduct_ive.T e nex se o 4 per orate• intervals were per ora e• a e •eginning of Se•tember an• •roduced :as with waer rie e ore waterin: out at the end of Septembe 2014.The next Lit interval (LB-22) was perforated in November 2014 and found to be non-productive. Bridge plugs have been (10M/00 placed between these intervals with the last plug set above the LB-22. 4 t50 The purpose of this work/sundry is to plugback the Lower Beluga and add perforations in the Sterling./ Gj f' Notes Regarding Wellbore Condition cD" ./ - /// k I/ • Will swab down fluid level with slickline and apply N2 or jet dry with N2 before RU E-line. 1 / " • Well will be displaced with Nitrogen before initial perforatingat+/- 1,200 psi SITP. P g E-line Procedure: 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 1,200 psi (Nitrogen pressure). 2. MU dump bailer and dump bail 35' (26 gallons) of cement on CIBP at 7,820'. V 3. RU 3-1/8" 6 spf Connex HC wireline guns. 4. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Sterling B3L 5,279' 5,299' 20' 6 �./ Well Prognosis Well: BCU-12A 1I limp AIa..��` LL Date: 11/25/2014 a. Bleed tubing pressure to 1,200 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using SLB Cement USIT Log (dated 7/21/14) (Tie-in log). e. Use Gamma/CCL/to correlate. f. Record tubing pressures before and after each perforating run. g. Spacing allowance is based on CO 237A, no restrictions in Sterling Gas Pool. 5. RD E-line. 6. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic ,. BCU - 12A ACTUAL Pad 4 2,023 FNL, 48T FEL, SCHEMATIC Sec.33, T7N, RIOW, S.M. Hilcorp Alaska. I.1.0 Permit#: 214-070 Conductor 20" K-55 133 ppf API#: 50-133-20530-01 jj Ton Bottom Prop.Des: FED A-028083 MD 0' 103' KB elevation: 167.5' (17.5'AGL) TVD 0' 103' Lat: N60° 39' 22.118" Long: W151° 1' 45.593" Spud: 6/29/2014 12:00 hrs Surface Casing TD: 7/07/2014 07:00 hrs 13-3/8" K-55 68 ppf BTC VFluid Level T� Bottom Rig Released: 7/13/2014 6:00 hrs MD 0' 2,087' 4,040' TVD 0' 2,087' 1167____ 1 16"hole Cmt w/600 sks(271 bbl)of 12.0 ppg, Tree cxn=9-1/2"Otis Type 1 cmt, 18 sks(8 bbls)to surface 8.0"Seal Diameter 5-1/8"Modified ID Bore Intermediate Casing 9-5/8" L-80 40 ppf BTC TOC(USIT 7/21/14)-4,375' i Tom Bottom IP I Mkr Jt 4,967' MD 0' 4,765' TVD 0' 4,673' ''"v 'm, 12-1/4"hole Lead Cmt wl 833 sks(341 bbls)of SA y 12.5 ppg,Class G, Tail Cmt w/327 sks(106 bbls) !' of 13.5 ppg,Class G, 12 sks(5 bbls)to surface °, Production Casing 5-1/2" P-110 17 ppf DWC/C-HT i , Top Bottom Mkr Jt 5,325' MD 0' 7,564' ND 0' 7,348' 5" L-80 18 ppf DWC/C-HT Top Bottom MD 7,564' 9,760' ND 7,348' 9,538' ' Mkr Jt 6,094' 8-1/2"hole Cmt w/1030 sks(248 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK , Casing/Cementing Detai( - 9.4 ppg Mud Tag(CIBP)@ 7,820'ELM - 10.5 ppg Mud Push(38 bbl) w/Setting Tool(11/18/14) ::\i‘\\i, - 15.3 ppg Cement(248 bbl) Mkr Jt 6,235' - 8.4 ppg Fresh Water(215 bbl) ♦ XO Jt 7,564' � 2 LB-22 Perforations: 3 Zone MD ND Size SPF Date Status LB-23jk LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Open LB-24= LB-23 7,929'-7,941 7,708'-7,720' 2-718" 6 9/03/14 Isolated LB-24 II NIA Mkr Jt 8,054' LB-24 8,015-8,028' 7,794'-7,807' 2-7/8" 6 9/03/14 Isolated LB-26A _ LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 9/03/14 Isolated 4 LB-26A 8,107'-8,117' 7,885-7,896' 2-7/8" 6 9/03/14 Isolated LB-27 =IllikLB-27 8,135-8,155' 7,914'-7,934' 2-7/8" 6 8/20/14 Isolated LB-28 = LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 8/20/14 Isolated Jewelry Depth LB-28 = 5 LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 8/20/14 Isolated 1.Swell Packer(21'Long) 4,209' LB-29 lifl. LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 8/04/14 Isolated 2.CIBP(Set 11/18/14) 7,820' LB_29 = LB-29 8,393-8,403' 8,172'-8,182' 2-7/8" 6 8/04/14 Isolated 3.CIBP(Set 11/02/14) 7,914' LB_29B= LB-29B 8,435-8,450' 8,214'-8,229' 2-7/8" 6 8/04/14 Isolated 4.CIBP(Set 8/21/14) 8,125' LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 8/04/14 Isolated LB-29B:= S 5.CIBP(Set 8/09/14) 8,360' 6 LB-30 8,480'-8,490' 8,259'8,269' 2-7/8" 6 7/30/14 Isolated 6.CIBP(Set 8/02/14) 8,475' LB-30 _`- � LB-30 8,495-8,510' 8,274'-8,289' 2-7/8" 6 7/30/14 Isolated LB-30 MkrJt 8,500' LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 7/30/14 Isolated LB-31 8,600'-8,610' 8,379'-8,389' 2-7/8" 6 7/30/14 Isolated LB-31 = _ LB-31 S3 Casing Shoe @ 9,760' Tag(unset cement)@ 9,464'SLM O 40'off a Max Dogleg: w/3.84"GR(7/16/14) Casing 40'off bottom 4.42°/100'@ 8,004' TD: PBTD: 9,800'MD 9,676'MD Max Inclination: 9,578'ND 9,454'ND 20.3°@ 5,027' Well Name&Number: Beaver Creek Unit#12A Lease. A-028083 County or Parish. Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth: 19.2°@ 4,769' Angle/Perfs:I N/A Maximum Deviation: 20.3°@ 5,027' Date Completed._ 7/12/2014 Ground Level(above MSL): 150.0' RKB(above GL): 17.5' Revised By. Stan Porhola Downhole Revision Date: 11/18/2014 Schematic Revision Date: 11/25/2014 • BCU - 12A PROPOSED Pad 4 2,023 FNL, 482'FEL, SCHEMATIC Sec.33, T7N, R10W, S.M. tlileorp Alaska. LL(; Permit#: 214-070Conductor 20" K-55 133 ppf API#: 50-133-20530-01 ,�` Top Bottom Prop.Des: FED A-028083 MD 0' 103' KB elevation: 167.5' (17.5 AGL) TVD 0' 103' Lat: N60° 39' 22.118" Long: W151° 1' 45.593" Spud: 6/29/2014 12:00 hrs Surface Casing • TD: 7/07/2014 07:00 hrs 13-3/8" K-55 68 ppf BTC Tom Bottom Riq Released: 7/13/2014 6:00 hrs MD 0' 2,087' ti, ND 0' 2,087' 1 16"hole Cmt w/600 sks(271 bbl)of 12.0 ppg, Tree cxn=9-1/2"Otis . Type 1 cmt, 18 sks(8 bbls)to surface 8.0"Seal Diameter 5-1/8"Modified ID Bore 4' Intermediate Casing 9-5/8" L-80 40 ppf BTC TOC(USIT 7/21/14)-4,375' f T� Bottom I MkrJt 4,967' MD 0' 4,765' ND 0' 4,673' +a."1 12-1/4"hole Lead Cmt w/833 sks(341 bbls)of Lam' 12,5 ppg,Class G, Tail Cmt w/327 sks(106 bbls) of 13.5 ppg,Class G, 12 sks(5 bbls)to surface I \l • Production Casing Sterling B3L 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom MkrJt 5,325' MD 0' 7,564' ND 0' 7,348' 5" L-80 18 ppf DWC/C-HT 4 Top Bottom - ' MD 7,564' 9,760' ?i ND 7,348' 9,538' 8-1/2"hole Cmt wl 1030 sks(248 bbls)of 15.3 ppg, I Mkr Jt 6,094' Class G cmt w/EASYBLOK Casing/Cementing Detail .s w/35'of Cement - 9.4 ppg Mud 26gal of cement - 10.5 ppg Mud Push(38 bbl) - 15.3 ppg Cement(248 bbl) 'Mkr Jt 6,235' - 8.4 ppg Fresh Water(215 bbl) •,f .„ XO Jt 7,564' t - 2 LB-22=� Perforations: ' 3 Zone MD D Size SPF Date Status LB-23 , N Sterling B3L 5,279'-5,299' 5,156-5,177' 3-1/8" 6 Proposed LB-24= LB-22 7,841'-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Open LB-24 i 192A MkrJt 8,054' LB-23 7,923-7,941' 7,709-7,720' 2-718" 6 9/03/14 Isolated LB-26ALB-24 8,015-8,028' 7,794'-7,807' 2-7/8" 6 9/03/14 Isolated ;J ►. _ 4 LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 9/03/14 Isolated LB-27 �- LB-26A 8,107'-8,117' 7,886-7,896' 2-7/8" 6 9/03/14 Isolated LB-28 LB-27 8,135-8,155' 7,914-7,934' 2-7/8" 6 8/20/14 Isolated Jewelry Depth LB-28 _ LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 8/20/14 Isolated 1.Swell Packer(21'Long) 4,209' LB-29 ';'*15 LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 8/20/14 Isolated 2.CIBP(Set 11/18/14)Cap w/35'of cmt 7,820' LB-29 LB-29 8,374-8,384' 8,153-8,163' 2-7/8" 6 8/04/14 Isolated 3.CIBP(Set 11/02/14) 7,914' LB-29B.s LB-29 8,393-8,403' 8,172'-8,182' 2-7/8" 6 8/04/14 Isolated 4.CIBP(Set 8/21/14) 8,125' LB-29B 8,435-8,450' 8,214-8,229' 2-7/8" 6 8/04/14 Isolated LB-29B= LB-296 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 8/04/14 Isolated 5.CIBP(Set 8/09/14) 8,360' 6- 6.CIBP(Set 8/02/14) 8,475' LB-30 , LB-30 8,480'-8,490' 8,259-8,269' 2-7/8" 6 7/30/14 Isolated LB-30 ERA MkrJt 8,500' LB-30 8,495-8,510' 8,274-8,289' 2-7/8" 6 7/30/14 Isolated S LB-31 8,543-8,553' 8,322'-8,332' 2-7/8" 6 7/30/14 Isolated LB-31 LB-31 8,600'-8,610' 8,373-8,389' 2-7/8" 6 7/30/14 Isolated LB-31 S- Casing Shoe @ 9,760' Tag(unset cement)@ 9,464'SLM le Max Dogleg: w/3.84"GR(7/16/14) „ , Casingg 40 40'offoff bottom 4.42°/100'@ 8,004' TD: PBTD: 9,800'MD 9,676'MD Max Inclination: 9,578'ND 9,454'ND 20.3°@ 5,027' Well Name&Number: Beaver Creek Unit#12A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth: 19.2°@ 4,769' Angle/Perfs:I N/A Maximum Deviation: 20.3°@ 5,027' Date Completed: 7/12/2014 Ground Level(above MSL). 150.0' RKB(above GL): 17.5' Revised By: Stan Porhola Downhole Revision Date. Proposed Schematic Revision Date: 11/25/2014 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMIS—.JN NOV 2 5 2014 REPORT OF SUNDRY WELL OPERATIONS 11.Operations Abandon U Repair Well U Plug Perforations Lf Perforate L] Other 60GCC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown 0 Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 2 Exploratory ❑ 214-070 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20530-01 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)12A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Beluga Gas Pool 11.Present Well Condition Summary: 7,820; 7,914;8,125; Total Depth measured 9,800 feet Plugs measured 8,360'8,475 feet true vertical 9,578 feet Junk measured N/A feet Effective Depth measured 9,676 feet Packer measured N/A feet true vertical 9,454 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 103' 20" 103' 103' 3,060 psi 1,500 psi Surface 2,087' 13-3/8" 2,087' 2,087' 3,450 psi 1,950 psi Intermediate 4,765' 9-5/8" 4,765' 4,673' 5,750 psi 3,090 psi Production 9,760' 5-1/2"X 5" 9,760' 9,538' 10,640 psi 7,460 psi Liner 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) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 940 1340 Subsequent to operation: 0 0 0 600 1769 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 2 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑� WDSPL❑ GSTOR 0 WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-481 Contact Stan Porhola Email sporhola( hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature _....2 .1671/4-_—_ Phone 907-777-8412 Date t2s/N' I "4_, /?-1/-1 y MEN'S NOV 2 5 NA\ Form 10-404 Revised 10/2012 ` '�7 Submit Original Only • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-12A 50-133-20530-01 214-070 8/27/14 11/18/14 Daily Operations: 08/27/2014-Wednesday Morning safety meeting. Bop test. low pt 250 high 4,500. (Witness waived by Jim Regg, AOGCC) Open well. Initial WHP 1,300 PSI. RIH with N2 pumping down annulus starting at 3000 ft. Parked at 4,000' awaiting returns at surface. 600 scf.min. No returns at surface. Tagged plug at 8,070 ft. Pumping 1,000 scf/min. No returns at surface. 20 ft off bottom tag pumping 1,000 scf/min. No increase in pump pressure. Good indication we were not lifting fluid up coiled tubing. POOH at surface pumping N2 to pressure up well to 1,500 psi. 170,000 scf pumped for reverse out. No fluid at surface. Well was dry. Previous WSR indicates fluid levels at 4,800 ft. Incorrect fluid tag. Rigging down. 09/03/2014-Wednesday PTW and JSA. Rig up lubricator. PT to 250 psi low and 3,500 psi high. RIH w/GPT tool, 2-1/2" x 10' Connex HC, 6 spf, 60 deg phase and tie into SLB RST log. Run correlation pass and send to town. Get ok to shoot. S pot shot from 8,107' to 8,117'. Fired with 1,550 psi on tubing. Did not see any increase from GPT tool. POOH. Pressure about 1,575 psi. RIH 2-1/2" x 19' Connex HC, 6 spf, 60 deg phase and tie into SLB RST log. Run correlation pass and send to town. Get ok to shoot. Spot shot from 8,031' to 8,050'. Fired with 1,575 psi on tubing. Pressure went to 1,650 psi. POOH. RIH 2-1/2" x 13' Connex HC, 6 spf, 60 deg phase and tie into SLB RST log. Run correlation pass and send to town. Get ok to shoot. Spot shot from 8,015' to 8,028'. Fired with 1,650 psi on tubing. Pressure went to 1,700 psi. POOH. RIH 2-1/2" x 12' Connex HC, 6 spf, 60 deg phase and tie into SLB RST log. Run correlation pass and send to town. Get ok to shoot. Spot shot from 7,929' to 7,941'. Fired with 1,700 psi on tubing. Pressure went to 1,750 psi. POOH. Ran GPT tool and took stations above each perf zone for 10 min each. POOH. Sent info to town. Rig down and clean up area. 11/02/2014-Sunday Obtain permit and MIRU Priority E-line. SITP 250 psi. MU lubricator and 5" CIBP to tool string. Stab on wellhead and test lubricator with well pressure,good test. RIH w/5" CIBP and correlate to SLB RST log dated 7/21/14 and casing XO joint. Log correlation pass from 7,915'-7,550'. Send in correlation log for verification. Adjust CIBP set depth to 7,914'. Set CIBP @ 7,914' and confirm set with tag. POOH w/setting tool. RD Priority E-line and move to BCU-14A. 11/05/2014-Wednesday • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-12A 50-133-20530-01 214-070 8/27/14 11/18/14 Daily Operations: Hold JSA and safety meeting. Fill out and discuss permit to work. Talk about proper procedures, spill reporting and well work. Move in CTU trailer, mast trailer and crane. Remove well house and set to side of location. All equipment moved into place.Remove wellhead flanged night cap and replace with proper x over spool. Rig up pump iron to reel and return line. Pick injector head from back deck, stab onto lubricator and mast. Pick and stab onto well. Hammer up wellhead connections. Fluid pack coil at 2 bbls/min. CT volume 33 bbls. State representative on location at 16:45 to witness BOP test, Lou Gramaldi, AOGCC. Start BOP Test. Low PT 250 psi, High pt to 4,500 psi. Full body test complete. Move onto Blind test/choke valves, outside low torque flow cross valves. PT good to go. Moved to Front choke valves and Kill line HCR valves. Pressure did not hold on low Pressure test. Halliburton HCR valve leaking. Temperature was dropping below freezing. Decision was made to shut down for the night and resume BOP testing in the morning. Blow down CT with Nitrogen. Mixed up 50 bbls of water/ Methanol mixture. Added 350 gallons of Neat Methanol to 50 bbls of water for BOP test fluids in the morning. Halliburton crew rigged down complete well head stack as they did not have a night cap. Wellsite secure. 11/06/2014-Thursday Hold JSA safety meeting. Subjects: Slippery pit liner, new light plant location, Proper valve alignment and call out. Properly training SSE employees and assigning a mentor. Fire equipement, Raise mast, Remove night cap, pick injector head and stab onto dual stripper assembly, Risers and BOPS. Pick injector head, riser, BOPS and fly to well head. Hammer BOPS to wellhead flange. Fluid packed coil. Start BOP test. Low and high shell test 250/4,500 psi. RIH with Coil and close pipe slips and pipe rams. Pushl5k Pull 20k. Tested pipe rams, HCR valves 250/4,500 psi. Greased inner reel valve. Low and high pt inner reel valve 250/4,500 psi. BOP draw down test. Passed 2,900 psi system pressure. Shut down power pack. Cycled 4 sets of rams, close, open, close. Remaining system pressure 2,350 psi. Needs 200 psi over accumulator pre charge pressure. Pre charge pressure 1,500 psi. Draw down test successful. Open swab to make sure there was not an ice plug in wellhead. Ran to ground level inside tree to determine that it was free. Initial WHP 400 psi. Rigging off BOPs for the night. Setting down riser, stripper, injector head. Wellsite secure. 11/07/2014- Friday Hilcorp Alaska, LLC Well Operations Summary 111 Well Name API Number Well Permit Number Start Date End Date BCU-12A 50-133-20530-01 214-070 8/27/14 11/18/14 Daily Operations: Hold safety meeting and JSA. Permit to work. Talked about proper crane signals and rigging. Fire equipment/ pick injector head and stab onto risier pick up and make up 1-3/8" external slip conector, dual flapper check valve. Pull test to 20K. Make up Nozzle. Stab on well with injector head. Hammer up flange to BOPs. Fluid pack CT with methanol water mixture. Perform low PT 250 psi for 5 minutes. High pt 4,500 psi 5 minutes. Blow down coil to tank and recover with vac truck. Move fluid volume of 35 bbls to holding tank. Open well and RIH /WT chk @ 2,500 ft, 8k. Start n2 at 4,284ft @ 1,000 scf/min. Initial WHP was 400 psi. Bleed down WHP to open top tank while RIH. WT chk 21k @ 7,050 ft. 12:45 returns to surface. Light tag on top of CIBP at 7,906 ft CTMD. Pick up 5 ft from tag. Park and unload well at depth. Straight n2 at return tank. Total BBLs recovered from N2 lift is 90 bbls. 90 bbls=fluid level was at 4,043 ft in the wellbore. Start POOH to surface. Still dry at return tank while POOH close in choke and build pressure on well. Drop n2 to 500 scf/min while POOH. At surface. WHP is 1,560 psi SITP. Master swab closed. Bleeding off n2 to open top tank. N2 bled down. CTU crews rigging down equipment. Roustabouts breaking down return iron and moving to BCU 14A. Well house re-installed. Moving Halliburton equipment to BCU 14A. 11/10/2014- Monday PTW and JSA. Mobe equipment to location. Spot equipment and start rig up. When raising the lubricator it hung up on edge of walkway on top of well house. As SLB hand was holding lub away from walkway it hung up again. Lub came free and hit hand in mouth. Shut down job. Will start again after investigation. 11/11/2014-Tuesday Had safety stand down/meeting with SLB/Hilcorp safety people. Mobe to location. PTW&JSA. Go over the accident with SLB/Hilcorp safety people. Rig up lubricator and attempted to PT. Had leak in 7' riser connection. Changed oring and still leaked. Switched out to a 5' riser. PT 250 psi low and 3,200 psi high. Arm gun. RIH w/2-7/8 "x 24' Connex HC, 6 spf, 60 deg phase perf gun and tie into SLB RST log dated 7/21/14 and tagged at 7,904'. Ran correlation log to 7,000' and send to town. Get ok to perf. Bled well to 1,349 psi. Spot shot from 7,885' to 7,861'. Fired gun and TP went to 1,353' psi. POOH. All shots fired and guns were wet. Arm gun. RIH w/2-7/8" x 20' Connex HC, 6 spf, 60 deg phase perf gun and tie into correlation log of first run. Spot shot from 7,861' to 7,841'. Tubing pressure 1,353'. Fired gun and TP went to 1,355 psi. POOH. All shots fired and guns were wet. Rig down lubricator and clean up work area.Turn well over to field. 11/18/2014-Tuesday PTW and JSA. Mobe equipment to location. Spot and rig up PESI lubricator. PT lubricator to 250 psi low and 3,500 psi high. TP - 1,700 psi. RIH w/ 5" CIBP, tie into SLB perf log down to 7,840 '. Found FL at 4,040'. Set plug at 7,820'. Pick up 50' and go back down and tag plug. POOH. Rig down Lubricator. • BCU - 12A ACTUAL Pad 4 2,023 FNL, 482' FEL, SCHEMATIC Sec.33, T7N, R10W, S.M. Hileorp Alaska, LLC Permit#: 214-070 Conductor 20" K-55 133 ppf API#: 50-133-20530-01 Top Bottom Prop.Des: FED A-028083 I MD 0' 103' KB elevation: 167.5 (17.5'AGL) LL ND 0' 103' Let: N60° 39' 22.118" Long: W151° 1' 45.593" t° Spud: 6/29/2014 12:00 hrs °. Surface Casinq TD: 7/07/2014 07:00 hrs 13-3/9" K-55 68 ppf BTC Rig Released: 7/13/2014 6:00 hrs T_, Fluid Level -1:9 Bottom 4,040' MD 0' 2,087' TVD 0' 2,087' 1 16"hole Cmt w/600 sks(271 bbl)of 12.0 ppg, Tree cxn=9-1/2"Otis Type 1 cmt, 18 sks(8 bbls)to surface 8.0"Seal Diameter 5-1/8"Modified ID Bore d Intermediate Casinq 9-5/8" L-80 40 ppf BTC TOC(USIT 7/21/14)-4,375' iA lag Bottom I Mkr Jt 4,967' MD 0' 4,765' ND 0' 4,673' aM, 'w`, 12-1/4"hole Lead Cmt w/833 sks(341 bbls)of 1^v > 12.5 ppg,Class G, Tail Cmt w/327 sks(106 bbls) of 13.5 '.' ppg,Class G, 12 sks(5 bbls)to surface I -k, �( Production Casing `(. !!��"►► 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom 1 Mkr Jt 5,325' MD 0' 7,564' y ND 0' 7,348' L I, 5" L-80 18 ppf DWC/C-HT ,Vi Top Bottom MD 7,564' 9,760' i V or ND 7,348' 9,538' L'Alliii6 A. 8-1/2"hole Cmt w/1030 sks(248 bbls)of 15.3 ppg, ,r „kill 1 Mkr Jt 6,094' Class G cmt w/EASYBLOK 1`)o Casing/Cementing Detail, Tag(CIBP) 7,820'ELM - 9.4 ppg Mud- 10.5 ppg Mud Push(38 bbl) w/Setting Tool(11/18/14) - 15.3 ppg Cement(248 bbl) Mkr Jt 6,235' - 8.4 ppg Fresh Water(215 bbl) '. et:,XO Jt 7,564' . ; - -_-- 2 LB-22 _ _ Perforations: 3 ' Zone MD ND Size SPF Date Status LB-23 LB-22 7,841-7,885' 7,621'-7,664' 2-7/8" 6 11/11/14 Open LB-24= LB-23 7,929'-7,941' 7,708'-7,720' 2-7/8" 6 9/03/14 Isolated LB-24 111 A Mkr Jt 8,054' LB-24 8,015'-1,028' 7,794'-7,807' 2-7/8" 6 9/03/14 Isolated LB-26A _ LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 9/03/14 Isolated -407t. i/ _ 4 ' LB-26A 8,107'-8,117' 7,886-7,896' 2-7/8" 6 9/03/14 Isolated LB-27LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 8/20/14 Isolated LB-28 LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 8/20/14 Isolated Jewelry Depth LB-28 = _ LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 8/20/14 Isolated 1.Swell Packer(21'Long) 4,209' LB-29 - ?lftt 5 LB-29 8,374-8,384' 8,153'-8,163' 2-7/8" 6 8/04/14 Isolated 2.CIBP(Set 11/18/14) 7,820' LB-Y9 = = LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 8/04/14 Isolated 3.CIBP(Set 11/02/14) 7,914' LB-29B= _. LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 8/04/14 Isolated •4.CIBP(Set 8/21/14) 8,125' , LB-298 8,460'8,470' 8,239.-8,249' 2-7/8" 6 8/04/14 Isolated LB-29B= _ 5.CIBP(Set 8/09/14) 8,360' 6 LB-30 8,480'-8,490' 8,259'$,269' 2-7/8" 6 7/30/14 Isolated 6.CIBP(Set 8/02/14) 8,475' LB-30 ' _ - LB-30 8,495'-8,510' 8,274-8,289' 2-7/8" 6 7/30/14 Isolated LB-30 III ZA MkrJt 8,500' LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 7/30/14 Isolated LB-31 S LB-31 8,600-8,610' 8,379'-8,389' 2-7/8" 6 7/30/14 Isolated LB-31 Casing Shoe @ 9,760' Tag(unset cement)@ 9,464'SLM Open hole Max Dogleg: w/3.84"GR(7/16/14) Casing 40'off bottom 4.4r/100'@ 8,004' TD: PBTD: 9,800'MD 9,676'MD Max Inclination: 9,578'ND 9,454'ND 20.3"@ 5,027' Well Name&Number. Beaver Creek Unit#12A _ Lease: A-028083 County or Parish: Kenai Peninsula Borough Slate/Prov. Alaska Country:IUSA Angle @KOP and Depth. 19.2°@ 4,769' Angle/Per/s:1 N/A Maximum Deviation._ 20.3°@ 5,027' Date Completed: 7/12/2014 Ground Level(above MSL). 150.0' RKB(above GL): 17.5' Revised By: Stan Porhola Downhole Revision Date: 11/18/2014 Schematic Revision Date. 11/25/2014 RECEIVED • STATE OF ALASKA OCT 3 2014 ALA;, _OIL AND GAS CONSERVATION COMB, ..ION o ❑ WELL COMPLETION OReR❑ ❑ ECOMPLETIONnRE❑PORT AND LOGGGGGG Status:1a.Well 20AAC 25.105 20AAC 25.110 Development 0 . Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: / ,/b c.a.,is Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5. Date Comp.,Susp.,or 12. Permit to Drill Number: Hilcorp Alaska, LLC Aband.: 9/3/20.1r 7, '3c.)t=tai -f 214-070 - 3.Address: 6. Date Spudded: ,(w 13.API Number: 3800 Centerpoint Drive, Suite 1400,Anchorage,AK 99503 6/30/2014 /4„/1-; r s 50-133-20530-01 - 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 2024'FNL,481'FEL, Sec 33,T7N, R1OW,SM,AK - 7/8/2014 Beaver Creek Unit(BCU)12A - Top of Productive Horizon: 8.KB(ft above MSL):/6/.3' ,15.Field/Pool(s): 1900'FNL,796'FWL,Sec 34,T7N, R1OW,SM,AK GL(ft above MSL):)q 9,4, se, Total Depth: 9. Plug Back Depth(MD+TVD): Beaver Creek/Beluga Gas Pool _ 1915'FNL,842'FWL,Sec 34,T7N, R1OW,SM,AK '9,676'MD/9,454'TVD • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 315325.75- y- 2433191.53 • Zone- 4 - •9,800'MD/9,578'TVD • FEDA028083 TPI: x- 316600.15 y- 2433303.891 Zone- 4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 316646.16 y- 2433288.1 Zone- 4 N/A N/A 18. Directional Survey: Yes ❑✓ . No ❑ 19.Water Depth, if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top WindpAJMD TVD: ROP, DGR, EWR-Phase4,ALD, CTN, RST-GR-CCL,MUDLOGS(already submitted) • It 74&1 ' MI)/yb7a.Tv) - 23. CASING, LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 5" 18# P-110 7564' 9760' 7348' 9538' 7-7/8" 1 5-1/2" 17# P-110 18' 7564' 18' 7348' 7-7/8" - L' 248 bbls 15.3 ppg class G 24. Open to production or injection? Yes . No ❑ 25. TUBING RECORD If Yes, list each interval open(MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): N/A N/A 4,209'MD/4,149'TVD LB-23 7,929'-7,941'MD 7,708'-7,720'TVD 2-7/8" 6 spf Swell Packer LB-24 8,015'-8,028'MD 7,794'-7,807'TVD 2-7/8" 6 spf . 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. LB-24 8,031'-8,050'MD 7,810'-7,829'TVD 2-718" 6 spf Was hydraulic fracturing used during completion? Yes ❑ No 0 LB-26A 8,107'-8,117 MD 7,886'-7,896'TVD 2-7/8" 6 spf ac'(:Ei) DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED "/ ,..3 L . / PRODUCTION TEST Date First Production: Method of Operation(Flowing, gas lift, etc.): 9/5/2014 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 9/10/2014 24 Test Period 11.0 200 0 0 N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 685 840 24-Hour Rate -- 0 200 0 N/A 28. CORE DATA Conventional Core(s)Acquired? Yes,❑ No❑ Sidewall Cores Acquired? Yes ❑ No Q i If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water/'97ly (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. G,. ABC MS OCT a 3 201 .,` Form 10-407 Revised 102012 uONTINuED UN RtvtR� Submit of igirral only G 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. `� FORMATION TESTS NAME MD TVD Well tested? y Yes �/WNo If yes, list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form, if needed, Permafrost-Top and submit detailed test information per 20 AAC 25.071. Permafrost-Base STERLING_B 4961 4857 BC_B1ST 4994 4888 BC_B2ST 5087 4976 BC_B3ST 5205 5088 BC_B4ST 5397 5271 BELUGA 5971 5819 U_BELUGA 6023 5869 BC_UB1O_ST 6068 5911 BC_UB11_ST 6127 5967 BC_UB12_ST 6169 6006 BC_UB13_ST 6276 6108 BC_UB13_SB 6317 6147 M_BELUGA 6585 6401 SR_LBGT 7384 7161 BC_B23ST 7895 7666 BC_B31ST 8560 8331 SR_TYONEK 8992 . 8763 Formation at total depth: 31. List of Attachments: Well Schematic, MW vs Depth, Days vs Depth, Definitive directional survey, Drilling composite report,Casing and cmt reports for all strings 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Monty Mack Myers Email: mmyers(a7hilcorp.com_ Printed Name: Monty Mack Myers Title: Drilling Engineer Signature: Phone: 907-777-8431 Date: /0 • (7 . Z 0/1—/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item lb: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection, Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 BCU - 12A ACTUAL Pad 4 2,023 FNL, 482'FEL, SCHEMATIC Sec.33, T7N, R10W, S.M. Hilcorp Alaska. LLC Permit#: 214-070 Conductor API#: 50-133-20530-01LL 20" K-55 133 ppf Too Bottom 41] Prop.Des: FED A-028083 MD 0' 103' KB elevation: 167.5' (17.5'AGL) TVD 0' 103' Lat: N60° 39' 22.118" Long: W151° 1' 45.593" Spud: 6/29/2014 12:00 hrs Surface Casing TD: 7/07/2014 07:00 hrs 13-3/8" K-55 68 ppf BTC Rig Released: 7/13/2014 6:00 hrs Toy Bottom MD 0' 2,087' TVD 0' 2,087' -- 1 16"hole Cmt w/600 sks(271 bbl)of 12.0 ppg, Tree cxn=9-1/2"Otis Type 1 cmt, 18 sks(8 bbls)to surface 8.0"Seal Diameter 5-1/8"Modified ID Bore Intermediate Casing 9-5(8" L-80 40 ppf BTC L TOC(USIT 7121/14)-4,375' • Tog Bottom 'Mkr Jt 4,967' MD 0' 4,765' TVD 0' 4,673' 12-1/4"hole Lead Cmt w/833 sks(341 bbls)of 12.5 ppg,Class G, Tail Cmt wl 327 sks(106 bbls) of 13.5 ppg,Class G, 12 sks(5 bbls)to surface . Production Casing ' 'Mkr Jt 5,325' 5-1/2" P.110 17 ppf DWC/C-HT Top Bottom MD 0' 7,564' TVD 0' 7,348' 5" L-80 18 ppf DWC/C-HT Top Bottom MD 7,564' 9,760' II Mkr Jt 6,094' TVD 7,348' 9,538' 8-1/2"hole Cmt w/1030 sks(248 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK Casing/Cementing Detail - 9.4 ppg Mud I Mkr Jt 6,235' - 10.5 ppg Mud Push(38 bbl) - 15.3 ppg Cement(248 bbl) - 8.4 ppg Fresh Water(215 bbl) XO Jt 7,564' Perforations: Zone MD TVD Size SPF Date Status • LB-23= LB-23 7,929'-7,941 7,708'-7,720' 2-7/8" 6 9/03/14 Open LB-24- === LB-24 8,015-8,028' 7,794-7,807' 2-7/8" 6 9/03/14 Open LB-24 A Mkr Jt 8,054' LB-24 8,031'-8,050' 7,810'-7,829' 2-7/8" 6 9/03/14 Open LB-26A LB-26A 8,107-8,117' 7,886'-7,896' 2-7/8" 6 9/03/14 Open '" - -- - 2 LB-27 8,136-8,155' 7,914'-7,934' 2-7/8" 6 8/20/14 Isolated LB-27 j' _ LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 8/20/14 Isolated LB-28 = = LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 8/20/14 Isolated Jewelry Depth LB-28 = LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 8/04/14 Isolated 1.Swell Packer(21'Long) 4,209' LB-29 .. - 3 LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 8/04/14 Isolated 2.CIBP(Set 8/21/14) 8,125' LB-29B 8,435'-8,450' 8,214'-8,229' 2-7/8" 6 8/04/14 Isolated 3.CIBP(Set 8/09/14) 8,360' LB-29 LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 8/04/14 Isolated 4.CIBP(Set 8/02/14) 8,475' LB-29B= LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 7/30/14 Isolated LB-29B= LB-30 8,495'-8,510' 8,274-8,289' 2-7/8" 6 7/30/14 Isolated LB-30 =i' #►_- 4 LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 7/30/14 Isolated LB-30AMkrJt8,500' LB-31 8,600'-8,610' 8,379'-8,389' 2-7/8" 6 7/30/14 Isolated III Z LB-31 = __ LB-31 Casing Shoe @ 9,760' Tag(unset cement)@ 9,464'SLM 40Max Dogleg: w/3.84"GR(7/16/14) Casingg 40''ooffff bottom 4.42°/100'@ 8,004' TD: PBTD: 9,800'MD 9,676'MD Max Inclination: 9,578'TVD 9,454'TVD 20.3°@ 5,027' Well Name&Number Beaver Creek Unit#12A Lease: A-028083 County or Pansh: Kenai Peninsula Borough State/Prov: Alaska Country.IUSA Angle @KOP and Depth: 19.2°@ 4,769' Angle/Perls-I N/A Maximum Deviation. 20.3°@ 5,027' Date Completed: 7/12/2014 Ground Level(above MSL). 150.0' RKB(above GL): 17.5' Revised By: Stan Porhola Downhole Revision Date: 9/3/2014 Schematic Revision Date: 9/25/2014 SECTION 28 T7N R1OW SECTION 33 T7N R1OW - - - - - - -"- - - -"- - - - - ' ,-• - - N:2435208.07 E:315835.64 \ I NOTES �13 1) BASIS OF GEODETIC CONTROL AND NAD83 POSITION(EPOCH 2003)IS AN OPUS v J z j z SOLUTION FROM NGS COORDINATES o z i STATIONS"KEN1 CORS ARP","TLKA N (-)j M:M TALKEETNA CORS ARP",AND"POT3 POTATO z!z POINT 3 ARP"TO ESTABLISH THE POSITION OF O i g MCI BC1.THE GEODETIC POSITION OF BC1 w I w WAS DETERMINED TO HAVE A LATITUDE OF 60°38'50.02777"N AND A LONGITUDE OF 151°02'22.30311"W.THE ALASKA STATE PLANE COORDINATES(ASP)ZONE 4 ARE N=2429933.534 E=1453863.065 ELEV.131.31'(NAVD88) BCU PAD No.4 2) BASIS OF VERTICAL CONTROL IS NGS BM V80 PID TT0508 LOCATED WITHIN THE KENAI SPUR i HIGHWAY RIGHT OF WAY AT MILE POST 3.75 HAVING AN ELEVATION OF 164.55 FEET NAVD 88 ACCORDING TO NGS PUBLISHED DATA. 481' 3) COORDINATES CONVERTED TO NAD27 USING FEL CORPSCON6 CONVERSION SOFTWARE • 1 AS-BUILT WELL BCU 12 N:2433191.539' `.o.v4A111 _ LAT:60°39'22.031"N E:315325.751' A(q 11s = I C o ow 0 - .� Q -• ` u' Q Y O 3 p o a) _C a) a_ a) a) (0a E a m cn v U 6) O a) 5' 2) a) N _Y 0 L.L O Q m O (a O Q Q w a) U U' O (a IF) E ▪ E Y cncl E . 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L O I�) _ (00 = :c -0 3 II o °) a 8 c 73 a0 .m •- V °) - ..0 ...- O C)I� E '� O) N c0 O - 2� v O ` ` O N C 0 II .c C v \ II N t� N c. > _ LL f6 c 0- o (O Te, N co IN 0 12 -c, a) IN 0 Oi 0 y O > 23-O E 0 7 M a LL CO O m (nN 0 O L o 0 O0 a) co c6 `�- 0 II a) \ •O �- _ o cp > 1] n � COL!') .J C �co m OS afc ` C° ° 0 6 c_ a) - L £ CT � � � �- � @ Q� a 3 0 E ° 13L a - n o a) 0 0 0 00 O ° m o 0 �° 'A O O r .0 0 O O C - - °) O c O O w 0 N -0 CO C E a (n 0 O E o iA yr y o m 0 > C) ` 00 3 O E C a, II •v V) O co II _ 2_ II a L Q m m n 0 o N O to LL vi > •o •- L 15 cn E �c2 ° LL m u 3 \ mo CD 11 3 _ 3 a) 3 E n 2 o - m N_c o-C� Ri �. N n of O o U o ,E _ n ° E m = •.> r(°) ai o� n C 0 IN 0o Q E 0 C o n o (C) O v a O m a� U _co a a� N C L as C m 0) C E N O 2-.8 O 3 N II M ,,,,°0 ° o ` O II o - O II N O f6 N C c .-. - 0- -0 Q 0 0002 n E � m rn o Q rnL � rn a In -0 � � o .N � ° 0n °• `-° ° '- •- ° -(T.) ` "� . o ' L /1 00 p L E ll(O LQ. 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E _ T.0 0 1Z _ _ _ ° 2 0 1.3 - a Er COno0, 3 0)Qa m 0)Q (1)c0)° Eo 'm II L) m _crn 0M _ - Y 0)c 0 O m co_ C Y ° II CO v 0 Q CO v a ° L() a ° a) O C F- N Lc O CO 7 N 'L � c o -, 2 OCD - ami T3 78 Eo � sT(° (7, .c n coC) CaMi �c ° vCr CV aU 0 0 o m � a� co • a) .c 0-:Ise LM .c caj 00 m 0 0 O a) N 0 ,IU) O o 00 0.Im 3 CO 00 - I1f 0 0) N v v O N LO- D03-,- „ 4_ 0C0 '-. 07, 32N. 0 > "a- ' a _ N- `o > 0 .- o Z" E -- 30o 3N cn Crn ° M O m = II tl) ° _ _ C D " 0 0 ''- O L° O O O g O O LL O N C i--1) O -- (002 0 0_-0 > OM C co m mOO <T a00 O O) o ( m O 000N a I= -0 EP, -...1 o CO N- C 0 O COOM (6 a) 2O r CO II c-- r N- CO II N- O) 0 CO -5 00 O N N •2 0 .6 O) 0) II '- rn o of N -- 0-.9-7, i 11 ' n 3 ' n a) II m m E E ie, w W o Y ` II U '' W 0-tc w W E 2 U w 0 E -coo "E . u . .� ;:c, i o o = n E0 .v CL '- v 3 = 0 = -E .(7) F - E .� EIn_ _ Y o - 000 gf _ N o - o CO m a n ° EUm w -o '> 00 2- 0. n U m QQao ns) moo 12NrnmUaolzmrn = L a) a E z E COO CO CO C (00 (00 CO m Z C C C C C C - co o O O 0 o O 0 X X X X x x m CZ co co al co as ar Q V) (1) CO V) V) V) -CO rn r m 0 N ° r) O N H O N U) U) N a) m n o ,-- Z 0 c3 (3 3( (3 7,', 0 co O U Cl.M -7 -7 -7 -7 -7 ) C :") O m 0 ,0i __ Q 2 c U) L() v m O -- -0 1) L 0 0 I) N U a) o ( D i - .n sz - d 0) N 0 N CO (0 0 i 0 0 0 0 a) r) c-`_"° c LL (D (D (7 (D (D > m coO m C M M N •- X -) M -) m m Y N co V) ai -o i C7 i ai `o E L m Z 11 d p m m O ,r v v v v v Z LL U O Q Z o 0 0 0 0 0 \T J a C �+ N N N N N N 0 11) C 7 1] C 1- o n o ° > r- N M V' L� c0 DO JQ .@ U) - U j f\ I` r1`U ii C - o Wm v v v v v° O O O O O° N N N N NJ M -4- L` c0 _SQ °- f6 77 41 m o o) E m rn� N m orL 0_ � uoa m _ 0_,. a _ I.E.,? r` a) L -c M- p- OU I m o ° -m Q 3-V m - n O O on II m �c n m o 0 - cm 6 . 0) 0m -•_ m o (o n m Z N O m 7 Y O .N LL m Z m 3 ,n (q 7 E CO O C V -O _ O m N o LL a C C 0 6 ,-. 0C,1 m m -- (O L O O m a p N -O U .0 L a) c Y E- ° ° U O_° 0 7 • 2 U ,p L w m d 0 3 .0 `) n m _° . . p = m p .0 O ] -O N m L D U m m _ N m n m ,° 0 -p N m W a O C O m m m O N O Q o Y m p co , o moi -moo cu m c c m rn U o y , E - -r- � Ey, m C m NII C @ - m O O N -O O)!i V 0 •. _= , -. .(7) -06- 8E,�.r m 0 0 - m m o N O L c N m m N'_ Q mm ° b mN 000 ° CNN ~ � .., - co- m � ' no � ��wm 3 0 m Q ra c m m o a) 0) 0 N U m y a II d N N C 'c !A .0 a) m m o 'O p Y m 0 (n U n C m 2 a) .O mmn'coE - m mm u3m mo .oc = 7 n~_ u) EEo = U m.0m m 3 a m L _ m0 m N Y = m� L o c ci- 0 n Z m ° c = c m _CO3-, _ 0 U 3 o m a m U70 - Wa .o ai um Z, c c - -C m .N CL m o a m E p o o c n c c °� a>i `o _ m .g 'C m 3 ? ui = c m U 0 m m m O_ c ' H . m - v, m••- O U o O C _ S m - C m r- L 'O C O >` 0 :=_. (9 '(7) 0 U (n ° N U N •N N O m p c 0 m M E p - O m m ,f) CO n C m CO m U C ° m m@ m 0 U_ N O ° ~ U ° o m ri 3 a) m m m m = N Eli 3 ` U o ' 7-s- 1.04- = ,...,-C D _co)N O. D U ._ (4 m (Cl a) O u) o >.= Z b u) V c nN c co 7.5- o OU _Om a) ,° m m3 > U m 0O-0 "C ` ` EO = N CO C U N ow m .L •C in i > j -E 00 -Cv C m _ U U `mU > m E 3 m '-n ,t amOL o ui n m , m ° • m m o (Dom -;n m n m o c ;o ° moo .nl o .a" n �, E m c U > L m = m m p p M 'c ° > L0 ,_ 0. )-,- m m O)NU aUL O 0 0 ( m -C , m = N C > c N ° -o 3 m " m m n m 7 CO m O O U m C o N C L 0 o .n y 0 . 3 m L 0 b N m C'I m o N m > .o_O-u) a) m D o n u) E m m E m -O F- m m CO Y © ` oN oL 2 (() O) m 3 u) - c . J U O o CO 0 = -O m _ m N co N 0 'j m 3 V m - O C 0 n o O) , C _ .L-. ._ _n m i17 1] _o O c L 0 .L.., • C .ti L_ L L n' S - C C O N -O R - N N 0 , _° a O- , c0 = 6-i7 1C° 0 3 3 m 3- c N - 22° o o = 3 (000 = (0 m E '3 Y G = 3 C C >, c L O 3 m O-.m ._ 'd m Q U) .Q O - E m o p O y ' ai-o U n N o p E o a .5I m J j m3 m o = 3mo °7o -- E - o cwo3 - m3a . - a3 - mm c.l '-.= ai moo ° pd amimc oa0 '3o- � ° N _ m anJ > a) Em0u > wCvac mGEco o3m -0 -cLo ._ m o = m v o . d mpmOO aNLZm � m , 'O - OCO OU U� CLO °- ,� _ 0mmm � C EI . YpmLbND_LmC0 - mOmo0 ° m � ,7CLr- O -OV mm Lo ,a a mm � a = m . wN _ _) .. 't) NonD = m _0ocoo • m ,0 L (60mmmD - o EOomt . mo Y } j- 0 3 C L - m OO n0 0_ m � Z+L m L 00 0 ° o0- N0m cMm > OO -O amu) m Lf11 OO. 7Lm ( m11 --: (11-6. > N -0Z -° -0 -02 EacLV -o° m Nm m m v 00 ma 0 O - U a m aa -- ma = = Qca a) Np - o . -0 Om .0- ) pO - c - n O _ o OD = oNOmp mEncpm mC ) maaOmmJ c,-,,,- = 0 aoM o -00 - - o - - m -ow 0_ '5Z,NL LE >, omoi E -o mm = ? -p2mamn . „ ioam . Oca a ZLmO LLQ • OON 'OCm mO mL C , ) as e.0 ,,_ — = m L ' m ,7o < om O0cLL gCO TAYN mmNr30aa ( o mCgvo . opom � mwspm D _ oc0 U = ° ' °) nocm > °) UN 0 omomaLo L oou ° L) - 0E � c4 cu 0 RS Q o = ° c0-90 _c -pb0LLuN , - 0 4w ;0N oLoaM ~ Nno p m o c) 3oN = mIo - c <.-- Q EU -o ° n 0o � ovE ° ° o mo ciome -° >-. Q._mo am3YOm O O .. Mm OLL `� °" O !n .- m NO"- E 3Wm -O y= C7 0 °iL) ` moCEE mp- - OCa) OaLm - 0;O °O C iD Ey -, C . . Vj ,n - LOa) - O 0mC0 0 O a ` a) •C (0 0 (0 I- m Ou )V m c m > wL E .2s_ U ap-.0 0 z mce ° = oc °) oOmo . 00 - (1) 01- coy xa _ = Cm Lmm .c > 0 . .2m = mNdu_ 2E NE _ N 5rn U m ) c o2Y mCmo ' o mm ) . m3 -° m N C O O •Ya ,() m a) 2 a) o OV C .0i m > _c3n = o = ° Q -,' CD L - ° o 2 ' - cJ3 `no O 0- 0 _ Io oc • 0 ° o a) m 000 pcYmO+-' -o -pCOmNUoM °- C � mEw - oo -c Lo ,- a) a) QLC - mm. C 2 NOoC "6 C .2-Y.) 0 aoU) g a ' 7 o .c a) 2m Y -o Y p am ° ca� EcU . ° -oE ,n o 2 OcO « Toa - ¢ w m INp004-. 4,L 2, • Qm C LLn7 -. ulnmOLonn p - m . E _m - 4 .- ` Em72 a) U � . on0O7C . -o7C0 , RuC ° Lma7Q) c noorUm m000 nmo _ mQQm0 uO 0nm mL0 mm20o -) u0o a a- a.) a E z cu� S OD Z C m C C C - 00 0 0 0 Cl) X X X X m CC m co CO m Q U) CO U) Cl) m n m m (7 - -0N QN OZm aa) a) Mo,° ,- CO C/) n U) mM WO 7 C O.)U a) C M O [O 3 c c c N Q C ,f) V 0 ' " 9 N N N N U m o L m m m o a m N o N a) -o -o -o _ co m a) co -, c co M NI M o u -) a a a CO CO Y N o� co V (n ai 'g ai ;:7,- a * i 0o w - - E 1) m Z Y d E 15 O v v R v LI: in 0 _ Q o Z j., 1 c -o C Z'O O O N 0 a) = g o n o ° > _co rn NSU � � 0 - > Q C _ O LL :.7.• dr).- .1.. "4- 03 `-- V R rt U l0 O O O J 0 O O N N a W C 7 6 J ;r • T O C 7 V � U) � Q.1 m 7 N - � m .n O N c LO J U) D a 0)U 17 'O > O • O 'O 3 ✓3_N O M 'U O co d o m m a) a) E a) O o U �` OD @ U O) 0 N 0 w L (a U) - 0) O n .- , M a) -0 c 2 m m 2 - D Y m cC d � _a o)-0 U -o sTo co m n 2 o o o a 0 MOL N O O ca-.,7„ To m w in 0 E a 7 „ `, L E .- o_O - E o_ O` co _c U p - a) c o -0 O -0 C 3 o N U = r c 0_ Enema 0 .r Hti 0. r co a� . 0 m a w � c o i Q 3 U) m o ma aNi H o0 :c.0. n m 7 a > ° Cr) a) 0 U - 0 N V) m 3 aU 0) E E N N = 70 M r aOcJ .cO -O C N O -0 O m-0 d Or eY- a) O N 0 O .N E a) 2 a o m o o N c p o) • 3 Lo oa o mar E - a M c cn 0 () rn a o)o a o > m u ULI O N 1- o cco o ..7' o 0 o C •c C -C CO a) c — ..= c 0 � N a'0 0 C .c -O - E X 5 N aD 0) O U ' m m rnm _j-a 03 a 0)-0 -0 Lo to co73rn � c 0 7 . - j a J E U 7 c 7 _c c a fn 'E c 2 0 0 E 7 -2 o E U) a W ° m E w cri c m a) c c m m 0Q c 3 � L. Y c,„ >, _ m 3 m M c m a) a a N > tom 3 a 0 U U E o U 3 0) _ c) N _0 O O E 0 m ` 0 '0 0) c O N 0) N -0 0 _c N ` O_ c c m E � Q � E � m N a o ' Ln O C a) ul -0 a) m L CO a) > co C C 0 7 E'0 N ., - - m E = C a) a) -0 L-5- >O - .0'0 .- i) a N 0-O ^ •> �n 7a = 0 a) a) o--o a) V o 0 Y . 0)t0 m O _ 0)d M o a a) to E C L 0 0 m N 0 0)O J co D C m tD u) H U) V a. c m c) co c o w = z'= =o = c 1° U) M m ) II m e c ' 3 0 m o S m o m x� a) o c o 0 0 ,r 9 J M c0 > c 0 5 c a a) 0)- N ID a7 a) o 0 m ` U W W a) 0 c N 0 E O = a) +% N Q' E O C U O N cfl rn a E o a)�- > .—= o m u) o Q) V) n o .. c 0 z -o a) U - .N• 'mt E cco_c U U i) a) m o) o X Ew 0• Y of m � 0 yc o m mi) Ta) o .C > o (2,_ 8-_,_—.3 ,..2c,) H00 o m o a0 0- °)o 2..)ai ) ;n 0 -c .C 0 3 a) T E N c o m ON c E L_ N C O D LL m m@ a) m a O X 0 n o m = w °) 3 a ni d a) U 0 ~ 3 > u`) o) `S - a coo E -0 -� 'c o am mU E NY yNa mp o m N o O v) -2 .1 r) C = D . fn LL• c� 0 c 0 m a � = 'NI E ai o1 .Oc'D .- a0 o o .- 0 � co > > o) m O > = C a O C a) -0 5 • V) Oa) N a 7 O - � O � � 'O O TN C m E N ( � .0 V W o- E CD N cco U - 3 V) c E N 0 0 CO r m 0 fl O m J o C "O" w 3 m V 7 N d O N L U) C - N O C O m -0 -00 `0- 0 O .. c E o a) c73 opo u) a .0 — 0 - o a) co.co 0 0 0_ m -0 = to CO to X Lf) ai 7 O C 0 To Ur 0"H 0 0) O _ N d O O m op Xei N Mtn N O `n ma (N6 � m cC . 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O N W m • c Y N L o a Z N m 0 3 O . a) ) 0 U N 0 'y V) co '0 N U �z m co N r) a o N o- „ m `n m 3 m 0 •c ._ a) H � 0 op c rn II O U 0 0_(NJ N _ m L c a a) rn v . 0 3 m M CC ID 7 N N C - U 7 > a) c in -0 -C O "00 c 0 U r > 3 '0 .)(CD a N m 0 .6 o N Y - r 0 w e -C E�... a In -`0 m o E o-0 -0 a) c C_ O '6 Ur U) .c C .L a) C = = a _0 a - a) a) U 3 m 0) O V) Y O I (V a) E 3 '= O m 0 m '0 a t X O c 0 ., E 0 IL 0 ES M m c oicsJ 3 cc) co E w co -0 co mC.9 m � � 0 .0 o 0 a N 0 o- J = Y C -c L a a) a) -0 � o - .rU) o] mL0 U -o c 0Y o o- o-- o 3E = 0 � � �230 rnWMao � mEomLmmoY • 01 ,- „,0 0 a> V m 0_ -oN N r 3 Y a) — 3 U N -0 cn Ocn _ m a c 3 E E E o ,_0..a) a o N .N c C7 a) V m o m a D m . r N U ` .-� -0 -O ID O d 0'O a. Oa'E 0 -8 0 Y 0 d w Q_ .? 0 3 a) o_ c d M ° M 0) . a) N p O O C O E o ci t0a O) U N o -C y m O 0 m a- Y d C 0 $ v -3a 3 o_2 0 D 0 Q c 3 v v 3 = z io v3) m aa) a 3 Ce = a) a E z m �co _ m z O c Y p) O O 0 X X m d' m as Q co (/) _c Lc) cn r•-• 0 -ii)" •fn 7 `n Q o a) a) CO to o N 0 3 3 _ o o 'Z cn v) as Y 0 M O ? 0.- 7 c c Q N 'C lr) coM m co 0 0 N U a) o - ,- co 'O Cl- (N O N a) 0 0 0 M N CO C it -o a a m N C M co m XO IZ IZ U a) a) N tY cc m m m Y N O� co V U) ai -o m O m tt C) m o w E co Z Y d p m m O o- v Z >, OJ Q -O z c 0 0 EN 0 7) c o a o O > o -, U " U 2 c) N- N- c a) Q O W - -a- ..., V CM m o 0 J CI N N O.N (--;') — a ` Si cn j -c a) O -p O Ur !n V O = N C C Y N 0 It CO (� _ 3 M CO co0N- 715 O 0 = - a 41- U) 1a) a) O a. -.6C a) a) d 0 -p U) V > 0 co N a) 0 o E CO a' 3 c4* *k _1 -a .Q o �cJ EP =p C -§ Ur = i o C 72 °O co (0 -p ( Y O vi . a 3 . cr = NO z a'm a) E c C 7 2 0 O N LL a) U „ '� 3 c C C p O 3 N Z a) _CI - c ao (i) CI- fn CA _� a o V a) -Q a (a co 0) Cr a) C cn m E o (n Q O -0 o f p C 0 � Q.Q J < p U)) 0 0) C N a) 0 Y z`in .� c N N C U ro, � U) E XU) Lo O -0 ' 7 (0 .p iC) U) - - C N a N a Q) a 0 p Q p) O co 3 j E -p O LL in o E a) H C O � � -a � � -O p" C cc-JJ Q >0 • (0 Z U) C O p C E _ (D O 0 a) 3 = -' (a (6 O C '- O O 1) a) L 2 O _c C -p 12 Qd � � OC () 3o ° a) c _D _ _ a) O . n m 3 ac) o)t . 3 0 ai aa) a 'n Q c ci 3 c co = c Lo ° c M = O c ca J O M � cam c Do co CC .w- -a c -c � CCCl cti - 20, U Uw' N c (p O cc) 'E) N \ V Y o < oa ca �'� p o m. 3 oo '- a) m Lo 3 o c- o c (n c N CL 3 c ,_,,- 2 co O p CO O O (- • X_ U) D 0- N .� o Z '7 L C o ID 0 U) CL E .c c Q) 0 a (� .� co N Z Cn co o - o J (13 N a (o -c (z)L0 a) E E E c-2 a) U Z E o N o Ln 2 E Z U) d 0) u) (U N Y a o 0 0 � CZ a) m ° o H " o f c Cm U ° L D a rn F- o L iL U a., Un . O Na% -0 p O a. CC 00Zo U as c (u .� • oQua) cc 2C . Q c �, ((a o � C O Oo O (n cot N C E p 0 N1,7 O co J `.- N �Q 7 ' C o 0Q wL -p a 0 C `- C 'C 0 0 c '(d N /i co C w (C6 N Y dID Y '0_ 0 Q) Oa ai 5 = Q- 0 C� o o vas o a)D o E C 0 V ani .a? m2 c -0rn E ° a`) - c 0 .c J ^+ , = p (6 00 0 Qv- p ` Q ca N �- W U) w a3 0 p o a co ,- O E -O Z• d •+ D a (o E a o o E o `~ i3 m e C _D _N ., c C -a - ( • a C (`u -0 N O C o 1 .` Cn 3 u) ` N 3 a`) CY C C C - C N Q N .E00 NY aU n0 _ O N • 2 o - O :( _C = E a N E C7 0 > •° J O o oQ ,- -0 a� (ten (/Y • Co •mD c-U _ E H - c C (o t1)p ° N 2 E Y = C • Q Q Q 3 �o .a? 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N I- CO Q N N N N NY W O CO CO CO O a II Hilcorp Energy Company Beaver Creek Unit Beaver Creek Unit BCU-12A 501332053001 'I Sperry Drilling Definitive Survey Report 30 September, 2014 HALLIBURTON IN ■;■ Sperry Drilling -.-. True Vertical Depth (2000 usft/ir' IL Li_ O 0 0 0 o O o 0 0 0 0 0 0 0 rr o 0 0 0 0 0 0 0 0 0 o 1,-r- o_ 0 0 0 0 0 0 0 0 0 _ T T 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 I I I I I I I I I I I I I I I I I I I o m o o o O �a (Of0 - V 0)0) CN s� r O)0) N - O O O O as O Z G C > - M Z N X X c_ No 2 co co N v8 F- I-!n<0 ? 4 - a;V,. „ 0 ao coO U o U Z- '° CC . O O d c7 CO O O to 0 - 0 0 (4 W U a) > aov, U un li -tea —- O O .0 W I O• o O G LL �» - _., 5 �' m ,mm2 ' - ii 8. c8i 8 o (<1 -a •te `. ,- —o c c c c w d m d U _ O mei d2 m 0 N o K K O - O (/) a3o W0 – ocB thoZ�yN _ U + - • E m.sy( _ a) •c•f- z o O> 0 0 b —0 U 4M N — N U 0l /-)1 N O pm”.� N w U N U m 0 0 0 +_N C C,– - 1 Y C L' N a)D 2 2Y UoUNN co = 4) 0 a )''– N. 0 > > >as co N 0)) a) a)UU - `.., m m m m m .. .. .. .. .. - a+ 0 (n>>� ccl . 0 - - 00 )n _ 0o °?cm00 a,7 uorof tri c�° �C�7 o 8 z° gr.�ui 00 00 — 2to u 2.-acod M N U ct doh o y ' 2 M 0 •L •¢m i ('m CC N 301 c m .L (4.3 a —O J 0 J LI 1 I I I I I QL 0 0 0 O 0 0 OUJ O N O N v') / /N X (ui/gsn ocz) (+)q.ots (-)u;nos N Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 12 Project: Beaver Creek Unit ND Reference: BCU-12A @ 167.30usft(Saxon169(149.6 GL+17.7 DF' Site: Beaver Creek Unit MD Reference: BCU-12A @ 167.30usft(Saxon169(149.6 GL+17.7 DF' Well: Beaver CK Unit 12 North Reference: True Wellbore: BCU-12A Survey Calculation Method: Minimum Curvature Design: BCU-12A Database: Sperry EDM-NORTH US+CANADA Project Beaver 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 Beaver CK Unit 12 Well Position +N/-S 0.00 usft Northing: 2,433,191.54 usft Latitude: 60.6561198 +E/-W 0.00 usft Easting: 315,325.75 usft Longitude: -151.0292990 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 149.60 usft Wellbore BCU-12A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 6/20/2014 17.01 73.63 55,450 Design BCU-12A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 4,758.30 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 17.70 0.00 0.00 120.00 Survey Program Date 9/30/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 165.30 4,758.30 BCU 12(BCU-12) MWD MWD v3:standard declination 11/21/2013 4,769.00 4,839.68 BCU-12A Rig Surveys(BCU-12A) MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sag 06/11/2014 4,903.18 9,761.76 BCU-12A(MWD+SC+sag(BCU-12A) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 07/01/2014 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 17.70 0.00 0.00 17.70 -149.60 0.00 0.00 2,433,191.54 315,325.75 0.00 0.00 UNDEFINED 165.30 0.10 113.00 165.30 -2.00 -0.05 0.12 2,433,191.49 315,325.87 0.07 0.13 MWD(1) 221.30 0.20 341.30 221.30 54.00 0.02 0.13 2,433,191.56 315,325.88 0.49 0.10 MWD(1) 281.30 0.60 306.90 281.30 114.00 0.31 -0.15 2,433,191.85 315,325.60 0.75 -0.29 MWD(1) 342.30 0.40 319.40 342.30 175.00 0.66 -0.55 2,433,192.21 315,325.21 0.37 -0.81 MWD(1) 402.30 0.30 314.20 402.29 234.99 0.93 -0.80 2,433,192.48 315,324.97 0.17 -1.16 MWD(1) 462.30 0.40 266.40 462.29 294.99 1.03 -1.12 2,433,192.59 315,324.65 0.50 -1.48 MWD(1) 523.30 0.70 311.10 523.29 355.99 1.26 -1.61 2,433,192.82 315,324.16 0.82 -2.03 MWD(1) 583.30 0.60 272.60 583.29 415.99 1.52 -2.20 2,433,193.09 315,323.57 0.73 -2.66 MWD(1) 643.30 0.90 280.70 643.28 475.98 1.62 -2.98 2,433,193.20 315,322.80 0.53 -3.39 MWD(1) 734.30 1.30 291.30 734.27 566.97 2.13 -4.64 2,433,193.74 315,321.14 0.49 -5.08 MWD(1) 799.30 0.70 273.80 799.26 631.96 2.42 -5.72 2,433,194.05 315,320.07 1.03 -6.17 MWD(1) 9/30/2014 12:36:32PM Page 2 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 12 Project: Beaver Creek Unit TVD Reference: BCU-12A @ 167.30usft(Saxon169(149.6 GL+17.7 DE; Site: Beaver Creek Unit MD Reference: BCU-12A @ 167.30usft(Saxon169(149.6 GL+17.7 DF; Well: Beaver CK Unit 12 North Reference: True Wellbore: BCU-12A Survey Calculation Method: Minimum Curvature Design: BCU-12A Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 862.30 1.20 292.60 862.25 694.95 2.70 -6.72 2,433,194.34 315,319.08 0.93 -7.17 MWD(1) 925.30 0.80 276.60 925.24 757.94 3.00 -7.76 2,433,194.66 315,318.04 0.77 -8.22 MWD(1) 989.30 0.40 286.40 989.23 821.93 3.12 -8.42 2,433,194.79 315,317.38 0.64 -8.85 MWD(1) 1,052.30 0.50 280.50 1,052.23 884.93 3.23 -8.90 2,433,194.91 315,316.90 0.17 -9.32 MWD(1) 1,115.30 0.10 158.20 1,115.23 947.93 3.23 -9.15 2,433,194.91 315,316.65 0.89 -9.54 MWD(1) 1,176.30 0.50 66.10 1,176.23 1,008.93 3.29 -8.89 2,433,194.96 315,316.91 0.84 -9.34 MWD(1) 1,240.30 0.20 140.80 1,240.23 1,072.93 3.31 -8.56 2,433,194.99 315,317.24 0.76 -9.07 MWD(1) 1,302.30 0.20 131.10 1,302.23 1,134.93 3.16 -8.41 2,433,194.83 315,317.39 0.05 -8.87 MWD(1) 1,365.30 0.20 127.40 1,365.23 1,197.93 3.02 -8.24 2,433,194.69 315,317.56 0.02 -8.65 MWD(1) 1,428.30 0.30 141.20 1,428.23 1,260.93 2.82 -8.05 2,433,194.49 315,317.74 0.18 -8.39 MWD(1) 1,491.30 0.50 51.80 1,491.23 1,323.93 2.87 -7.73 2,433,194.53 315,318.06 0.92 -8.13 MWD(1) 1,554.30 0.30 25.80 1,554.23 1,386.93 3.18 -7.45 2,433,194.84 315,318.36 0.42 -8.04 MWD(1) 1,617.30 0.20 349.30 1,617.22 1,449.92 3.44 -7.39 2,433,195.09 315,318.41 0.29 -8.12 MWD(1) 1,681.30 0.30 134.30 1,681.22 1,513.92 3.43 -7.30 2,433,195.09 315,318.51 0.75 -8.03 MWD(1) 1,744.30 0.60 103.90 1,744.22 1,576.92 3.24 -6.86 2,433,194.88 315,318.95 0.59 -7.56 MWD(1) 1,806.30 0.20 29.30 1,806.22 1,638.92 3.26 -6.49 2,433,194.90 315,319.31 0.94 -7.25 MWD(1) 1,867.30 0.70 81.90 1,867.22 1,699.92 3.40 -6.07 2,433,195.03 315,319.74 0.98 -6.96 MWD(1) 1,932.30 0.50 64.70 1,932.22 1,764.92 3.58 -5.42 2,433,195.20 315,320.39 0.41 -6.48 MWD(1) 1,995.30 0.20 12.50 1,995.21 1,827.91 3.80 -5.15 2,433,195.42 315,320.67 0.65 -6.36 MWD(1) 2,043.30 0.30 56.00 2,043.21 1,875.91 3.95 -5.02 2,433,195.57 315,320.79 0.43 -6.33 MWD(1) 2,174.30 0.30 65.60 2,174.21 2,006.91 4.29 -4.43 2,433,195.90 315,321.39 0.04 -5.98 MWD(1) 2,238.30 0.30 105.00 2,238.21 2,070.91 4.31 -4.11 2,433,195.92 315,321.71 0.32 -5.72 MWD(1) 2,301.30 0.10 99.00 2,301.21 2,133.91 4.26 -3.90 2,433,195.86 315,321.92 0.32 -5.51 MWD(1) 2,367.30 0.40 110.60 2,367.21 2,199.91 4.17 -3.63 2,433,195.77 315,322.19 0.46 -5.23 MWD(1) 2,430.30 0.30 84.20 2,430.21 2,262.91 4.11 -3.26 2,433,195.70 315,322.56 0.30 -4.88 MWD(1) 2,490.30 0.90 37.00 2,490.21 2,322.91 4.50 -2.82 2,433,196.09 315,323.01 1.22 -4.69 MWD(1) 2,553.30 3.00 43.80 2,553.17 2,385.87 6.09 -1.38 2,433,197.65 315,324.47 3.35 -4.24 MWD(1) 2,616.30 4.80 49.30 2,616.02 2,448.72 9.00 1.76 2,433,200.51 315,327.65 2.91 -2.97 MWD(1) 2,690.30 6.20 53.30 2,689.68 2,522.38 13.41 7.31 2,433,204.83 315,333.27 1.96 -0.37 MWD(1) 2,743.30 6.70 54.30 2,742.34 2,575.04 16.92 12.12 2,433,208.27 315,338.13 0.97 2.04 MWD(1) 2,806.30 7.20 55.70 2,804.88 2,637.58 21.29 18.36 2,433,212.54 315,344.45 0.84 5.26 MWD(1) 2,869.30 8.60 55.80 2,867.28 2,699.98 26.16 25.52 2,433,217.30 315,351.68 2.22 9.02 MWD(1) 2,932.30 9.80 55.20 2,929.47 2,762.17 31.87 33.82 2,433,222.88 315,360.07 1.91 13.36 MWD(1) 2,996.30 10.60 55.00 2,992.45 2,825.15 38.35 43.12 2,433,229.21 315,369.46 1.25 18.16 MWD(1) 3,058.30 11.10 55.40 3,053.35 2,886.05 45.01 52.70 2,433,235.72 315,379.15 0.82 23.13 MWD(1) 3,121.30 12.30 55.20 3,115.04 2,947.74 52.29 63.20 2,433,242.83 315,389.76 1.91 28.59 MWD(1) 3,185.30 13.20 54.60 3,177.46 3,010.16 60.41 74.76 2,433,250.77 315,401.44 1.42 34.54 MWD(1) 3,247.30 14.50 54.20 3,237.65 3,070.35 69.05 86.82 2,433,259.22 315,413.64 2.10 40.66 MWD(1) 3,310.30 15.30 53.00 3,298.53 3,131.23 78.67 99.86 2,433,268.63 315,426.83 1.36 47.14 MWD(1) 3,372.30 15.90 53.20 3,358.25 3,190.95 88.68 113.19 2,433,278.44 315,440.32 0.97 53.69 MWD(1) 9/30/2014 12:36:32PM Page 3 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 12 Project: Beaver Creek Unit TVD Reference: BCU-12A @ 167.30usft(Saxon169(149.6 GL+17.7 DF; Site: Beaver Creek Unit MD Reference: BCU-12A @ 167.30usft(Saxon169(149.6 GL+17.7 DF; Well: Beaver CK Unit 12 North Reference: True Wellbore: BCU-12A Survey Calculation Method: Minimum Curvature Design: BCU-12A Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,435.30 18.40 53.90 3,418.44 3,251.14 99.71 128.14 2,433,289.23 315,455.43 3.98 61.12 MWD(1) 3,498.30 19.10 54.30 3,478.10 3,310.80 111.58 144.54 2,433,300.84 315,472.02 1.13 69.39 MWD(1) 3,562.30 18.90 53.90 3,538.61 3,371.31 123.80 161.42 2,433,312.80 315,489.09 0.37 77.89 MWD(1) 3,625.30 19.00 54.00 3,598.20 3,430.90 135.84 177.96 2,433,324.58 315,505.82 0.17 86.20 MWD(1) 3,687.30 19.20 54.00 3,656.79 3,489.49 147.76 194.37 2,433,336.24 315,522.42 0.32 94.45 MWD(1) 3,751.30 19.70 53.90 3,717.13 3,549.83 160.31 211.60 2,433,348.51 315,539.84 0.78 103.10 MWD(1) 3,814.30 19.70 54.00 3,776.45 3,609.15 172.80 228.77 2,433,360.74 315,557.20 0.05 111.72 MWD(1) 3,877.30 19.70 53.80 3,835.76 3,668.46 185.32 245.93 2,433,372.98 315,574.56 0.11 120.33 MWD(1) 3,940.30 19.40 54.20 3,895.13 3,727.83 197.71 262.99 2,433,385.10 315,591.80 0.52 128.90 MWD(1) 4,003.30 19.20 54.40 3,954.59 3,787.29 209.86 279.90 2,433,396.99 315,608.90 0.33 137.47 MWD(1) 4,066.30 18.90 54.20 4,014.14 3,846.84 221.86 296.60 2,433,408.73 315,625.79 0.49 145.93 MWD(1) 4,129.30 19.40 54.10 4,073.65 3,906.35 233.96 313.35 2,433,420.57 315,642.72 0.80 154.39 MWD(1) 4,192.30 19.80 53.80 4,133.00 3,965.70 246.40 330.43 2,433,432.73 315,660.00 0.65 162.96 MWD(1) 4,255.30 19.60 53.90 4,192.31 4,025.01 258.93 347.58 2,433,444.99 315,677.35 0.32 171.55 MWD(1) 4,317.30 19.10 53.90 4,250.81 4,083.51 271.03 364.18 2,433,456.83 315,694.13 0.81 179.87 MWD(1) 4,380.30 18.80 54.10 4,310.39 4,143.09 283.06 380.73 2,433,468.60 315,710.87 0.49 188.20 MWD(1) 4,443.30 19.40 53.00 4,369.93 4,202.63 295.31 397.31 2,433,480.59 315,727.64 1.11 196.43 MWD(1) 4,506.30 19.80 51.70 4,429.28 4,261.98 308.22 414.04 2,433,493.23 315,744.57 0.94 204.46 MWD(1) 4,569.30 19.70 51.70 4,488.57 4,321.27 321.41 430.75 2,433,506.16 315,761.48 0.16 212.33 MWD(1) 4,632.30 19.80 51.50 4,547.86 4,380.56 334.63 447.43 2,433,519.13 315,778.37 0.19 220.17 MWD(1) 4,696.30 19.60 51.60 4,608.12 4,440.82 348.05 464.33 2,433,532.27 315,795.47 0.32 228.10 MWD(1) %'` 4,758.30 19.20 51.70 4,666.60 4,499.30 360.83 480.48 2,433,544.80 315,811.82 0.65 235.69 MWD(1) V', 4,769.00 19.12 51.73 4,676.70 4,509.40 363.00 483.24 2,433,546.93 315,814.61 0.75 236.99 MWD_InterpAzi+sag(2) 4,839.68 19.99 60.04 4,743.32 4,576.02 376.21 502.79 2,433,559.83 315,834.37 4.12 247.33 MWD_Interp Azi+sag(2) 4,903.18 19.74 67.49 4,803.05 4,635.75 385.74 522.11 2,433,569.05 315,853.84 4.00 259.29 MWD+SC+sag(3) 4,965.03 20.16 74.51 4,861.20 4,693.90 392.58 542.03 2,433,575.59 315,873.86 3.93 273.12 MWD+SC+sag(3) 5,027.30 20.33 81.18 4,919.63 4,752.33 397.11 563.06 2,433,579.78 315,894.96 3.71 289.07 MWD+SC+sag(3) 5,089.28 20.25 82.55 4,977.76 4,810.46 400.15 584.34 2,433,582.49 315,916.28 0.78 305.98 MWD+SC+sag(3) 5,151.10 19.79 81.94 5,035.85 4,868.55 403.00 605.31 2,433,585.01 315,937.30 0.82 322.71 MWD+SC+sag(3) 5,213.97 18.97 81.65 5,095.16 4,927.86 405.98 625.96 2,433,587.67 315,957.99 1.31 339.11 MWD+SC+sag(3) 5,274.81 18.88 80.85 5,152.71 4,985.41 408.98 645.46 2,433,590.36 315,977.54 0.45 354.49 MWD+SC+sag(3) 5,338.66 18.04 81.28 5,213.27 5,045.97 412.12 665.43 2,433,593.19 315,997.55 1.33 370.22 MWD+SC+sag(3) 5,399.76 17.88 80.47 5,271.39 5,104.09 415.11 684.03 2,433,595.89 316,016.20 0.49 384.83 MWD+SC+sag(3) 5,462.06 17.73 83.97 5,330.71 5,163.41 417.69 702.90 2,433,598.17 316,035.10 1.73 399.88 MWD+SC+sag(3) 5,524.53 17.35 89.39 5,390.28 5,222.98 418.79 721.67 2,433,598.97 316,053.89 2.68 415.59 MWD+SC+sag(3) 5,587.56 17.36 93.71 5,450.44 5,283.14 418.28 740.46 2,433,598.17 316,072.67 2.04 432.11 MWD+SC+sag(3) 5,646.93 17.29 97.08 5,507.12 5,339.82 416.62 758.05 2,433,596.24 316,090.23 1.69 448.18 MWD+SC+sag(3) 5,710.21 17.66 100.56 5,567.48 5,400.18 413.70 776.82 2,433,593.02 316,108.95 1.75 465.89 MWD+SC+sag(3) 5,772.66 17.40 104.70 5,627.03 5,459.73 409.60 795.16 2,433,588.63 316,127.23 2.04 483.83 MWD+SC+sag(3) 5,834.41 16.89 111.43 5,686.05 5,518.75 403.97 812.45 2,433,582.74 316,144.42 3.32 501.61 MWD+SC+sag(3) 9/30/2014 12:36:32PM Page 4 COMPASS 5000.1 Build 70 Halliburton Definiiive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 12 Project: Beaver Creek Unit TVD Reference: BCU-12A @ 167.30usft(Saxon169(149.6 GL+17.7 DF; Site: Beaver Creek Unit MD Reference: BCU-12A @ 167.30usft(Saxon169(149.6 GL+17.7 DF; Well: Beaver CK Unit 12 North Reference: True Wellbore: BCU-12A Survey Calculation Method: Minimum Curvature Design: BCU-12A Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 5,893.53 17.10 116.81 5,742.59 5,575.29 396.92 828.20 2,433,575.44 316,160.06 2.68 518.78 MWD+SC+sag(3) 5,958.70 17.31 120.82 5,804.84 5,637.54 387.63 845.08 2,433,565.88 316,176.80 1.85 538.05 MWD+SC+sag(3) 6,017.79 16.71 121.32 5,861.35 5,694.05 378.71 859.88 2,433,556.73 316,191.46 1.05 555.33 MWD+SC+sag(3) 6,079.90 16.46 121.10 5,920.87 5,753.57 369.52 875.05 2,433,547.31 316,206.48 0.42 573.05 MWD+SC+sag(3) 6,142.43 16.43 119.79 5,980.85 5,813.55 360.55 890.31 2,433,538.10 316,221.59 0.60 590.75 MWD+SC+sag(3) 6,204.16 15.73 120.16 6,040.16 5,872.86 352.01 905.12 2,433,529.33 316,236.27 1.15 607.85 MWD+SC+sag(3) 6,266.43 16.23 120.79 6,100.03 5,932.73 343.31 919.89 2,433,520.41 316,250.91 0.85 624.99 MWD+SC+sag(3) 6,328.58 17.91 119.25 6,159.44 5,992.14 334.20 935.69 2,433,511.04 316,266.56 2.80 643.23 MWD+SC+sag(3) 6,390.96 17.92 118.69 6,218.79 6,051.49 324.90 952.48 2,433,501.49 316,283.20 0.28 662.42 MWD+SC+sag(3) 6,453.32 17.23 117.64 6,278.24 6,110.94 316.01 969.08 2,433,492.34 316,299.66 1.22 681.24 MWD+SC+sag(3) 6,514.19 16.63 118.50 6,336.47 6,169.17 307.68 984.72 2,433,483.76 316,315.17 1.07 698.95 MWD+SC+sag(3) 6,576.58 16.65 119.85 6,396.25 6,228.95 298.97 1,000.32 2,433,474.80 316,330.63 0.62 716.82 MWD+SC+sag(3) 6,638.17 16.12 119.92 6,455.34 6,288.04 290.31 1,015.38 2,433,465.91 316,345.55 0.86 734.19 MWD+SC+sag(3) 6,701.18 16.73 121.33 6,515.78 6,348.48 281.23 1,030.71 2,433,456.60 316,360.74 1.16 752.00 MWD+SC+sag(3) 6,762.70 18.23 121.65 6,574.45 6,407.15 271.58 1,046.46 2,433,446.70 316,376.34 2.44 770.48 MWD+SC+sag(3) 6,824.59 17.73 122.68 6,633.32 6,466.02 261.41 1,062.64 2,433,436.28 316,392.35 0.96 789.57 MWD+SC+sag(3) 6,887.97 17.28 121.30 6,693.77 6,526A7 251.31 1,078.80 2,433,425.92 316,408.36 0.97 808.62 MWD+SC+sag(3) 6,947.75 16.71 121.26 6,750.94 6,583.64 242.24 1,093.74 2,433,416.62 316,423.15 0.95 826.09 MWD+SC+sag(3) 7,010.08 16.10 121.50 6,810.73 6,643.43 233.07 1,108.77 2,433,407.22 316,438.03 0.98 843.68 MWD+SC+sag(3) 7,071.67 15.73 121.63 6,869.96 6,702.66 224.23 1,123.16 2,433,398.15 316,452.28 0.60 860.57 MWD+SC+sag(3) 7,133.60 15.63 121.88 6,929.58 6,762.28 215.42 1,137.39 2,433,389.12 316,466.37 0.19 877.30 MWD+SC+sag(3) 7,195.35 14.99 123.23 6,989.14 6,821.84 206.65 1,151.13 2,433,380.14 316,479.98 1.19 893.58 MWD+SC+sag(3) 7,257.90 14.26 123.73 7,049.66 6,882.36 197.94 1,164.31 2,433,371.22 316,493.01 1.18 909.35 MWD+SC+sag(3) 7,320.23 13.90 124.30 7,110.12 6,942.82 189.46 1,176.87 2,433,362.54 316,505.45 0.62 924.47 MWD+SC+sag(3) 7,381.93 13.73 123.06 7,170.04 7,002.74 181.29 1,189.13 2,433,354.18 316,517.58 0.55 939.18 MWD+SC+sag(3) 7,445.53 12.58 123.10 7,231.97 7,064.67 173.39 1,201.26 2,433,346.09 316,529.58 1.81 953.63 MWD+SC+sag(3) 7,506.39 12.32 123.37 7,291.40 7,124.10 166.20 1,212.24 2,433,338.73 316,540.44 0.44 966.73 MWD+SC+sag(3) 7,569.03 11.31 120.50 7,352.71 7,185.41 159.40 1,223.11 2,433,331.77 316,551.21 1.86 979.54 MWD+SC+sag(3) 7,631.92 11.17 120.54 7,414.39 7,247.09 153.18 1,233.67 2,433,325.38 316,561.67 0.22 991.80 MWD+SC+sag(3) 7,693.55 9.45 119.14 7,475.02 7,307.72 147.68 1,243.23 2,433,319.73 316,571.14 2.82 1,002.83 MWD+SC+sag(3) 7,756.19 9.32 116.64 7,536.83 7,369.53 142.90 1,252.26 2,433,314.81 316,580.09 0.68 1,013.03 MWD+SC+sag(3) 7,816.27 7.98 116.41 7,596.22 7,428.92 138.87 1,260.34 2,433,310.65 316,588.11 2.23 1,022.05 MWD+SC+sag(3) 7,875.11 7.20 119.46 7,654.55 7,487.25 135.24 1,267.21 2,433,306.91 316,594.92 1.49 1,029.82 MWD+SC+sag(3) 7,940.66 5.43 120.49 7,719.70 7,552.40 131.64 1,273.46 2,433,303.22 316,601.12 2.71 1,037.03 MWD+SC+sag(3) 8,003.61 2.73 110.32 7,782.48 7,615.18 129.61 1,277.43 2,433,301.13 316,605.06 4.42 1,041.48 MWD+SC+sag(3) 8,065.55 2.05 113.87 7,844.37 7,677.07 128.65 1,279.83 2,433,300.13 316,607.44 1.12 1,044.04 MWD+SC+sag(3) 8,127.44 0.61 122.21 7,906.24 7,738.94 128.03 1,281.12 2,433,299.49 316,608.72 2.34 1,045.47 MWD+SC+sag(3) 8,187.52 0.54 76.16 7,966.32 7,799.02 127.92 1,281.67 2,433,299.38 316,609.26 0.76 1,045.99 MWD+SC+sag(3) 8,248.38 0.43 126.92 8,027.17 7,859.87 127.85 1,282.13 2,433,299.30 316,609.72 0.70 1,046.43 MWD+SC+sag(3) 8,310.25 0.56 131.91 8,089.04 7,921.74 127.51 1,282.54 2,433,298.95 316,610.13 0.22 1,046.95 MWD+SC+sag(3) 9/30/2014 12:36:32PM Page 5 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 12 Project: Beaver Creek Unit TVD Reference: BCU-12A @ 167.30usft(Saxon169(149.6 GL+17.7 DF; Site: Beaver Creek Unit MD Reference: BCU-12A @ 167.30usft(Saxon169(149.6 GL+17.7 DF' Well: Beaver CK Unit 12 North Reference: True Wellbore: BCU-12A Survey Calculation Method: Minimum Curvature Design: BCU-12A Database: Sperry EDM-NORTH US+CANADA Survey i Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 8,374.24 0.77 126.78 8,153.03 7,985.73 127.05 1,283.11 2,433,298.48 316,610.70 0.34 1,047.69 MWD+SC+sag(3) 8,437.02 0.65 102.24 8,215.80 8,048.50 126.72 1,283.80 2,433,298.14 316,611.38 0.52 1,048.44 MWD+SC+sag(3) 8,498.96 0.75 131.70 8,277.74 8,110.44 126.37 1,284.45 2,433,297.78 316,612.02 0.60 1,049.18 MWD+SC+sag(3) 8,562.44 0.68 111.13 8,341.21 8,173.91 125.96 1,285.11 2,433,297.36 316,612.67 0.42 1,049.95 MWD+SC+sag(3) 8,623.74 1.18 128.73 8,402.50 8,235.20 125.44 1,285.94 2,433,296.82 316,613.50 0.93 1,050.94 MWD+SC+sag(3) 8,686.33 0.82 114.88 8,465.09 8,297.79 124.84 1,286.85 2,433,296.22 316,614.40 0.69 1,052.02 MWD+SC+sag(3) 8,748.46 0.95 112.37 8,527.21 8,359.91 124.46 1,287.73 2,433,295.82 316,615.27 0.22 1,052.97 MWD+SC+sag(3) 8,810.93 1.21 103.27 8,589.67 8,422.37 124.11 1,288.85 2,433,295.45 316,616.39 0.50 1,054.12 MWD+SC+sag(3) 8,872.84 1.27 115.56 8,651.56 8,484.26 123.67 1,290.10 2,433,294.99 316,617.63 0.44 1,055.43 MWD+SC+sag(3) 8,935.04 1.83 101.95 8,713.74 8,546.44 123.16 1,291.70 2,433,294.46 316,619.22 1.07 1,057.06 MWD+SC+sag(3) 8,995.21 2.00 105.91 8,773.88 8,606.58 122.68 1,293.65 2,433,293.94 316,621.16 0.36 1,058.99 MWD+SC+sag(3) 9,057.13 1.92 101.18 8,835.76 8,668.46 122.18 1,295.70 2,433,293.41 316,623.21 0.29 1,061.02 MWD+SC+sag(3) 9,118.98 1.08 92.64 8,897.59 8,730.29 121.95 1,297.30 2,433,293.16 316,624.80 1.40 1,062.52 MWD+SC+sag(3) 9,181.90 1.21 95.28 8,960.50 8,793.20 121.86 1,298.56 2,433,293.05 316,626.06 0.22 1,063.65 MWD+SC+sag(3) 9,245.09 1.86 82.89 9,023.66 8,856.36 121.93 1,300.24 2,433,293.09 316,627.74 1.15 1,065.08 MWD+SC+sag(3) 9,307.74 1.56 94.41 9,086.28 8,918.98 121.99 1,302.10 2,433,293.12 316,629.60 0.73 1,066.66 MWD+SC+sag(3) 9,367.54 2.07 90.51 9,146.05 8,978.75 121.92 1,303.99 2,433,293.02 316,631.49 0.88 1,068.33 MWD+SC+sag(3) 9,431.33 1.77 102.83 9,209.81 9,042.51 121.69 1,306.10 2,433,292.76 316,633.60 0.80 1,070.27 MWD+SC+sag(3) 9,493.02 2.07 99.62 9,271.46 9,104.16 121.29 1,308.13 2,433,292.33 316,635.62 0.52 1,072.23 MWD+SC+sag(3) 9,555.19 1.76 110.70 9,333.60 9,166.30 120.77 1,310.13 2,433,291.77 316,637.61 0.77 1,074.22 MWD+SC+sag(3) 9,615.22 2.32 104.73 9,393.59 9,226.29 120.13 1,312.17 2,433,291.11 316,639.64 1.00 1,076.30 MWD+SC+sag(3) 9,679.48 2.19 108.81 9,457.80 9,290.50 119.40 1,314.59 2,433,290.34 316,642.05 0.32 1,078.76 MWD+SC+sag(3) 9,740.15 2.01 119.73 9,518.43 9,351.13 118.50 1,316.61 2,433,289.41 316,644.05 0.72 1,080.96 MWD+SC+sag(3) 9,761.76 2.45 121.18 9,540.02 9,372.72 118.08 1,317.33 2,433,288.97 316,644.77 2.05 1,081.81 MWD+SC+sag(3) 9,800.00 2.45 121.18 9,578.23 9,410.93 117.23 1,318.73 2,433,288.10 316,646.16 0.00 1,083.44 PROJECTED to TD Checked By: Patrick Walker �„»� .,- Approved By: Cary Taylor Date: 30 Sep 2014 9/30/2014 12:36:32PM Page 6 COMPASS 5000.1 Build 70 • BCU-12A Definitive Surveys H HEADER INFORMATION H COMPANY : Hilcorp Energy Company H FIELD : Beaver Creek Unit H SITE : Beaver Creek Unit H WELL : Beaver CK Unit 12 H WELLPATH: Rig: BCU-12A H DEPTHUNT: usft H SURVDATE: 7/17/2014 H H WELL INFORMATION H WELL EW MAP : 315325.75 H WELL NS MAP : 2433191. 54 H DATUM ELEVN : 167.30 H VSECT ANGLE : 120.00 H VSECT NORTH : 0.00 H VSECT EAST : 0.00 H H SURVEY TYPE INFORMATION H 165.30 - 4758.30 BCU 12 : MWD H 4769.00 - 4839.68 BCU-12A RIG SURVEYS : MWD_INTERP AZI+SAG H 4903.18 - 9761.76 BCU-12A (MWD+SC+SAG : MWD+SC+SAG H H SURVEY LIST H MD INC AZI TVD NS EW 17.70 0.00 0.00 17.70 0.00 0.00 165.30 0.10 113.00 165.30 -0.05 0.12 221.30 0.20 341.30 221.30 0.02 0.13 281.30 0.60 306.90 281.30 0.31 -0.15 342.30 0.40 319.40 342.30 0.66 -0. 55 402.30 0.30 314.20 402.29 0.93 -0.80 462.30 0.40 266.40 462.29 1.03 -1.12 523.30 0.70 311.10 523.29 1.26 -1.61 583.30 0.60 272.60 583.29 1. 52 -2.20 643.30 0.90 280.70 643.28 1.62 -2.98 734.30 1.30 291.30 734.27 2.13 -4.64 799.30 0.70 273.80 799.26 2.42 -5.72 862.30 1.20 292.60 862.25 2.70 -6.72 925.30 0.80 276.60 925.24 3.00 -7.76 989.30 0.40 286.40 989.23 3.12 -8.42 1052.30 0. 50 280.50 1052.23 3.23 -8.90 1115.30 0.10 158.20 1115.23 3.23 -9.15 1176.30 0. 50 66.10 1176.23 3.29 -8.89 1240.30 0.20 140.80 1240.23 3.31 -8. 56 1302.30 0.20 131.10 1302.23 3.16 -8.41 1365.30 0.20 127.40 1365.23 3.02 -8.24 1428.30 0.30 141.20 1428.23 2.82 -8.05 1491.30 0. 50 51.80 1491.23 2.87 -7.73 1554.30 0.30 25.80 1554.23 3.18 -7.45 1617.30 0.20 349.30 1617.22 3.44 -7.39 1681.30 0.30 134.30 1681.22 3.43 -7.30 1744.30 0.60 103.90 1744.22 3.24 -6.86 1806.30 0.20 29.30 1806.22 3.26 -6.49 1867.30 0.70 81.90 1867.22 3.40 -6.07 1932.30 0.50 64.70 1932.22 3. 58 -5.42 1995.30 0.20 12. 50 1995.21 3.80 -5.15 2043.30 0.30 56.00 2043.21 3.95 -5.02 2174.30 0.30 65.60 2174.21 4.29 -4.43 2238.30 0.30 105.00 2238.21 4.31 -4.11 2301.30 0.10 99.00 2301.21 4.26 -3.90 2367.30 0.40 110.60 2367.21 4.17 -3.63 2430.30 0.30 84.20 2430.21 4.11 -3.26 2490.30 0.90 37.00 2490.21 4. 50 -2.82 2553.30 3.00 43.80 2553.17 6.09 -1.38 Page 1 BCU-12A Definitive surveys 2616.30 4.80 49.30 2616.02 9.00 1.76 2690.30 6.20 53.30 2689.68 13.41 7.31 2743.30 6.70 54.30 2742.34 16.92 12.12 2806.30 7.20 55.70 2804.88 21.29 18.36 2869.30 8.60 55.80 2867.28 26.16 25. 52 2932.30 9.80 55.20 2929.47 31.87 33.82 2996.30 10.60 55.00 2992.45 38.35 43.12 3058.30 11.10 55.40 3053.35 45.01 52.70 3121.30 12.30 55.20 3115.04 52.29 63.20 3185.30 13.20 54.60 3177.46 60.41 74.76 3247.30 14. 50 54.20 3237.65 69.05 86.82 3310.30 15.30 53.00 3298. 53 78.67 99.86 3372.30 15.90 53.20 3358.25 88.68 113.19 3435.30 18.40 53.90 3418.44 99.71 128.14 3498.30 19.10 54.30 3478.10 111. 58 144. 54 3562.30 18.90 53.90 3538.61 123.80 161.42 3625.30 19.00 54.00 3598.20 135.84 177.96 3687.30 19.20 54.00 3656.79 147.76 194.37 3751.30 19.70 53.90 3717.13 160.31 211.60 3814.30 19.70 54.00 3776.45 172.80 228.77 3877.30 19.70 53.80 3835.76 185.32 245.93 3940.30 19.40 54.20 3895.13 197.71 262.99 4003.30 19.20 54.40 3954. 59 209.86 279.90 4066.30 18.90 54.20 4014.14 221.86 296.60 4129.30 19.40 54.10 4073.65 233.96 313.35 4192.30 19.80 53.80 4133.00 246.40 330.43 4255.30 19.60 53.90 4192.31 258.93 347. 58 4317.30 19.10 53.90 4250.81 271.03 364.18 4380.30 18.80 54.10 4310.39 283.06 380.73 4443.30 19.40 53.00 4369.93 295.31 397.31 4506.30 19.80 51.70 4429.28 308.22 414.04 4569.30 19.70 51.70 4488. 57 321.41 430.75 4632.30 19.80 51. 50 4547.86 334.63 447.43 4696.30 19.60 51.60 4608.12 348.05 464.33 4758.30 19.20 51.70 4666.60 360.83 480.48 4769.00 19.12 51.73 4676.70 363.00 483.24 4839.68 19.99 60.04 4743.32 376.21 502.79 4903.18 19.74 67.49 4803.05 385.74 522.11 4965.03 20.16 74. 51 4861.20 392.58 542.03 5027.30 20.33 81.18 4919.63 397.11 563.06 5089.28 20.25 82. 55 4977.76 400.15 584.34 5151.10 19.79 81.94 5035.85 403.00 605.31 5213.97 18.97 81.65 5095.16 405.98 625.96 5274.81 18.88 80.85 5152.71 408.98 645.46 5338.66 18.04 81.28 5213.27 412.12 665.43 5399.76 17.88 80.47 5271.39 415.11 684.03 5462.06 17.73 83.97 5330.71 417.69 702.90 5524. 53 17.35 89.39 5390.28 418.79 721.67 5587. 56 17.36 93.71 5450.44 418.28 740.46 5646.93 17.29 97.08 5507.12 416.62 758.05 5710.21 17.66 100. 56 5567.48 413.70 776.82 5772.66 17.40 104.70 5627.03 409.60 795.16 5834.41 16.89 111.43 5686.05 403.97 812.45 5893.53 17.10 116.81 5742. 59 396.92 828.20 5958.70 17.31 120.82 5804.84 387.63 845.08 6017.79 16.71 121.32 5861.35 378.71 859.88 6079.90 16.46 121.10 5920.87 369. 52 875.05 6142.43 16.43 119.79 5980.85 360. 55 890.31 6204.16 15.73 120.16 6040.16 352.01 905.12 6266.43 16.23 120.79 6100.03 343.31 919.89 6328.58 17.91 119.25 6159.44 334.20 935.69 6390.96 17.92 118.69 6218.79 324.90 952.48 6453.32 17.23 117.64 6278.24 316.01 969.08 Page 2 BCU-12A Definitive Surveys 6514.19 16.63 118. 50 6336.47 307.68 984.72 6576.58 16.65 119.85 6396.25 298.97 1000.32 6638.17 16.12 119.92 6455.34 290.31 1015.38 6701.18 16.73 121.33 6515.78 281.23 1030.71 6762.70 18.23 121.65 6574.45 271.58 1046.46 6824. 59 17.73 122.68 6633.32 261.41 1062.64 6887.97 17.28 121.30 6693.77 251.31 1078.80 6947.75 16.71 121.26 6750.94 242.24 1093.74 7010.08 16.10 121. 50 6810.73 233.07 1108.77 7071.67 15.73 121.63 6869.96 224.23 1123.16 7133.60 15.63 121.88 6929.58 215.42 1137.39 7195.35 14.99 123.23 6989.14 206.65 1151.13 7257.90 14.26 123.73 7049.66 197.94 1164.31 7320.23 13.90 124.30 7110.12 189.46 1176.87 7381.93 13.73 123.06 7170.04 181.29 1189.13 7445. 53 12. 58 123.10 7231.97 173.39 1201.26 7506.39 12.32 123.37 7291.40 166.20 1212.24 7569.03 11.31 120.50 7352.71 159.40 1223.11 7631.92 11.17 120. 54 7414.39 153.18 1233.67 7693. 55 9.45 119.14 7475.02 147.68 1243.23 7756.19 9.32 116.64 7536.83 142.90 1252.26 7816.27 7.98 116.41 7596.22 138.87 1260.34 7875.11 7.20 119.46 7654. 55 135.24 1267.21 7940.66 5.43 120.49 7719.70 131.64 1273.46 8003.61 2.73 110.32 7782.48 129.61 1277.43 8065. 55 2.05 113.87 7844.37 128.65 1279.83 8127.44 0.61 122.21 7906.24 128.03 1281.12 8187.52 0.54 76.16 7966.32 127.92 1281.67 8248.38 0.43 126.92 8027.17 127.85 1282.13 8310.25 0.56 131.91 8089.04 127.51 1282. 54 8374.24 0.77 126.78 8153.03 127.05 1283.11 8437.02 0.65 102.24 8215.80 126.72 1283.80 8498.96 0.75 131.70 8277.74 126.37 1284.45 8562.44 0.68 111.13 8341.21 125.96 1285.11 8623.74 1.18 128.73 8402. 50 125.44 1285.94 8686.33 0.82 114.88 8465.09 124.84 1286.85 8748.46 0.95 112.37 8527.21 124.46 1287.73 8810.93 1.21 103.27 8589.67 124.11 1288.85 8872.84 1.27 115. 56 8651. 56 123.67 1290.10 8935.04 1.83 101.95 8713.74 123.16 1291.70 8995.21 2.00 105.91 8773.88 122.68 1293.65 9057.13 1.92 101.18 8835.76 122.18 1295.70 9118.98 1.08 92.64 8897. 59 121.95 1297.30 9181.90 1.21 95.28 8960. 50 121.86 1298.56 9245.09 1.86 82.89 9023.66 121.93 1300.24 9307.74 1. 56 94.41 9086.28 121.99 1302.10 9367. 54 2.07 90. 51 9146.05 121.92 1303.99 9431.33 1.77 102.83 9209.81 121.69 1306.10 9493.02 2.07 99.62 9271.46 121.29 1308.13 9555.19 1.76 110.70 9333.60 120.77 1310.13 9615.22 2.32 104.73 9393. 59 120.13 1312.17 9679.48 2.19 108.81 9457.80 119.40 1314. 59 9740.15 2.01 119.73 9518.43 118.50 1316.61 9761.76 2.45 121.18 9540.02 118.08 1317.33 9800.00 2.45 121.18 9578.23 117.23 1318.73 Page 3 Well BC4-12A Grid Conver 0.897282 Date 30-Sep-14 HALLIEURTDN DDI 5.'_07 .67.3 ft V S Plane 120.00° Unwrapped Displaceme 72 Sperry Origins Services 11D Inc Azimuth TVDSS TN"D Local Coordinates Map Coordinates DLS Vertical SV)NNorthing Easting Northing Lasting (°/100usf Section Comments (WI) 0_ ei (usft) 040 (usft) (usft) (nsft) 0,40 0 (ucft 1 17.70 0.00 0.00 -149.60 17.70 0.00 N 0,00 E 315325.75 E 2433191.54 N 0.00 0.09 2 165.30 0.10 113.00 -2.00 16530 -0.05 S 0.12 0 315325.87 E 243319149 N 0.07 0.13 MWD(1) 3 221.30 0.20 341_,0 54.00 221.30 0.02 N 0.13 E 315325.88 E 2433191.56 N 0.49 0.10 4 281 30 0.60 306.90 114.00 281.30. 0.31 N -0.15 W 315325 60 E:62433191.85 N 0.75 1 3 i 5 342.30 0.40 19.40 175.00 34240 0.66 N -0.55 W 315325 22 E ;2433192 21 N 0.37 1 t 6 402.30 0.30 314.20 234.99 tra r.? 4 0.93 N -0.80 W 315324 97 E'612433192.48 N 0.17„pal 7 162.30 0.40 266.40 294.99. 4$2.29 1.03 N -1.12 W 315324.65 E 2433192.591N 0.50` . -'.48 8 523.30 0.70 311.10 355.99-: 523.29 1.26 N -1.61 Vs 315324.16 E 2433192.83 N 0.82 -2.03 9 583.0 0.60 272.60 415.99 583.29 1.52 N -2.20 W 315323.58 E 2433193.09 N 0.73 -2.66 10 1,43.3(1 0.90 280.70 475.98 643.28 1.62 N -2.98 Vs 315322.80 1 2433193.20 N 0.53 -3.39 11 734.30 1.30 291.30 566.97 734.27 2.13 N -4.64 W 315321.14 I. 2433193.74 N 0.49 -5.08 12 799.30 0.70 273.80 63196 799.26 2.42 N -5.72 W 315320.07 I'. 2433194 05 N 1.03 -6.17 13 862.30 1.20 292.60 69495 86225 2.70 N -6.72 W 315319.08 1 2433194 34 N 0.93 -7.17 14 925.30 0.80 276.60 757.94 925.24 3.00 N -7.76 W 315318.04 E 2433194 66 N 0.77 -8.22 15 989.30 0.40 286.40 82193 989.23; 3.12 N -8.42 Vs 315317.38 E 2433194.79 N 0.64 -8.85 16 1052.30 0.50 280.50 884 93 105 3.23 N -8.90 W 315316.90 1 2433194 91 N 0.17 17 I 1 1 30 0.10 158.20 94793 11 3.23 N -9.15 W 315316.65 E 2433194 91 N 0.89 !! a 18 1176.30 050 66.10 1008.93 11 �- 3.29 N -8 89 315316.91 E,2433194 97 N 0.84 4�,04a dt 2 i„ p - .3: v 19 40.30 020 140.80 1072.93 Al 3.31 N -8.561f, 315317.24 E6433194 99 N 0.76 ' 1 20 1302 30 0.20 131.10 1134.93 1302.21 3.16 N -8.41 W 315317.39 E 2433194.83 N 0.05 21 130530 0.20 127.40 1197.93 1365 23 3.02 N -8.24 W 315317.56 E 2433194.69 N 0.02 22 1128_; 0 0.30':- 141.20 1260.93 1 t�R.23 2.82 N -8.05\\ 315317.74): �433194A9 N 0.18 -8.39 23 1191.30 0.50 51.80 1323.93 1491.23 2.87 N -7.73 W 315318.06 E 2433194.53 N 0.92 -8.13 24 1554.30 0 31) 25.80 1386.93 1554.23 3.18 N -7.45\4 315318.36 E 2433194.84 N 0.42 -8.04 25 1617.30 0.20 349.30 1449.92 1617.22 3.44 N -7.39 W 315318.41 E 2433195.10 N 0.29 -8.12 26 1681.30 0.30 134.30 1513.92 1681.22' 3.43 N -7.30 W 315318.51 E 2433195.09 N 0.75 -8.03 27 1744.30 0.60 103.90 1576.92 1744.22 3.24 N -6.86 W 315318.95 E 2433194.89 N 0.59 -7.56 28 ' 1806.30 0.20 29.30 1638.92 1806.22 3.26 N -6.49 W 315319.31 E 2433194.90 N 0.94 -7.25 29 1867.30 0.70 81.90 1699.92 1867.22 3.40 N -6.07 W 315319.74 E243 3195.03 N 0.98 -6.96 30 1932.30 0.50 7 9 asu 1764.92 1932.22 3.58 N -5.42 W 315320.39 E'2433195 20 N 0.41 -6.48 31 1995.30 0.2017 "1°* 1827.91 1995.21 3.80 N -5.15 W 315320.67 I 2433195.42 N 0.65,-6.36 32 2043130: 0.30 '-'5..V1 187591 2043.21 3.95 N -5.02 W 315320.79 E '2433195.57 N 0.43 -6.33 33 2087.30 0.30 59.22 191991 2087.21 4.08 N -4.83 W 315320.99 0 2433195.69 N 0.04 -6.22 13 3/8" 34 2174.30 0.30 65.60 2006.91 2174.21 4.29 N -4.43 W 315321.39 0 2433195.90 N 0.04 -5.98 35 2238.30 0.30 105.00 2070.91 2238.2)(1 4.31 N -4.11 W 315321.71 E 2433195.92 N 0.32 -5.72 36 2301.30 0.10 99.00 2133.91 2301.21 4.26 N -3.90 W 315321.92 E 2433195.86 N 0.32 -5.51' 37 2367.30 0.40 110.60 2199.91 2367.21 4.17 N -3.63 W 315322.19 E 2433195 77 N 0.46 -5.23 38 2430.30 0.30 84.20 2262.91 2430.21 4.11 N -3.26 W 315322.56 E 2433195.70 N 0.30 -4.88 39 2490.30 0.90 37.00 2322.91 2490.21 4.50 N -2.82 W 315323.01 E 2433196.09 N 1.22 -4.69 40 2553.30 3.00 43.80 2385.87 2553.17 6.09 N -1.38 Vs 315324.47 E 2433197.65 N 3.35 -4.24 41 2616.30 4.80 49.30 2448.72 26 16.02 9.00 N 1.76 E 315327.65 E 24 3200 51 N 2.91 '297. 42 1 2690.30 6.20: 53.30 2522.38 2689.6& 13.41 N 4 ,7,4„.g 315333.27 E ,2433204 113,y 1.96 t,,.s Page 1 of 4 4Local Coordinates Map Coordinates 1)14F 'tical ''" iV1U Inc Azimuth 7VUSS T' -)z SVY N Northing lasting Northing Fasting C/100 'tion Comments (mit) (°) (°) (usft) pr. (usft) (usft) (tat) (usft) t) ins()) t 43 2743.30 6.70 54.30 2575.04 2742.34 16.92 N 12.12 E 315338 13 E 2433208.27 N 0.97 2.04 44 2806.30 7.20 55.70 2637.58 2804.88 21.29 N 1836 E 315344.45 E 2433212.54 N 084 5.26 45 2869.30 8.60 55.80 2699.98 2867,23' 26.16 N 25.52 E 315351.68 I[ 2433217.30 N 222 9.02 46 2932.30 9.80 55.20 2762.17 2929.47 31.87 N 33.82 E 315360.07 E 2433222.88 N 1.91 13.36 47 2996 30 10.60 55.00 2825.15; 2992,45 38.35 N 43.12 E 315369.46 E .2433229.21 N 1.25 18.16 48 3058.30 11.10 55.40 2886.05 3053 45.01 N 52.70 E 315379 15 E„ 24 235 72 N 0.82 23.13 49 3121.30 12.30 55.20 2947.74 311 it,' 52.29 N 63,20 E 315389 76 E l'''2433242.83 N 1.91 28.59 50 3185.30 13.20 54.60 3010.16 1 60.41 N 74,76 E 315401 45 E 2433250 77 N 1.42 51 3247.30 14.50 54.20 3070.35 32374 69.05 N 86,82 E 315413.64 E 2433259 22 N 2.10 52 3310.30 15.30 53.00 3131.23 3298.53 78.67 N 99,86 E 315426.83 P. 2433268.64 N 1.36 47.14 53 372.30 15.90 53.20 3190.95 3358.25 88.68 N 113.19 E 315440.32 I 243327844 N 0.97 53.69 54 343530 18.40 53.90 3251.14 3418.44 99.71 N 128.14 E 315455.43 f 2433289.23 N 3.98 61.12 55 3498.30 19.10 54.30 3310.80 3478.10 111.58 N 144.54 E 315472.02 F 2433300 84 N 1.13 69.39 56 3562.30 18.90 53.90 3371.31 3538.61 123.80 N 161.42 E 315489.09 E 2433312.80 N 0.37 77.89 57 3625.30 19.00 54.00 3430.90 3598.20 135.84 N 177.96 E 315505.82 E 2433324.58 N 0.17 86.20 58 3687.30 19.20 54.00 3489.49 3656.79 147.76 N 194.37 E 315522.42 L 24 336.24 N 0.32 94.45 59 3751.30 19.70. 53.90 3549.83 3717.13 160.31 N 211.60 E 315539.84 E'24 3348.51 N 0.78 103.10 60 3814.30 19.70` 54.00 3609.15 3776.45 172.80 N 228.77 E 315557.20 E X2433360.74 N 0.05 111,72. 61 3877.30 19.701 53.80 3668.46 3835.76 185.32 N 245.93 E 315574 56 IC 2433372.98 N 0.11 1:4 62 39-10.30 19.40 54.20 3727.83 389h4 197.71 N 262.99 E 315591 80 1' 2433385 1 1 N 0.52 1 t.. 63 4003.30 19.20 54.40 3787.29 344,M 209.86 N 27990 E 315608 90 F. 2433396 99 N 0.33 1 64 406630 18.90 54.20 3846.84 4014.1 221.86 N 296.60 E 315625.79 E<24 3408.73 N 0.49 145.93 65 412930 19.40 54.10 3906.35 4073,651,', 233.96 N 313.35 E 315642.73 E 2433420.57 N 0.80 15439 66 419230 19.80 53.80 5965.70 4133,09', 246.40 N 330.43 E 315660.00 E 2433432.73 N 0.65 162.96 67 425530 19.60 53.90 4025.01 4192.31 258.93 N 347.58 E 315677.35 E 2433444.99 N 0.32 171.55 68 4317.30 19.10 53.90 4083.51 4250.81 271.03 N 364.18 E 315694.13 E 2433456.83 N 0.81 179.87 69 4380.30 18.80 54.10 4143.09 431039 283.06 N 380.73 E 315710.87 E 2433468.60 N 0.49 18820 70 4443.30 19.40 53.00 4202.63 4369.93- 295.31 N 397.31 E 315727.64 H 2433 480.59 N 1.11 196.43 71 4506.30 19.80 51.70 4261.98 4429.28 308.22 N 414.04 E 315744.57 E 2433493.23 N 0.94 204.46 72 4569.30 19.70 51.70 4321.27 4488,57 321.41 N 430,75 E 315761.48 L 2433506.16 N 0.16 212.33 73 4632 30 19.80 51.50 4380.56= 454 334.63 N 447.43 E 315778.37 I. 24 519.13 N 0.19 22h 74 4696.30 19.60 51.60 4440.82 46 348.05 N 464.33 E 315795.47 E 24335.227 N 0.32 7i:/f1,,, a` Tie-On 4758.30 19.201 51.70 4499.30 r 466666: 360.83 N 480,48 E 315811 82 E42433544.80 N 0.65 :4 1 4769.00 19.12 51.73 4509.40 4676,70-, 363.00 N 483.24 E 315814 61 E`X243546.93 N 0.75 23•.99 MWD_Intetp Azi+sag(2) 2 4786.00 19.29 53.79 4525.-16 4692.76 366.39 N 487.69 E 315819 12 E 42433550.24 N 4.12 239.16 9 5/8"TOW 3 4839.68 19.99. 60.04 4576.02 4743.32 376.21 N 502.79 E 315834.38 E X2433559.83 N 4.12 247.33 4 4903.18 19.74 67.49 4635.75 4803,05 385.74 N 522.11 E 315853.84 E 2433569.05 N 4.00 259.29\IWD+SC+sag(3) 5 4965.03 20.16 74.51 4693.90 4861.20 392.58 N 542.03 E 315873.86 E 2433575.59 N 3.93 273.12 6 5027.30 20.33 81.18 4752.33 4919.63 397.11 N 563.06 E 315894.96 E 2433579.78 N 3.71 289.07 7 5089.28 2025 82.55 4810.46 4977.76 400.15 N 584.34 E 315916.28 E 2433582.49 N 0.78 305.98 8 5151.10 19.79 81.94 4868.55 5035.85 403.00 N 605.31 E 315937.30 E '2433585.01 N 0.82 322.71 9 5213.97 18.97 81.65 4927.86; 5095.16 405.98 N 625.96 E 315957.99 E�"-,2"433587.67 N 1.31 339.11 10 5274.81 18.88 80.85 4985.41 5152,71 408.98 N 645.46 E 315977.54 E 2433590.36 N 0.45 354.49 11 5338.66 18.04 81.28 5045.97 5213,27 412.12 N 665,43 E 315997.56 E 2433593 19 N 1.33 370.221 12 5399.76 17.88 80.47 5104.094 N 0.49.I?�I�s� 71 39 415.11 N 684.03 E 316016.20 E t e 3 � � �s� Page 2 of 4 MU Inc Azimuth "fYDBg •I'. Loral Coordinates Map Coordinates DI.S `tical SYY n Northing Fasting Northing ' Fasting 0100 tion Comments (nsft) (°) (°) (nsf) (a: Oat) (list)) (usft) (list)) 11 tusft) 13 5462.06 17 73 83.97 5163.41 5330.71 417.69 A 702.90 E 316035.1 1 11 2433598.17 N 1.73 399.88 14 5524.53 17.35 89.39 5222.98 5390.28 418.79 N 721.67 E 316053.90 I[ 2433598.98 N 2.68 415.59 15 5587.56 17.36 93.71 5283.14 5450.44 418.28 N 740.46 F 316072.67 1: 2433598.17 N 2.04 432.11' 16 5646.93 17.29 97.08 5339.82 5507.12 416.62 N 758.05 E 316090.23 F 2433596.24 N 1.69 448.18 17 5710.21 17.66 100.56 5400.18 5567,48 413.70 N 776.82 E 316108.95 1 2433593.03 N 1.75 465.89 18 5772.66 17.40 104.70 5459.73 5627.03 409.60 N 795.16 E 316127.23 1: 2433588.63 N 2.04 483.83 19 5834.41 16.89 111.43 5518.75 5686.05 403.97 N 812.45 E 316144.42 I: 2433582.74 N 3.32 501.61; 20 5893.53 17.10 116.81 5575.29 5742,59 396.92 N 828.20 F 316160.06 I. 2433575.44 N 2.68 51878 21 5958.70 17.31 120.82 5637.54 5804,84 387.63 N 845.08 E 316176.80 I: 2433565.89 N 1.85 538.05 22 6017.79 16.71 121.32 5694.05 5861,35. 378.71 N 859.88:E 316191.46 I: 2433556.73 N 1.05 555.33. 23 6079.90 16.46 121.19 5753.57 5920,87 369.52 N 875.05 E 316206.48 I[ 2433547.31 N 0.42 573.051 24 . 6142.43 16 43 1191 5813.55 5980,85 360.55 N 890.31 F. 316221.60 11 2433538.10 N 0.60 590.75 25 6204.16 15.73 120.1 J 5872.86 6040,16 352.01 N 905.12 F. 316236.27 I 24 529.33 N 1.15 607 85 26 6266.43 16.23 120 5932.73 6100.03 343.31 N 919.89 E 316250.91 I f 24 3520.41 N 0.85 624.99 27 6328.58 17.91 119.25 5992.14 6159.44 334.20 N 935.69 E 316266.56 I: 2433511.04 N 2.80 643.23 28 6390.96 17.92 118.69 6051.49 6218.79 324.90 N 952.48 E 316283.20 I: 2433501.49 N 0.28 662.42 29 645332 17.23 117.64 6110.94 6278.24 316.01 N 969.08 E 316299.66 E 2433492.34 N 1.22 681.24 30 6514.19 16.63 118.50 6169.17 6336.47 307.68 N 984.72 E 316315.17 I' 2433483.76 N 1.07 698.95 31 6576.58 16.65 119.85 6228.95 6396.25 298.97 N 1000.32 F. 316330.63 F 2433474.80 N 0.62 716.82 32 6638.17 16.12 119.92 6288.04 6455.34 290.31 N 1015.38 E 316345.55 E 2433465.91 N 0.86 734.19 33 6701.18 16.73 121.33 6348.48 6515.78 281.23 N 1030.71 E 316360.74 F 2433456.60 N 1.16 752.00 34 6762.70 18.2 3 121.65 6407.15 6574.45 271.58 N 1046.46 E 316376.34 E 2433446.70 N 2.44 770.48 35 6824.59 17.73 122.68 6466.02 6633.32 261.41 N 1062.64 E 316392.35 E 2433436.28 N 0.96 789.57 36 6887.97 17.28 121.30 6526.47 6693.77. 251.31 N 1078.80 E 316408.36 F: 2433425.92 N 0.97 808.62: 37 6947.75 16.71 121.26 6583.64 6750.94 242.24 N 1093.74 E 316423.15 EC 2433416.62 N 0.95 826.09 38 7010.08 16.10 121.50 6643.4 3 6810.73. 233.07 N 1108.77 E 316438.03 1' 2433407.22 N 0.98 843.68 39 7071.67 15.73 121.63 6702.66 6869.96 224.23 N 1123.16 E 316452.28 F 2433398.15 N 0.60 860.57 40 7133.60 15.6 3 121.88 6762.28 6929.58 215.42 N 1 13 7.39 E 316466.37 F. 2433389.12 N 0.19 877.30 41 7195.35 14.99 123.23 6821.84 6989.14 206.65 N 1151.13 E 316479.98 E 2433380.14 N 1.19 893.58 42 7257.90 14.26 123.73 6882.36 7049,66 197.94 N 1164.31 E 316493.01 E 2433371.22 N 1.18 90935 43 '. 7320.23 13.90 124.30 6942.82 7110.12 189.46 N 1176.87 E 316505.45 E 243 3362.55 N 0.62 924.47 44 7381.93 13.73 123.06 7002.74 7170.04 181.29 N 1189.13 E 316517.58 F 2433354.18 N 0.55 939.18 45 7445.53 12.58 123.10 7064.67 7231.97 173.39 N 1201.26 E 316529.58 E 2433346.09 N 1.81 953.63 46 7506.39 12.32 123.37 7124.10 7291.40 166.20 N 1212.24 E 316540.44 1: 2433338.73 N 0.44 966.73 47 7569.03 1131 120.50 7185.41 7352,71 159.40 N 1223.11 E 316551.21 1. 2433331.77 N 1.86 979.54 48 7631.92 11.17 120.54 7247.09 7414,39 153.18 N 1233.67 E 316561.67 1: 2433325.38 N 0.22 991.80 49 7693.55 9.45 119.14 7307.72 7475.02 147.68 N 1243.23 E 316571.14 F 2433319.73 N 2.82 1002.83 50 7756.19 9.32 116.64 7369.53 7536.83 142.90 N 1252.26 E 316580.09 E 2433314.81 N 0.68 1013.03 51 7816.27 7.98 116.41 7428.92 7596.22 138.87 N 1260.34 E 316588.11 E 2433310.65 N 2.23 1022.05 52 7875.11 7.20 119.46 7487.25 7654.55 135.24 N 1267.21 E 316594.92 F 2433306.91 N 1.49 1029.82 53 7929.00 5.74 12026 7540.79 7708.09 132.22 N 1272.48E 316600.15 F 2433303.81 N 2.71 1035.89 TPI 54 7940.66 5.43 120,49 7552.40 7719.70 131.64 N 1273 46 316601.12 1[ 2433303 22 N 2.71 1037.03 55 8003.61 2.73 11032, 7615.18 7782.48 129.61 N 1277.43 F 316605.06 1,, 2433301 13 N 4.42 1041.48 56 ' 8012.40 2.63 1104 7623.96 7791.26 129.47 N 1277.82 E 316605.44 I: 2433300.98 N 1.12 1041 89 BCU-12A Tgt 1 57 8065.55 2.05 113.87 7677.07 7844,37 128.65 N 1279.83 F. 316607.44 1: 243 3300.13 N 1.12 1044.04 Page 3 of 4 r local Coordinates Slap Coordinates DLS tical `;° P SID Inc Azimuth TVUSS '1" SVYa Northing Lasting Northing Lasting (%100, tion Comments (usft) (°) (°) (usft) (os usft (usft)) ( ) ;(usft) (nsft) 0 tasfq 58 8127.44 0.61 122.21 7738.04 7906,24 128.03 N 1281.12 E 316608.72 E2433299.49 N 234 1045.47 59 8187.52 0.54 76.16 7799.02 7966.32 127.92 N 1281,67 E 316609.26 E 2433299.38 N 0.76 1045.99 60 8248.38 0.43" 126.92 7859.87' 8027.17 127.85 N 1282.13 E 316609.72 E 2433299.30 N 0.70 1046.43 61 8310.25 0.56 131.91 7921.74 8089.04 127.51 N 1282.54 E 316610.13 E '2433298 95 N 0.22 1046.95 62 837424 0.77 126.78 7985.73 815303127.05 N 1283.11 E 316610.70 E '2433298.48N 0.34 1047.69 63 8437.02 0.65 102.24 8048.50 8215.80 126.72 N 1283.80 E 316611.38 E 24 329814; 0.52 1048.44 64 8498.96 0.75 131.70 8110.44 8277.74 126.37 N 1284.45 E 316612.02 E 24,3297 78 M 0.60 1049.18 65 8562.44 0.68 111.13 8173.91 8341.21, 125.96 N 1285.11 E 316612.67 E 2433297.36 N 0.42 1049.95 66 8623.74 1.18 128.73 823520 8402.50 125.44 N 1285.94 E 316613.50 E 2433296.82 N 0.93 1050.94 67 8686.33 0.82 114.88 8297.79 8465.09 124.84 N 1286.85 E 316614.40 E 2433296.22 N 0.69 1052.02 68 8748.46 0.95 112.37 8359.91 8527.21 124.46 N 1287.73 E 316615.27 E 2433295.82 0.22 1052.97 69 8810.93 1.21 103.27 8422.37 8589.67 124.11 N 1288.85 E 316616.39 E 2133295.451 0.50 1054.12 70 8872.84 1.27 115.56 8484.26 8651.56 123.67 N 1290.10 E 316617.63 E 2433294.9$! 0.44 1055.43 71 8935.04 1.83 101.95 8546.44 8713.74 123.16 N 1291.70 E 316619.22 E 2433294 _-= 1.07 1057.06 72 8993.28 1.99 105.79 8604.65 8771.95 122.70 N 1293.58 6 316621.10 E 2433293 96 i 0.36 1058.93 BCU-12A BHL Tgt 73 8995.21 2.00 - 105.91 8606.58 8773.88 122.68 N 1293.65 6 316621.16 E 24 ,293.94 N 0.36 1058.99 74 9057.13 1.92 101.18 8668.46 8835.76 122.18 N 1295.70 6 316623.21 E 2433293.41 N 0.29 1061.02 75 9118.98 1.08 92.64 8730.29 8897.59 121.95 N 1297.30 6 316624.80 E 2433293 16 N 1.40 1062.52 76 9181.90 1.21 95.28 8793.20 8960.50 121.86 N 1298.56 E 316626.06 E 2433293 05 N 0.22 1063.65 77 9245.09 1.86 82.89 8856.36 9023.66 121.93 N 1300.24 6 316627.74 E 2433293.09A 1.15 1065.08 78 9307.74 1.56 94.41 8918.98 9086.28 121.99 N 1302.10 E 316629.60 F 2433293.12'M 0.73 1066.66 79 9367.54 2.07 90.51 8978.75 9146,05': 121.92 N 1303.99 E 316631.49 E 2433293.02 N 0.88 106833 80 9431.33 1.77 102.83 9042.51 9209.81 121.69 N 1306.10 E 316633.60 E 2433292.76 N 0.80 107027 81 9493.02 2.07 ` 99.62 9104.16 9271,46 121.29 N 1308.13 E 316635.62 E 2433292.33 N 0.52 1072 23 82 9555.10 1.76 110.70 9166.30 9333.60 120.77 N 1310.13 E 316637.61 F 2433291 77 N 0.77 1074.22 83 0615.22 2.32 -.104,73 9226.29 9393.50 120.13 N 1312.17 E 316639.64 E 2433201.11 N 1.00 1076.30 84 9679.48 2.19 108.81 9290.50 9457.80 119.40 N 1314.59 F 316642.05 E 2433290 34 N 0.32 1078.76 85 0740.15 2.01 119.73 9351.13 9518.43 118.50 N 1316.61 E 316644.05 E 2433289.41 N 0.72 1080.96 86 0761.76 2.45, 121.18 9372.72 9540.02 118.08 N 1317.33 6 316644.77 E 2433288.97 N 2.05 1(181.81 87 9800.00 2.45 f 121.18 9410.93_= 9578.23 117.23 N 1318.73 E 316646.16 E 2433288 10 N 0.00 1083.44 13CU-12A BHL Tgt 2 rev!-PROJECTED to TD Page 4 of 4 Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. BCU 12A Date 12-Jul-14 County Kenai Peninsula Borough State Alaska Supv. R Pederson/J Sweetsir CASING RECORD TD 9800.00 Shoe Depth: 9759.79 PBTD: 9675'MD/9457'TVD ' Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 5" DWC Wfd _ 1.62 9,759.79 9,758.17 2 5" 18 L-80 DWC _ 81.12 9,758.17 9,677.05 Float Collar 5" DWC Wfd 1.42 9,677.05 9,675.63 52 5" 18 L-80 DWC 2,110.39 9,675.63 7,565.24 Crossover 5"x 5.5" 18 P-110 DWC Unique 1.69 7,565.24 7,563.55 80 _ 5.5" 17 P-110 DWC 3,310.49 7,563.55 4,253.06 Swell Packer 5.5" 17 P-110 DWC Baker 43.80 4,253.06 4,209.26 5.5" 17 P-110 DWC 4,191.07 4,209.26 18.19 Hanger 5.5"x 11" DWC Cameron _ 0.69 18.19 17.50 Totals Csg Wt.On Hook: 170,000 Type Float Collar: Model 402E No.Hrs to Run: 26 Csg Wt.On Slips: N/A Type of Shoe: Bullnose 303E Casing Crew: Wfd Fluid Description: 9.4 ppg 6%KCL/ PV=14 YP=19 HTHP=11.8 Liner hanger Info(Make/Model): N/A Liner top Packer?: _Yes X No Liner hanger test pressure: N/A Centralizer Placement: Every other jnt first 39 jnts,every jnt for 65 juts,every other jnt for 8 jnts,every 3rd jnt for 23 jets(130 total) CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 10.5 Volume pumped(BBLs) 38 Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry Type: Class"0"Tail Density(ppg) 15.3 Volume pumped(BBLs) 248 Mixing/Pumping Rate(bpm): 5 N Post Flush(Spacer) ( Type: Density(ppg) Rate(bpm): Volume: ce LL Displacement: Type: Fresh Water Density(ppg) 8.34 Rate(bpm): 6 bpm Volume(actual/calculated): 215/214 FCP(psi): 2300 Pump used for disp: Schlumberger pump Plug Bumped? X Yes No Bump press 3000 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 100% Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: 0 Cement In Place At: 1:00 Date: 7/12/2014 Estimated TOC: 4,300 Method Used To Determine TOC: Volume Calculation Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry w Type: a Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): rn Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: Displacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes _No Reciprocated'? _Yes _No %Returns during job Cement returns to surface'? Yes No Spacer returns? Yes No Vol to Surf: _ Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: BCU 12A Days Vs Depth o -BCU 12A ACTUAL BCU 12A Plan 2000 _ --_- 4000 --- F F s .. a 6000 8000 10000 12000 0 5 10 15 20 25 Days BCU 12A MW Vs Depth 0 500 Planned MW vs Depth —Actual MW vs Depth 1000 I _ 1500 J 2000 2500 3000 — 3500 4000 4500 F 5000 L cu 5500 v i 6000 z co co 6500 7000 - 7500 8000 8500 9000 9500 10000 10500 11000 11500 -- -- 8.0 8.5 9.0 9.5 10.0 10.5 11.0 11.5 12.0 Mud Density(ppg) 2_,,_._,0 II Debra Oudean Hilcorp Alaska, LLC GeoTech II 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8337 Ildrnr' iIn+11.a.1.1A. Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATA LOGGED 0/ /2014 Ivl.K.BENDER DATE 09/26/14 RECEIVED SEP 29 2014 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 12A Elog data Prints: ROP Rate of Penetration, DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity, CTN Compensated Thermal Neutron MD DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity, CTN Compensated Thermal Neutron TVD RST-GR-CCL CD 1: Final Well Data 2_1-VI CGM 9/26/2014 10:59 A... File folder DLIS+LAS 9/26/2014 10:59 A... File folder EMF 9/26/2014 10:59 A... File folder PDF 9/26/2014 10:59 A... File folder TIFF 9/26/2014 10:59 A... File folder CD 2: Directional survey data `Z� :\VG I Please include current contact information if different from above. Please acknoledge receipt by si ing nd returning one copy of this transmittal or FAX to 907 777.8337 Received5_ teti Date: 21'4- 6`xo 11 Debra Oudean Hilcorp Alaska, LLC 2. 9 1 GeoTech II 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8337 lielviirp tla41,:i.1.1 I Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATA LOGGED +O/ 1 /207 ti DATE 09/26/2014 M.K.BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender ��^����® Natural Resource Technician (r 333 W 7th Ave Ste 100 SEP 2 9 2Ui�► Anchorage, AK 99501 DATA TRANSMITTAL AOGCC BCU 12A Mudlog data Prints: Final Well Report, DML Logging Data Formation Log 5in MD Formation Log 5in TVD Formation Log 2in MD Formation Log 2in TVD LWD Combo Log 2in MD LWD Combo Log 2in TVD Drilling Dynamics Log 2in MD Drilling Dynamics Log 2in TVD Gas Ratio Log 2in MD Gas Ratio Log 2in TVD CD: Final Well Data ja, Daily Reports 9/26/2014 10:31 A... File folder k DML Data 9/26/2014 10:31 A... File folder ,.: Final Well Report 9/26/2014 10:31 A... File folder k LAS Data 9/26/2014 10:31 A... File folder k Log PDFs 9/26/2014 10:31 A... File folder L Log TIFFs 9/26/2014 10:31 A... File folder 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 4/Received B ��Q:ti v 15cetjDate: air- ate Debra oudean Hilcorp Alaska, LLC Q GeoTech II 3800 Centerpoint Drive, Suite 100 `l 1 (� Anchorage,AK 99503 Tele: 907 777-8337 Pm Ild�nrp U:t.ku.LLt, Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 9/15/2013r c�ec�c�i1 CZc I ?Q 'olecJn� (LQo .� J1E'ASST FIFO To: Alaska Oil & Gas Conservation Commission SEP Z01 . , . . 333 W. 7th Ave. Ste#100 ���� Anchorage, AK 99501 DATA TRANSMITTAL Transmitted herewith are cuttings WELL BOX# SAMPLE INTERVAL BCU-12A BOX 1 4800'- 5900' BCU-12A BOX 2 5900'- 6860' BCU-12A BOX 3 6860'- 7740' BCU-12A BOX 4 7740'- 8700' BCU-12A BOX 5 8700'- 9800' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: c Date: Angela K. Singh sLi s, z>_;.aas 1ft ar-.... - ---`.*l.wva—a�aE �,aaAs—.—aos. , , .... .... .i.- d OF 'E pa w 9 -,e - =L 17 `1 _- te_ \,. \\,._/ �___it t _ -- --- ---- � , ^ _y=`_-_.�� J 333 1/Vel $evenif� Avenue, GOVERNOR 4l..\�i PAR h1 I Anchorage, Alaska 99501-3572 �,r i\ncl n 907 279 1433 0/,j Iri ...... 70 Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, BCU 12A Sundry Number: 314-481 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0,-, Daniel T. Seamount, Jr. Commissioner DATED this 1--' day of August, 2014. Encl. RECEIVED STATE OF ALASKA u ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 2 2 2014 �Ix,� i ZIY1 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well] Change Approved Program❑ Suspend❑ Plug Perforations[ . Perforate 2 . Pun Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ After Casing❑ Other.❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Doll Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 . 214-070 - 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service 1=16.API Number. Anchorage,Alaska 99503 50-133-20530-01 - 7.If perforating: 8.Wel Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237A / Beaver Creek(BCU)12A • Will planned perforations require a spacing exception? Yes ❑ No L❑ • 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 ' Beaver Creek/Beluga Gas Pod • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9,800 9,578 9,676 9,454 8,125/8,360/8,475 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 103' 20" 103' 103' 3,060 psi 1,500 psi Surface 2,087' 13-3/8" 2,087' 2,08? 3,450 psi 1,950 psi Intermediate 4,765' 9-5/8" 4,765' 4,673' 5,750 psi 3,090 psi Production 9,760' 5-1/2"x 5" 9,760' 9,538' 10,640 psi 7,460 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 WA N/A Packers and SSSV Type: Packers and SSSV MD(t)and TVD(It): N/A;N/A N/A;WA 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stretigraphicn Development[-.71• Service n 14.Estimated Date for 15.Well Status after propsed work: 08/29/14 Commencing Operations: Oil ❑ Gas Q - WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Pothole Phone: 907-777-1412 Email soorhola( hilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature E 4 l'p+A- Phone 907-777-8412 Date &72 1//(14 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: '. \1— ._ lici6 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: /o `I C 1 APPROVED BY J22/1 51 Approved by: COMMISSIONER THE COMMISSION Date: G �L.� �/ I .ZS I`� n /1 ^r /� f q Submn Farm and ' Form taao3(Revised poi tz) Ap o 1f�T`p i�Vat(,p fwlIAoII1 2months from the date of approval. Attachments in Duplicate RBCMS AUG 2 8 22; /eg72yfzt y,� k.z.�- is, Well Prognosis • Well: BCU-12A Ililcor,Alaska,LL' Date:8/22/2014 Well Name: BCU-12A API Number: 50-133-20530-01 Current Status: New Sidetrack Gas Well Leg: N/A Estimated Start Date: August 29th, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-070 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1411321C Current Bottom Hole Pressure: —0 psi @ 7,886' TVD (No open perfs) Maximum Expected BHP: — 3,215 psi @ 8,249' TVD (Based on offset wells) Max. Allowable Surface Pressure: —2,390 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) • Brief Well Summary Beaver Creek Unit#12 was drilled as a Grass roots EXCAPE monobore completion in 2004 to target gas sands in the lower Beluga formation.All 12 EXCAPE modules were perforated and fracture stimulated. A capillary string was installed to deliver foamer to alleviate liquid loading in 2009.The capillary string was pulled in Sep 2010 but a fish was left in the well.The capillary string was re-ran to a shallower depth in Oct 2010.The capillary string was pulled in Feb 2014 and soap sticks have been dropped in place of the foamer.The well was sidetracked with Saxon#169 as Beaver Creek Unit#12A and the 5-1/2"x5" production longstring was cemented in mid July 2014.The first 4 perforated intervals were perforated at the end ofJuly and were shown to be non- productive.The next set of 4 perforated intervals were perforated at the beginning of August and were shown to be non-productive.The next set of 3 perforated intervals were perforated in the middle of August and were shown to be non-productive. The purpose of this work/sundry is to add additional perforations. Notes Regarding Wellbore Condition • Well will be displaced with Nitrogen before initial perforating at+/- 1,500 psi SITP. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 1,500 psi (Nitrogen pressure). 2. RU 2-7/8" 6 spf Connex HC wireline guns. 3. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Upper Beluga UB-11 to UB-13 6,127' 6,316' Varies 6 Middle Beluga MB-18 to MB-20 7,487' 7,688' Varies 6 Lower Beluga LB-21 to LB-28 7,733' 8,117' Varies 6 a. Bleed tubing pressure to 1,400 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. Well Prognosis Well: BCU-12A Hilcorp Alaska,LL Date: 8/22/2014 c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using SLB Cement USIT Log (dated 7/21/14) (Tie-in log). e. Use Gamma/CCL/to correlate. f. Record tubing pressures before and after each perforating run. g. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool. 4. RD E-line. 5. Turn well over to production. E-line Procedure(Contingency): 6. If any zone produces sand and/or water. 7. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be +/- 1,400 psi (remaining gas or applied Nitrogen pressure). 8. RIH and set 5" or 5-1/2" CIBP at depth above zone. Or 9. RIH and set 5" or 5-1/2" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Schematic BCU - 12A ACTUAL Pad 4 2,023 FNL, 48T FEL, SCHEMATIC Sec. 33, T7N, R10W, S.M. Hileorp Alaska.LIA; 'Permit#: 214-070 Conductor 20" K-55 133 ppf API#: 50-133-20530-01 Top Bottom Prop.Des: FED A-028083 MD 0' 103' 6. KB elevation: 167.5' (17.5'AGL) ND 0' 103' Lat: N60° 39' 22.118" Long: W151° 1' 45.593" Spud: 6/29/2014 12:00 hrs Surface Casing TD: 7/07/2014 07:00 hrs 13-3/8" K-55 68 ppf BTC Rig Released: 7/13/2014 6:00 hrs T� Bottom MD 0' 2,087' ND 0' 2,087' "--- 1 16"hole Cmt wl 600 sks(271 bbl)of 12.0 ppg, Tree cxn=9.112"Otis Type 1 cmt, 18 sks(8 bbls)to surface 8.0"Seal Diameter 5-1/8"Modified ID Bore Intermediate Casing TOC(USIT 7/21/14)-4,375' • Fluid Level 9-5/8"5/8 Ton 40 Bottom pf BTC om 4,800'RKB -E I Mkr Jt 4,967' MD 0' 4,765' ND 0' 4,673' 12-1/4"hole Lead Cmt w/833 sks(341 bbls)of 12.5 ppg,Class G, Tail Cmt w/327 sks(106 bbls) of 13.5 ppg,Class G, 12 sks(5 bbls)to surface . Production Casing ' ,Mkr Jt 5,325' 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom MD 0' 7,564' ND 0' 7,348' 5" L-80 18 ppf DWC/C-HT k Top Bottom • MD 7,564' 9,760' NO 7,348' 9,538' 8-1/2"hole Cmt w/1030 sks(248 bbls)of 15.3 ppg, Class G cmt wl EASYBLOK II Mkr Jt 6,094' _ Casing/Cementing Detail - 9.4 ppg Mud - 10.5 ppg Mud Push(38 bbl) 1 Mkr Jt 6,235' - 15.3 ppg Cement(248 bbl) - 8.4 ppg Fresh Water(215 bbl) • XO Jt 7,564' Perforations: II rti Zone MD ND Size SPF Date Status iii RA Mkr Jt 8,054' LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 8/20/14 Open LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 8/20/14 Open LB-27 -_ 2 " LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 8/20/14 Open LB-28 = LB-29 8,374'-8,384' 8,153'-8,163' 2-7/8" 6 8/04/14 Isolated Jewelry Depth LB-28 = -r LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 8/04/14 Isolated ---- 3 LB-29B 8,435-8,450' 8,214'-8,229' 2-7/8" 6 8/04/14 Isolated 1.Swell Packer(21'Long) 4,209' LB-29 = ' = LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 8/04/14 Isolated 2.CIBP(Set 8/21/14) 8,125' LB-29 = LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 7/30/14 Isolated 3.CIBP(Set 8/09/14) 8,360' LB-29B= LB-30 8,495-8,510' 8,274'-8,289' 2-7/8" 6 7/30/14 Isolated 4.CIBP(Set 8/02/14) 8,475' LB-29B= LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 7/30/14 Isolated LB-30 4 LB-31 8,600'-8,610' 8,379'-8,389' 2-7/8" 6 7/30/14 Isolated LB-30 a ERA MkrJt 8,500' LB-31 LB-31 = e= } Casing Shoe @ 9,760' Tag(unset cement)@ 9,464'SLM Open hole Max Dogleg: w/3.84"GR(7/16/14) Casing 40'off bottom 4.42°/100'@ 8,004' TD: PBTD: Max Inclination: 9,800'MD 9,676'MD 20.3°@ 5,027' 9,578'ND 9,454'ND Well Name&Number. Beaver Creek Unit#12A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country.IUSA Angle @KOP and Depth. 19.2°@ 4,769' _ Angle/Perfs:I N/A Maximum Deviation 20.3°@ 5,027' Date Completed: 7/12/2014 Ground Level(above MSL)._ 150.0' RKB(above GL). 17.5' Revised By: Stan Porhola Downhole Revision Date: 8/21/2014 Schematic Revision Date: 8122/2014 • • BCU - 12A PROPOSED Pad 4 2,023FNL, 482' FEL, SCHEMATIC Sec.33, T7N, R10W, S.M. Ililenrp Alaska. LLC Permit#: 214-070 :,' LConductor • API#: 50-133-20530-01 20" K-55 133 ppf Top Bottom Prop.Des: FED A-028083j MD 0' 103' KB elevation: 167.5' (17.5'AGL) ND 0' 103' Lat: N60° 39' 22.118" Long: W151° 1' 45.593" Spud: 6/29/2014 12:00 hrs Surface Casing TD: 7/07/2014 07:00 hrs 13-3/8" K-55 68 ppf BTC Ria Released: 7/13/2014 6:00 hrs T� Bottom MD 0' 2,087' -Mk 167_ ND 0' 2,087' 1 16"hole Cmt w/600 sks(271 bbl)of 12.0 ppg, Tree cxn=9-1/2"Otis Type 1 cmt, 18 sks(8 bbls)to surface 8.0"Seal Diameter 5-1/8"Modified ID Bore Intermediate Casing 7/21/14)-4,375' • 9-5/8" L-80 40 ppf BTC TOC (USIT Tg Bottom Mkr Jt 4,967' MD 0' 4,765' ND 0' 4,673' • 12-1/4"hole Lead Cmt w/833 sks(341 bbls)of 12.5 ppg,Class G, Tail Cmt w/327 sks(106 bbls) of 13.5 ppg,Class G, 12 sks(5 bbls)to surface . Production Casing ' 'Mkr Jt 5,325' 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom MD 0' 7,564' ' ND 0' 7,348' 5" L-80 18 ppf DWC/C-HT • Top Bottom MD 7,564' 9,760' I ii Mkr Jt 6,094' ND 7,348' 9,538' 8-1/2"hole Cmt wl 1030 sks(248 bbls)of 15.3 ppg, Class G cmt wl EASYBLOK Casing/Cementing Detail - 9.4 ppg Mud Upper Beluga kr Jt 6,235' - 10.5 ppg Mud Push(38 bbl) - 15.3 ppg Cement(248 bbl) 11 �^ - 8.4 ppg Fresh Water(215 bbl) Middle Beluga O Jt 7,564' Perforations: 3 Zone MD ND Size SPF Date Status UB 6,127'6,316' 5,966'-8.147 2-1/8" 6 Proposed MB 7,487'-7,688' 7,273'-7,470' 2-7/8" 6 Proposed Lower Beluga MkrJt 8,054' LB 7,733-8,117' 7,514-7,896' 2-7/8" 6 Proposed IRA LB-27 8,135'-8,155' 7,914'-7,934' 2-7/8" 6 8/20/14 Isolated 4 LB-28 8,262'-8,292' 8,041'-8,071' 2-7/8" 6 8/20/14 Isolated LB-27 LB-28 8,302'-8,322' 8,081'-8,101' 2-7/8" 6 8/20/14 Isolated LB-28 LB-29 8,374'-8,384' 8,153-8,163' 2-7/8" 6 8/04/14 Isolated Jewelry Depth LB-28 -- LB-29 8,393'-8,403' 8,172'-8,182' 2-7/8" 6 8/04/14 Isolated 1.Swell Packer(21'Long) 4,209' LB-29 - _- 5 LB-29B 8,435'-8,450' 8,214-8,229' 2-7/8" 6 8/04/14 Isolated 2.CIBP(Contingency) LB-29 = - = LB-29B 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 8/04/14 Isolated 3.CIBP(Contingency) LB 29B= LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 7/30/14 Isolated 4.CIBP(Set 8/21/14) 8,125' LB-30 8,495'-8,510' 8,274-8,289' 2-7/8" 6 7/30/14 Isolated LB-29B= 5.CIBP(Set 8/09/14) 8,360' 6 LB-31 8,543-8,553' 8,322'-8,332' 2-7/8" 6 7/30/14 Isolated 6.CIBP(Set 8/02/14) 8,475' LB-30 -4_ . LB-31 8,600'-8,610' 8,379'-8,389' 2-7/8" 6 7/30/14 Isolated LB-30 1DbN Mkr Jt 8,500' LB-31 LB-31 Casing Shoe @ 9,760' Tag(unset cement)@ 9,464'SLM Openhole Max Dogleg: wl 3.84"GR(7/16/14) Casing 40'off bottom 4.421100'@ 8,004' TD: PBTD: Max Inclination: 9,800'MD 9,676'MD 9,578'ND 9,454'ND 20.3"@ 5,027' Well Name&Number: Beaver Creek Unit#12A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth 19.2°@ 4,769' Angle/Perls I N/A Maximum Deviation. 20.3°@ 5,027' Date Completed. 7/12/2014 Ground Level(above MSL): 150.0' RKB(above GL): 17.5' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 8/22/2014 t. cw,�\\ /2- THE STATE A .v.ca C '. ..�i�.(� :�.,E _ i /—') Ns} __�,_, :_� 333 west 3evenih A onue (;OvI.RNOR S'FAN PARN111, Anchorage, Alaska 99:)01 3572 _ . rlr,n 907 '27° 1/33 @\Ei.LE � 171 Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, BCU 12A Sundry Number: 314-451 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P 9,,..4.4 Cathy P. Foerster Chair DATED this Say of August, 2014. Encl. RECE lED STATE OF ALASKA A 0 0 01 2 U D algIN ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,6-1-c G1 20 AAC 25.280 AO GM Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well El Change Approved Program❑ Suspend❑ Plug Perforations [ 1" ) ,i H Perforate❑., ' Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other.❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number • Exploratory ❑ Development Q 214-070 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ • 6.API Number. Anchorage,Alaska 99503 50-133-20530-01 7.If perforating: 8.Well Name end Number. What Regulation or Conservation Order governs well spacing in this pool? CO 237A BeaverWill planned perforations require a spacing exception? Yes ❑ No CI Creek(BCU)12A 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083. Beaver Creek/Beluga Gas Pod ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9,800 9,578 9,676 9,454 N/A N/A Casing Length Size MD 7VD Burst Cdlspss Structural Conductor 103' 20" 103' 103' 3,060 psi 1,500 psi Surface 2,087' 13-3/8" 2,087' 2,087' 3,450 psi 1,950 psi Intermediate 4,765' 9-5/8" 4,765' 4,673' 5,750 psi 3,090 psi Production 9,760' 5-1/2"x 5" 9,760' 9,538' 10,640 psi 7,460 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 WA N/A Packers and SSSV Type: Packers and SSSV MD(t)end TVD(It): N/A,N/A N/A;WA 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphic❑ Development n Service n 14.Estimated Date for 15.Well Status after proposed work: 08/04/14 Commencing Operations: Oil ❑ Gas El - WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email,,Soorhola( hilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature 4 , Phone 907-777-8412 Date ,j D f ,7 COMMISSION USE ONLY G Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No u Subsequent Form Required: /0 "- 0 _ VI APPROVED BY Approved by: ale" [4,/_ //�� COMMISSIONERATHE COMMISSION Date: 9-S-/ _ ' / �Y p�Q ' _ I 1\' Submit Form andD�rRl10 A�(R?..4,2 A r �d�i Cl�tlfrt�i�r f r 12 months from the da a of approval. ` Attachments in Duplicate SS GG 0174/ y ., --f T'4. ,cil Well Prognosis , '• II Well: BCU-12A Ilikorp Alaska,LU Date:8/01/2014 Well Name: BCU-12A API Number: 50-133-20530-01 Current Status: New Sidetrack Gas Well Leg: N/A Estimated Start Date: August 4th, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-070 First Call Engineer: Stan Porhola _ (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1411321C Current Bottom Hole Pressure: —2,000 psi @ 8,339' TVD (Existing perforations) Maximum Expected BHP: — 3,363 psi @ 8,249' TVD (Based on offset wells) Max. Allowable Surface Pressure: —2,538 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#12 was drilled as a Grass roots EXCAPE monobore completion in 2004 to target gas sands in the lower Beluga formation.All 12 EXCAPE modules were perforated and fracture stimulated.A capillary string was installed to deliver foamer to alleviate liquid loading in 2009.The capillary string was pulled in Sep 2010 but a fish was left in the well.The capillary string was re-ran to a shallower depth in Oct 2010.The capillary 1 string was pulled in Feb 2014 and soap sticks have been dropped in place of the foamer. The well was sidetracked with Saxon#169 as Beaver Creek Unit#12A and the 5-1/2"x5" roduction longstring was cemented P g g in mid July 2014.The first 4 perforated intervals were perforated at the end of July and were shown to be non- . productive. , -_ The purpose of this work/sundry is to add additional perforations. Notes Regarding Wellbore Condition • Well will be displaced with Nitrogen before initial perforating at+/- 2,100 psi SITP. E-line Procedure_ � - Ctrl!" C' II 7,s ' ill) - 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 2,100 psi (Nitrogen pressure). 2. RU 2-7/8" 6 spf Connex HC wireline guns. 3. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF - Lower Beluga LB-27 8,135' 8,153' 18 6 Lower Beluga LB-28 8,264' 8,277' 13 6 Lower Beluga LB-28 8,282' 8,292' 10 6 Lower Beluga LB-28 8,302' 8,321' 19 6 Lower Beluga LB-29 8,374' 8,384' 10 6 Lower Beluga LB-29 8,393' 8,403' 10 6 Lower Beluga LB-29B 8,435' 8,450' 15 6 Well Prognosis Well: BCU-12A Hi[carp Alaska,LL Date:8/01/2014 Lower Beluga LB-29B 8,460' 8,470' 10 6 a. Bleed tubing pressure to 2,100 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using SLB Cement USIT Log (dated 7/21/14) (Tie-in log). e. Use Gamma/CCL/to correlate. f. Record tubing pressures before and after each perforating run. g. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool. ✓ 4. RD E-line. 5. Turn well over to production. E-line Procedure (Contingency): 6. If any zone produces sand and/or water. 7. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be +/- 2,100 psi (remaining gas or applied Nitrogen pressure). 8. RIH and set 5" CIBP at depth above zone. Or 9. RIH and set 5" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Schematic • BCU - 12A ACTUAL Pad 4 2,023 FNL, 482' FEL, SCHEMATIC Sec.33, T7N, R10W, S.M. IIiIi•urp ; Ia.,ka. IAA. Permit#: 214-070 Conductor API#: 50-133-20530-01 :I] 20" K-55 133 ppf .,. L Top Bottom Prop.Des: FED A-028083 MD 0' 103' KB elevation: 167.5' (17.5'AGL) ND 0' 103' Lat: N60° 39' 22.118" Long: W151" 1' 45.593" Spud: 6/29/2014 12:00 hrs Surface Casing TD: 7/07/2014 07:00 hrs 13-3/8" K-55 68 ppf BTC Rig Released: 7/13/2014 6:00 hrs T� Bo0' om MD2,087' TVD 0' 2,087' . Ihi--- 1 16"hole Cmt w/600 sks(271 bbl)of 12.0 ppg, Tree cxn=9-1/2"Otis'' Type 1 cmt, 18 sks(8 bbls)to surface 8.0"Seal Diameter 5-1/8"Modified ID Bore Intermediate Casing TOC(USIT9-5/8" L-80 40 ppf BTC 7/21/14)-4,375' Top Bottom 111 'Mkr Jt 4,967' MD 0' 4,765' ND 0' 4,673' • 12-1/4"hole Lead Cmt wl 833 sks(341 bbls)of 12.5 ppg,Class G, Tail Cmt w/327 sks(106 bbls) of 13.5 ppg,Class G, 12 sks(5 bbls)to surface Production Casing 5-1/2" P-110 17 ppf DWCIC-HT 'MkrJt 5,325' Top Bottom MD 0' 7,564' TVD 0' 7,348' 5" L-80 18 ppf DWC/C-HT Top Bottom MD 7,564' 9,760' TVD 7,348' 9,538' 8-1/2"hole Cmt wl 1030 sks(248 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK II Mkr Jt 6,094' Casing/Cementing Detail - 9.4 ppg Mud - 10.5 ppg Mud Push(38 bbl) ' 'Mkr Jt 6,235' - 15.3 ppg Cement(248 bbl) - 8.4 ppg Fresh Water(215 bbl) XO Jt 7,564' Perforations: Zone MD ND Size SPF Date LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 7/30/14 LB-30 8,495-8,510' 8,274'-8,289' 2-7/8" 6 7/30/14 WRA MkrJt 8,054' LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 7/30/14 LB-31 8,605-8,610' 8,379'-8,389' 2-7/8" 6 7/30/14 Jewelry Depth 1.Swell Packer(21'Long) 4,209' LB-30 LB-30 A DA MkrJt 8,500' LB-31 --- c LB-31 ;ys Casing Shoe @ 9,760' Tag(unset cement)@ 9,464'SLM Open hole Max Dogleg: w/3.84"GR(7/16/14) • Casing 40'off bottom 4.42°/100'@ 8,004' TD: PBTD: Max Inclination: 9,800'MD 9,676'MD 9,578'ND 9,454'ND 20.3°@ 5,027' Well Name 8 Number_ Beaver Creek Unit#12A Lease:_ A-028083 County or Parish. Kenai Peninsula Borough State/Prov: Alaska Country USA . Angle @KOP and Depth. 19.2°@ 4,769' Angle/Perts.j N/A Maximum Deviation' 20.3°@ 5,027' Date Completed:, 7/12/2014 Ground Level(above MSL): 150.0' RKB(above GL): 17.5' Revised By: Stan Porhola Downhole Revision Date: 7/30/2014 Schematic Revision Date: 8/1/2014 .. BCU - 12A PROPOSED Pad 4 2,023 FNL, 482'FEL, SCHEMATIC Sec. 33, T7N, R10W, S.M. IIil,•orrp Alaska. I.IA: - Conductor Permit#: 214-0701::„ 20" K-55 133 ppf API#: 50-133-20530-01 Top Bottom Prop.Des: FED A-028083 MD 0' 103' KB elevation: 167.5' (17.5'AGL) TVD 0' 103' Lat: N60° 39' 22.118" Long: W151° 1' 45.593" Spud: 6/29/2014 12:00 hrs Surface Casing TD: 7/07/2014 07:00 hrs 13-3/8" K-55 68 ppf BTC Rio Released: 7/13/2014 6:00 hrs -1:)2Bo0' om MD2,087' ND 0' 2,087' 1 16"hole Cmt w/600 sks(271 bbl)of 12.0 ppg, Tree cxn=9-1/2"Otis Type 1 cmt, 18 sks(8 bbls)to surface 8.0"Seal Diameter 5-1/8"Modified ID Bore Intermediate Casing pf TOC(USIT 7/21/14)-4,375' 9-5/8Top Bo40ttom BBTC Mkr Jt 4,967' MD 0' 4,765' ND 0' 4,673' 12-1/4"hole Lead Cmt w/833 sks(341 bbls)of 12.5 ppg,Class G, Tail Cmt w/327 sks(106 bbls) of 13.5 ppg,Class G, 12 sks(5 bbls)to surface Production Casing 5-1/2" P-110 17 ppf DWC/C-HT Mkr Jt 5,325' Top Bottom MD 0' 7,564' • • ND 0' 7,348' 5" L-80 18 ppf DWC/C-HT Top Bottom MD 7,564' 9,760' ND 7,348' 9,538' 8-1/2"hole Cmt w/1030 sks(248 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK Mkr Jt 6,094' Casing/Cementing Detail - 9.4 ppg Mud - 10.5 ppg Mud Push(38 bbl) Mkr Jt 6,235' - 15.3 ppg Cement(248 bbl) - 8.4 ppg Fresh Water(215 bbl) XO Jt 7,564' Perforations: Zone MD ND Size SPF Date RA MkrJt 8,054' LB-27 8,135-8,153' 7,914-7,932' 2-7/8" 6 Proposed LB-27 - LB-28 8,264-8,277' 8,043-8,056' 2-718" 6 Proposed LB-28 LB-28 8,282'-8,292' 8,061'-8,071' 2-7/8" 6 Proposed LB-28 _ --- 2 LB-28 8,302'-8,321' 8,081'-8,100' 2-7/8" 6 Proposed Jewelry Depth LB-28 =' LB-29 8,374-8,384' 8,153-8,163' 2-7/8" 6 Proposed 3 L8-29 8,393-8,403' 8,172'-8,182' 2-7/8" 6 Proposed 1.Swell Packer(21'Long) 4,209' LB-29 • L8-29B 8,435-8,450' 3214-8,229' 2-7/8" 6 Proposed 2.Casing Patch(15'Long)If needed to isuiate 1130 LB-P9LB-296 8,460'-8,470' 8,239'-8,249' 2-7/8" 6 Proposed sand/water LB-29B --* d LB-30 8,480'-8,490' 8,259'-8,269' 2-7/8" 6 7/30/14 3.CIBP TBD LB-29B • i LB-30 8,495-8,510' 8,274-8,289' 2-7/8" 6 7/30/14 4.CIBP 8,475' 4 3"(°3 LB-31 8,543'-8,553' 8,322'-8,332' 2-7/8" 6 7/30/14 1 LB-30 -- LB-31 8,600'-8,610' 8,379'-8,389' 2-7/8" 6 7/30/14 LB-30 �_-• MkrJt 8,500' LB-31 - - LB-31 - Casing Shoe @ 9,760' Openhole Tag(unset cement)@ 9,464'SLM ,. Max Dogleg: w/3.84"GR(7/16/14) „ Casing 40'off bottom 4.42°/100'@ 8,004' TD: PBTD: 9,800'MD 9,676'MD Max Inclination: 9,578'ND 9,454'ND 20.3°@ 5,027' Well Name&Number Beaver Creek Unit#12A Lease: A-028083 • County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:1USA Angle @KOP and Depth. 19.2°@ 4,769' Angle/Perin.I N/A Maximum Deviation: 20.3°@ 5,027' Date Completed: 7/12/2014 Ground Level(above MSL): 150.0' RKB(above GL): 17.5' Revised By. Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 8/1/2014 pTD 214 • Ferguson, Victoria L (DOA) From: Ferguson, Victoria L(DOA) Sent: Wednesday,July 23, 2014 2:06 PM To: 'Stan Porhola' Cc: Schwartz, Guy L (DOA); Davies, Stephen F (DOA) Subject: RE: Procedure Change Request - Sundry 314-426, PTD 214-07, Follow Up Flag: Follow up Flag Status: Completed Stan, The changes are approved as outlined. Next time include the PTD#in the subject line along with the sundry#. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferguson aialaska.gov 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 Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov From: Stan Porhola [mailto:sporhola©ahilcorp.com] Sent: Wednesday, July 23, 2014 1:31 PM To: Ferguson, Victoria L(DOA) Cc: Schwartz, Guy L (DOA); Davies, Stephen F (DOA) Subject: Procedure Change Request- Sundry 314-426 Victoria, Would like to change the perforation depth for well BCU-12A under Sundry 314-426. Change the perf depth of the following intervals... Interval: LB-31 From:8,600'-8,608' (8') To:8,600'-8,610' (10') Interval: LB-31 From: 8,546'-8,552' (6') 1 To 8,543'-8,553' (10') Interval: LB-30 From: 8,482'-8,487' (5') To:8,480'-8,490' (10') Regards, Stan Porhola ' Operations Engineer No h Kenai Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 2 OF 7.4A' ,§'�1%7- ,s' THE STATE Ai-aSka Oi a�lue, Gas �,. j/ '/ 'PA or ' -7 77-1, 7,-, ^(-r ,i�, o -' (_1- i, ^f r- ifkia 1414sz,_. _ 1E117-__ _- — 333 West Seventh Avenue GOVERNOR SEAN PARNELI. Anchorage, Alaska 99501-3572 Main 907.279 1433 AL ASICP Fa., 907 27c 7942 c2 ( -1 — 7D Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek 12A Sundry Number: 314-426 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause'shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, r)e-t(4/t , Cathy P. oerster Chair DATED this day of July, 2014. Encl. RECEIVED STATE OF ALASKA J U L 1 7 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION D7-5 -7 I // APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate 0 • Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other. Initial Completion ❑✓ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development 0• 214-070 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service CI6.API Number. Anchorage,Alaska 99503 50-133-20530-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237A ' Will planned perforations require a spacing exception? Yes ❑ No ❑� Beaver Creek(BCU)12A 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 • Beaver Creek/Beluga Gas Pod . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft): Effective Depth MD(ft). Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9,800 9,578 9,676 9,454 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 103' 20" 103' 103' 3,060 psi 1,500 psi Surface 2,087' 13-3/8" 2,087' 2,087' 3,450 psi 1,950 psi Intermediate 4,765' 9-5/8" 4,765' 4,673' 5,750 psi 3,090 psi Production 9,760' 5-1/2"x 5" 9,760' 9,538' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)end TVD(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal ❑' 13.Well Class after proposed work: - Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development❑ Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing07/23/14 Operations: Oil ❑ Gas 10 • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sDorhola( hilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature ..cJ" Phone 907-777-8412 Date —1/1 -1/i COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \i—L_ `2 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No [4j Subsequent Form Required: ID — 4 0 APPROVED BY Approved by: P.414,44",_aiee47 'COMMISSIONER THE COMMISSION Date: 7... Z/-/ (.( D " I � A Submit n Form and Form 10-403(Revised 10/2012) Appr v I t sdT�d`rLmonthsa a of approval. AttacFun nts in Duplicate !/` r �`z 1 14— I CM JUL 2 2 20 ,,s J1 7 zi. .q Well Prognosis Well: BCU-12A Ilikorp Alaska,LU Date: 7/17/2014 Well Name: BCU-12A API Number: 50-133-20530-01 Current Status: New Sidetrack Gas Well Leg: N/A Estimated Start Date: July 23`d, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-070 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1411321C Current Bottom Hole Pressure: — 0 psi @ 8,339' TVD (No open perforations) Maximum Expected BHP: — 3,400 psi @ 8,339' TVD (Based on offset wells) Max. Allowable Surface Pressure: —2,566 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#12 was drilled as a Grass roots EXCAPE monobore completion in 2004 to target gas sands in the lower Beluga formation.All 12 EXCAPE modules were perforated and fracture stimulated. A capillary string was installed to deliver foamer to alleviate liquid loading in 2009.The capillary string was pulled in Sep 2010 but a fish was left in the well.The capillary string was re-ran to a shallower depth in Oct 2010. The capillary string was pulled in Feb 2014 and soap sticks have been dropped in place of the foamer. The well was sidetracked with Saxon #169 as Beaver Creek Unit#12A and the 5-1/2"x5" production longstring was cemented in mid July 2014. The purpose of this work/sundry is to perforate the well for the initial completion. Notes Regarding Wellbore Condition • Plan to tag with slickline before running E-line. Moderate dogleg near window. • Will run Cement Bond Log before perforating. • MIRU Coil Tubing and perform BOPE Test to 250/4,500 psi to displace well over to Nitrogen. • Well will be displaced with Nitrogen before initial perforating at+/- 2000 psi SITP. • Pressure test IA (5-1/2"x9-5/8") to 2,500 psi before perforating. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 2,000 psi (Nitrogen pressure). 2. RU 3-3/8" 6 spf Connex HC wireline guns (will use 1 each 8' gun and 1 each 6'gun). 3. RIH and perforate Lower Beluga (LB-31) interval from 8,600'-8,608' and 8,546'-8,552' (4 runs, total of 12 spf). a. Bleed tubing pressure to 2,000 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using SLB Cement USIT Log (pending) (Tie-in log depth pending). e. Use Gamma/CCL/to correlate. f. Record tubing pressures before and after each perforating run. g. Distance to nearest well open in same sands= 1,450'to BCU-14A. Well Prognosis Well: BCU-12A Hilcorp Alaska,LL Date:7/17/2014 h. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool. 4. RD E-line. 5. Turn well over to production. 6. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be +/- 1,500 psi (remaining gas or applied Nitrogen pressure). 7. RU 3-3/8" 6 spf Connex HC wireline guns (will use 1 each 15'gun and 1 each 5' gun). 8. RIH and perforate Lower Beluga (LB-30) interval from 8,495'-8,510' and 8,482'-8,487' (4 runs,total of 12 spf). a. Bleed tubing pressure to 1,500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using SLB Cement USIT Log(pending) (Tie-in log depth pending). e. Use Gamma/CCL/to correlate. f. Record tubing pressures before and after each perforating run. g. Distance to nearest well open in same sands= 1,450'to BCU-14A. h. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool. 9. RD E-line. 10. Turn well over to production. 11. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. c. Tree connection is 9.5" OTIS. d. SITP will be+/- 1,500 psi (remaining gas or applied Nitrogen pressure). 12. RU 3-3/8" 6 spf Connex HC wireline guns (will use 1 each 10'gun and 1 each 12'gun). 13. RIH and perforate Lower Beluga (LB-29) interval from 8,460'-8,470' and 8,435'-8,447' (4 runs,total of 12 spf). e. Bleed tubing pressure to 1,500 psi before perforating. f. Proposed perfs shown on the proposed schematic in red font. g. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. h. Correlate using SLB Cement USIT Log (pending) (Tie-in log depth pending). i. Use Gamma/CCL/to correlate. j. Record tubing pressures before and after each perforating run. k. Distance to nearest well open in same sands= 1,450'to BCU-14A. I. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool. 14. RD E-line. 15. Turn well over to production. E-line Procedure(Contingency): 16. If any zone produces sand and/or water. 17. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. i. Tree connection is 9.5" OTIS. j. SITP will be +/- 1,500 psi (remaining gas or applied Nitrogen pressure). 18. RIH and set 5" CIBP at depth above zone. 19. Or 20. RIH and set 5" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Schematic • BCU - 12A ACTUAL Pad 4 2,023 FNL, 482'FEL, SCHEMATIC Sec.33, T7N, R10W, S.M. Itikorp Alaska. I.1,(: Permit#: 214-070 I Conductor API#: 50-133-20530-01 20" K-55 13 ppf Top Bottom Prop.Des: FED A-028083h. MD 0' 103 KB elevation: 167.5' (17.5 AGL) ND 0' 103• Lat: N60° 39' 22.118" Long: W151° 1' 45.593" Spud: 6/29/2014 12:00 hrs Surface Casing TD: 7/07/2014 07:00 hrs 13-318" K-55 68 ppf BTC Rig Released: 7/13/2014 6:00 hrs Tom B 0om MD 0' 2,,087' . ND 0' 2,087' 1 16"hole Cmt w/600 sks(271 bbl)of 12.0 ppg, Tree cxn=9-1/2"Otis Type 1 cmt, 18 sks(8 bbls)to surface 8.0"Seal Diameter 5-118"Modified ID Bore Intermediate Casing Lpf TOC(Est)-4,300' 9-5/8" Top Bo40ttom BBTC Mkr Jt 4,967' MD 0' 4,765' . ND 0' 4,673' 12-1/4"hole Lead Cmt w/833 sks(341 bbls)of 12.5 ppg,Class G, Tail Cmt w/327 sks(106 bbls) of 13.5 ppg,Class G, 12 sks(5 bbls)to surface Production Casinq 5-1/2" P-110 17 ppf DWC/C-HT Mkr Jt 5,325' Top Bottom MD 0' 7,564' b. ND 0' 7,348' 5" L-80 18 ppf DWC/C-HT Top Bottom MD 7,564' 9,760' ND 7,348' 9,538' 8-1/2"hole Cmt w/1030 sks(248 bbls)of 15.3 ppg, I Class G cmt w/EASYBLOK Mkr Jt 6,094' • Casing/Cementing Detail - 9.4 ppg Mud i',- - 10.5 ppg Mud Push(38 bbl) Mkr Jt 6,235' - 15.3 ppg Cement(248 bbl) - 8.4 ppg Fresh Water(215 bbl) F ii7 4.1 XO Jt 7,564' PP W RA Mkr Jt 8,054' 4a., yT Jewelry Depth 1.Swell Packer(21'Long) 4,209' ' ""1,�� 1 'tr RA Mkr Jt 8,500' s,. „... r t.7 fItt., ...• '.-. Casing Shoe @ 9,760' 1,a Open hole Casing 40'off bottom Max Dogleg: _ 4.42°/100'@ 8,004' TD: PBTD: Max Inclination: 9,800'MD 9,676'MD 9,578'ND 9,454'ND 20.3°@ 5,027' Well Name 8 Number Beaver Creek Unit#12A Lease._ A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country.IUSA Angle @KOP and Depth. 19.2°@ 4,769' Angle/Perfs:I N/A - Maximum Deviation. 20.3°@ 5,027' Date Completed. 7/12/2014 Ground Level(above MSL): 150.0' RKB(above GL): 17.5' Revised By. Stan Porhola Downhole Revision Date: 7/12/2014 Schematic Revision Date: 7/14/2014 • • BCU - 12A PROPOSED Pad 4 2,023 FNL, 487 FEL, SCHEMATIC Sec.33, T7N, R10W, S.M. IIiIr'oep Alaska. LIA: Permit#: 214-070 Conductor 20" K-55 133 ppf API#: 50-133-20530-01 ii ^, Ton Bottom Prop.Des: FED A-028083 MD 0' 103' KB elevation: 167.5' (17.5'AGL) TVD 0' 103' Lat: N60° 39' 22.118" Long: W151° 1' 45.593" Spud: 6/29/2014 12:00 hrs Surface Casing 13-3/8" K-55 68 ppf BTC TD: 7/07/2014 07:00 hrs T� Bottom Ria Released: 7/13/2014 6:00 hrs MD 0' 2,087' ,. TVD 0' 2,087' 1 16"hole Cmt w/600 sks(271 bbl)of 12.0 ppg, Tree cxn=9.1/2"Otis Type 1 cmt, 18 sks(8 bbls)to surface 8.0"Seal Diameter 5-1/8"Modified ID Bore Intermediate Casing ' 9-5/8" L-80 40 ppf BTC TOC(Est)-4,300' To Bottom Mkr Jt 4,967' MD 0' 4,765' TVD 0' 4,673' 12-1/4"hole Lead Cmt w/833 sks(341 bbls)of 12.5 ppg,Class G, Tail Cmt w/327 sks(106 bbls) of 13.5 ppg,Class G, 12 sks(5 bbls)to surface , Production Casing 5-1/2" P-110 17 ppf DWC/C-HT Mkr Jt 5,325' Top Bottom MD 0' 7,564' TVD 0' 7,348' 5" L-80 18 ppf DWC/C-HT Top Bottom MD 7,564' 9,760' TVD 7,348' 9,538' • 8-1/2"hole Cmt w/1030 sks(248 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK Mkr Jt 6,094' • Casing/Cementing Detail - 9.4 ppg Mud - 10.5 ppg Mud Push(38 bbl) Mkr Jt 6,235' - 15.3 ppg Cement(248 bbl) - 8.4 ppg Fresh Water(215 bbl) 4 XO Jt 7,564' Perforations: A.+, Te Zone MD TVD Size SPF Date LB-29 8,435'-8,447 8,214-8,226' 3-3/8" 12 Proposed LB-29 8,460'-8,470' 8,239'-8,249' 3-3/8" 12 Proposed LB-30 8,482'-8,487' 8,261'-8,266' 3-3/8" 12 Proposed ♦ta RA MkrJt 8,054' LB-30 8,495'-8,510' 8,274-8,289' 3-3/8" 12 Proposed Jewelry Depth { LB-31 8,546-8,552' 8,325'-8,331' 3-3/8" 12 Proposed 1 Swell Packer(21'Long) 4,209' LB-29 LB-31 8,600'-8,608' 8,379'-8,387' 3-3/8" 12 Proposed 2.Casing Patch(.30'Long)If needed to isolate TBD sand/water LB-29 = 3.CIBP(If needed to isolate sand/water) TBD LB-30 i- LB-30 :cr-_.-' Mkr Jt 8,500' ar LB-31 LB-31 td+ .a x" , ` Casing Shoe @ 9,760' Alk; '" # ''.1)A.14;7' Openhole Casing 40'off bottom Max Dogleg: 4.42°/100'@ 8,004' TD: PBTD: Max Inclination: 9,800'MD 9,676'MD 20.3°@ 5,027' 9,578'TVD 9,454'ND Well Name&Number: Beaver Creek Unit#12A Lease: A-028083 County or Parish Kenai Peninsula Borough _ State/Prov: Alaska Country:lUSA Angle @KOP and Depth: 19.2°@ 4,769' Angle/Perfs:I N/A Maximum Deviation 20.3°@ 5,027' - Date Completed: 7/12/2014 Ground Level(above MSL): 150.0' RKB(above GL): 17.5' Revised By: Stan Porhola Downhole Revision Date Proposed Schematic Revision Date: 7/17/2014 7,<;07 �\�\v///' � THE STATE h_1',21{, . OFJ, aLLl.c), ye, --- , 0 f b T" /� (--'ti T % A, 'r s t ---------._- __ 333 West SeventhAvenue '"�"= -A; C;O!'tP. �'(�P, S}=,AN I'AP DELI Anchorage, Alaska 99561-3572 "� 0'n 917 q 1zn Monty M. Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek 12A Hilcorp Alaska, LLC Permit No: 214-070 Surface Location: 2024' FNL, 481', FEL, Sec. 33, T7N, R10W, SM Bottomhole Location: 1916' FNL, 4439' FEL, Sec. 34, T7N, R1 OW, SM Dear Mr. Myers: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, e;;41--- Cathy P, Foerster Chair DATED this day of Junew, 2014. STATE OF ALASKA AOIL AND GAS CONSERVATION COM ON MA 14 Z! i+ PERMIT TO DRILL 20 AAC 25.005 AOGCC la.Type of Work: lb Proposed Well Class. Development-Oil 9 Service- Winj 9 Single Zone 9 - lc.Specify if well is proposed for. Drill 9 Lateral 0 Stratigraphic Test 9 Development-Gas 9 • Service-Supply 9 Multiple Zone 0 Coalbed Gas ❑ Gas Hydrates ❑ Rednl❑✓ Reentry ❑ Exploratory 9 Service- WAG 0 Service-Disp 0 Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond. Blanket 9 . Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 22035244. Beaver Creek(BCU)12A• 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 MD: 10,500 • 10,271 ' Beaver Creek 4a. Location of Well(Governmental Section): 7.Property Desi nation(Lease Number): ' Beluga Gas Pool Surface: 2024'FNL,481'FEL,Sec 33,T7N,R1 OW,SM,AK A02814ti' i-f )ZS i�3 A /'i•ISZ Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1896'FNL,4474'FEL,Sec 34,T7N,R1 OW,SM,AK NA 6/15/2014 Total Depth. 9.Acres in Property' 14.Distance to Nearest Property' 1916'FNL,4439'FEL,Sec 34,T7N,R1 OW,SM,AK 2,400 acres 4,484'FEL Section 34,T7N,R1OW,SM,AK 4b.Location of Well(State Base Plane Coordinates-NAD 27)• 10.KB Elevation above MSL: • 168.6 feet 15.Distance to Nearest Well Open Surface. x- y- Zone- GL Elevation above MSL: • 150 feet to Same Pool: 1,547'(BCU 14A) 315325.75 • 2433191.53' 4 16.Deviated wells: Kickoff depth: 4800 feet • 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: 19 degrees Downhole: 4396 psi • Surface: 3369 psi 1' 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) 7-7/8" 5-1/2" 17# P-110 DWC/C 10,482 18' 18' 10,500' 10,271 263 7 bbls cmt(includes 35%excess on OH v W/AIJo,- e 1-(2,Zb M0 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 107' 20" NA 107' 107' Surface 2091' 13-3/8" 600 sx of class G 2091' 2091' Intermediate 7160' 9-5/8" 1160 sx of class G 7160' 6978' Production 8773' 3-1/2" 786 sx of class G 8773' 8590' Liner Perforation Depth MD(ft): Perforation Depth ND(ft). 7228'-8481' 7046'-8299' 20. Attachments. Property Plat ❑✓ BOP Sketch 9 Drilling Program 9 Time v.Depth Plot ❑' Shallow Hazard Analysis❑ Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 9 20 AAC 25 050 requirements❑✓ 21. Verbal Approval: Commission Representative Date 5 13 2014 22. I hereby certify that the foregoing is true and correct. Contact Monty M Myers Email mmyerSAhilcorp.com Printed Name Monty M Myers Title Drilling Engineer i Signature .�..--\� ~ C Phone 907.777.8431 Date 5.13.2014 ......... .5..), Commission Use Only Permit to Drill - /Tl API Number Permit Approval Ll See cover letter for other Number: „Z ty u i .) 50-/ —10-j }-(�(- ate: �.`7 / requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: © , Other. LI SL;07 /�5�, / '. e I „_.--t-/— Samples req'd: Yes❑ Nog' Mud log req'd:Yes No[ -I / 1 H2S measures: Yes 9 No R" Directional svy req'd:Yes['No❑ C ., L �Q (j Spacing exception req'd. Yes 9 Nog' Inclination-only svy req'd:Yes Nov' �� pZ r . St u 7 l APPROVED BY Approved b .- tatONER THE COMMISSION Date: / 44 L:'1_-/41 Submit Form and Form 10-401(Revised 10/2012) This per i v i fo 2 months from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate . Monty Myers Hilcorp Alaska, LLC H.1C0 Drilling Engineer P.O. Box 244027 ��� Anchorage,AK 99524-4027 EneTel 907 777 8431 Email mmyers@hilcorp.com May 14th, 2014 Commissioner RECEIVED Alaska Oil &Gas Conservation Commission 333 W.7th Avenue MAY 14 201.4 Anchorage,Alaska 99501 AOGCC Re: Beaver Creek Unit 12A Dear Commissioner, Beaver Creek #12A is a sidetrack to replace the original BCU 12 lower Beluga production hole section with a new well. Production logging shows that all production from the BCU 12 well came from the Lower Beluga B23 sand. Other Beluga sands are prospective. The details of the directional plan are not critical: our intent is to sidetrack the well to the East and basically mimic the original BCU 12 production hole section.The new well will utilize the existing casing program down to 4800' MD. The base plan is a deviated wellbore reaching a maximum inclination of 19 deg and a 1082'vertical separation at TD. Drilling operations are expected to commence approximately June 7th,2014 with the Saxon Rig#169.This rig will be used to sidetrack the existing Beaver Creek #12 well, drill the new wellbore, run casing and cement. The Beluga formation will be perforated after the rig has moved off. 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. A separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack. General sequence of operations pertaining to this approved drilling procedure: 1. MOB Saxon Rig#169 to well site. 2. N/U&test BOPE. 3. M/U 4-1/2" DP and 7-7/8"string mill and TIH to CIBP at"'4800'. POOH standing back DP. 4. Run and set w)l ipstock, displace to drilling fluid at 9 ppg. Mill window and 20' of new formation. Conduct FIT to 11 ppg. 5. Drill 7-7/8" production hole section to TD. POOH 6. Make wireline logging passes. 7. Run and cement 5-1/2" production casing. 8. TOOH, LDDP 9. Land tubing hanger.Set BPV. 10. N/D BOP, N/U tree, RDMO Hilcorp Alaska, LLC Page 1 of 2 Ei Monty Myers Hilcorp Alaska, LLC H.1C0 Drilling Engineer P.O. Box 244027 sn�1i I Anchorage,AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, 1 • ..... s Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 2 of 2 H Hilcorp Alaska, LLC Beaver Creek 12A Drilling Program Beaver Creek Reviewed By: , ' _ S• a• Zo I LI f Approved By: 1 C 4th z) 5! /D/ r4 Revision 0 April 28, 2014 Beaver Creek 12A Drilling Procedure Rev 0 Ililrnrp:Uu.ka. Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program• 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 BOP N/U and Test 11 11.0 Mud Program and Density Selection Criteria 12 12.0 Whipstock Running Procedure 13 13.0 Whipstock Setting Procedure: 16 14.0 Drill 7-7/8"Hole Section 18 15.0 Run 5-1/2"Production Casing 21 16.0 Cement 5-1/2"Production Casing 24 17.0 RDMO 27 18.0 BOP Schematic 28 19.0 Wellhead Schematic 29 20.0 Days vs Depth 30 21.0 Geo-Prog 31 22.0 Anticipated Drilling Hazards 32 23.0 Rig Layout 33 24.0 FIT Procedure 34 25.0 Choke Manifold Schematic 35 26.0 Casing Design Information 36 27.0 7-7/8"Hole Section MASP 37 28.0 Plot(NAD 27) (Governmental Sections) 38 29.0 Surface Plat(As Built) (NAD 27) 39 30.0 Directional Program (P1) 41 Beaver Creek 12A Drilling Procedure Rev 0 Ililcon)Ala.ka,I.I.l: 1.0 Well Summary Well Beaver Creek#12A Pad&Old Well Designation Sidetrack of existing well Beaver Creek 12 Planned Completion Type 5-1/2" 17#P-110 Longstring Target Reservoir(s) Beluga • Planned Well TD,MD/TVD 10500' MD/ 10271' TVD PBTD,MD/TVD 10380' MD/ 10171'TVD Surface Location(Governmental) 2024' FNL,481'FEL, Sec 33,T7N,R1OW, SM,AK Surface Location(NAD 27) X=315325.75,Y=2433191.53 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 1896'FNL, 4474'FEL, Sec 34, T7N,R1OW, SM, AK TPH Location(NAD 27) X=316609.61,Y=2433307.3 TPH Location(NAD 83) BHL(Governmental) 1916'FNL,4439'FEL, Sec 34,T7N,R1OW, SM,AK BHL(NAD 27) X=316644.19,Y=2433287.03 BHL(NAD 83) AFE Number 1411321D AFE Drilling Days 16 AFE Drilling Amount $4.55 MM Work String 4-1/2" 16.6#S-135 CDS-40 RKB—GL 18.6' Ground Elevation 150' AMSL(geoprog) BOP Equipment 11" 5M T3-Energy(Model 7082)Annular BOP 11" 5M T3-Energy(Model 6011i)Double Ram 11" 5M T3-Energy(Model 6011i) Single Ram Page 2 Revision 0 May 2,2014 Beaver Creek 12A Drilling Procedure Rev 0 l l h orp:1laxka.1.1A: 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp LocivCcmpary Changes to Approved Permit to Drill Date: April 16,2014 Subject Changes to Approved Permit to Drill for Beaver Creek #12A File#: Beaver Creek #12A Drilling Program Any modifications to the Drilling&Completion Program will be documented and approved below. Changes to an approved APD will be communicated to the AOGCC &BLM_ Date Procedure Change Approved Approved BY BY Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Revision 0 May 2, 2014 Beaver Creek 12A Drilling Procedure Rev 0 Ilukorp:�lu-ka.LL1: 3.0 Tubular Program: Hole OD (in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension Section (in) OD (in) (#/ft) (psi) (psi) (k-lbs) 7-7/8" 5-1/2" 4.892 4.767 6.05 17 P-110 DWC/C 10640 7460 548 4.0 Drill Pipe Information: Hole OD (in) ID (in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension Section (in) (in) (#/ft) (psi) (psi) (k-lbs) 7-7/8" 4-1/2" 3.826 2-11/16" 5-1/4" 16.6 S-135 CDS-40 17693 16769 595k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 May 2, 2014 Beaver Creek 12A Drilling Procedure Rev 0 Hikrorp Alasku,IJ.( 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. i. Report covers operations from 6am to 6am ii. 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. iii. Ensure time entry adds up to 24 hours total. iv. 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 i. Submit a short operations update each work day to pmazzolini@hilcorp.com, lkeller@hilcorp.com, mmyers@hilcorp.com and jbarrett@hilcorp.com 5.3 5am Daily Morning Comments i. Submit a short operations update each day via the Hilcorp main web page under"Enter Drilling Comment" ii. Be sure to include Daily Cost, Cumulative Drilling Cost and Total AFE 5.4 EHS Incident Reporting i. 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:0:(907)777-6726 C: (907)227-3189 b. Mark Tornai:0: (907)283-1372 C: (907)748-3299 c. Thad Eby: 0: (907) 777-8317 C: (907) 602-5178 2. Spills: Kate Kaufman: 0:907-777-8329 C:907-244-8292 ii. Notify Drlg Manager 1. Paul Mazzolini:0: 907-777-8369 C: 907-317-1275 iii. Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally i. Send final"As-Run"Casing tally to mmyers@hilcorp.com and jbarrett@hilcorp.com 5.6 Casing and Cmt report i. Send casing and cement report for each string of casing to mmyers@hilcorp.com and jbarrett@hilcorp.com Page 5 Revision 0 May 2, 2014 Beaver Creek 12A II Drilling Procedure Rev 0 Ililcorp Alaska,IAA: 6.0 Planned Wellbore Schematic BC-12A PROPOSED Pad 4 SCHEMATIC llil,,,,A. k..6::.Lir: 2,023' FNL,482'FEL, Sec.33,17N, R10W,S.M. Existing Conductor Permit#• 203-188 _`_____ 20" K-55 133 ppf API#: 50-133-20530-00-00 Bottom Property Des: A-028083 MD 17 10T KB; 21'AGL (171'KB Elevation) ti. TVD 17 1oT Lat: 60° 39' 22.118° N [SwellPacker Long: 151° 01' 45.593"W @4300'MD Existing Surface Casing Spud: 5272004 • ; `,' 73318" K 55 68 ppf BTC TD Reached: 6/10/2004 11, S0' B4O1 rim o• z,osr Rig Released: 00:00 hrs 06/15/04 KDP@4800' TVD 0' 2,091• • MD - 16"hole Cmt vs/600 sirs(271 bbl)of 120 ppg, Type 1 ant, 18 sks(8 bbls)to surface Existing Intermediate Casing Tree cxn=6-1/2-'0Us 9-518' L-80 40 ppf BTC t Too flot>nm MD 0' 7,1617 Bridge Plug @4,800 e; TVD Cr 6,978' 12-114"hole Lead Cmt w1833 sks(341 bbls)of Jet Cut Tubing@ 6`100' '', :; r 125 ppg,Class G, Tail Cml w/327 sks(106 bbts) .+ ',Z 1 of 13.5 ppg,Class G, 12sks(5bbls)to surface r Tubing Punch a 6,110' `.•: :1 Top of Cement ' ),: 6,400'MD '; Inclination Detail 4' Drill 7-7/8"Hole 1,, 1; Tubing Plug 07,200' i 1 1:1KOP:4800' - Azimuth:55 degrees Csppedtad35'Cement (� •,.• Hold:19 deg inclination Turn:55azi to 120 azi from 4850'to5893' ty' - I h, - Hold:19 deg inclination to 7138' „! T . Drop:2 deg per 100'to vertical at 8021' DI j Z t. TD at 10,500' , I f `' [� )t . if .,, -D) i 1-DIIS, , Proposed Production Casing -� 1 'Lr /- 5-1/7 Too Bottom P-110 17 ppf DWC/C ' C 11, '. ? •'t L i4 t.' MD 18' 10,500' r,. TVD 18' 10,271' 7-718"hole,proposed to cement to inside i:, window with 500"of overlap i 1 ; i , • Original TD 8,839'MD 1 '' 8,656'TVD h Proposed ID J 10,500'MD 10,271'TVD • Page 6 Revision 0 May 2,2014 Beaver Creek 12A Drilling Procedure Rev 0 Ilileorp.11a,ka,1.1.1: 7.0 Drilling Summary Beaver Creek#12A is a sidetrack to replace the original BCU 12 lower Beluga production hole section with a new well. Production logging shows that all production from the BCU 12 well came from the Lower Beluga B23 sand. Other Beluga sands are prospective. The details of the directional plan are not critical: our intent is to sidetrack the well to the East and basically mimic the original BCU 12 production hole section. The new well will utilize the existing casing program down to 4800' MD. The base plan is a deviated wellbore reaching a maximum inclination of 19 deg and a 1082' vertical separation at TD. Drilling operations are expected to commence approximately June 7th, 2014 with the Saxon Rig #169. This rig will be used to sidetrack the existing Beaver Creek #12 well, drill the new wellbore, run casing and cement. The Beluga formation will be perforated after the rig has moved off. 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. A separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack. General sequence of operations pertaining to this approved drilling procedure: 1. MOB Saxon Rig #169 to well site. 2. N/U &test BOPE. 3. M/U 4-1/2"DP and 7-7/8" string mill and TIH to CIBP at 4800'. POOH standing back DP. 4. Run and set whipstock, displace to drilling fluid at 9 ppg. Mill window and 20' of new formation. Conduct FIT to 11 ppg. 5. Drill 7-7/8"production hole section to TD. POOH 6. Make wireline logging passes. 7. Run and cement 5-1/2"production casing. 8. TOOH, LDDP 9. Land tubing hanger. Set BPV. 10. N/D BOP,N/U tree, RDMO Page 7 Revision 0 May 2, 2014 Beaver Creek 12A 1 ti Drilling Procedure Rev 0 Ilacorp 11a.ka,I.1.1: 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 Beaver Creek#12A. 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 is posted on the rig floor and in Co Man office. Variance Requests: • Onshore Oil and Gas Order No. 1, Section III. D. 3. C. o Hilcorp requests approval to install a 3-1/8" 5M HCR valve on kill line in lieu of a check valve. Operator suspects a freeze plug risk associated with installation of a check valve in the kill line. o Hilcorp requests approval to utilize flexible choke and kill lines in lieu of hard piping. Page 8 Revision 0 May 2, 2014 Beaver Creek 12A Drilling Procedure Rev 0 Ilileorp 11a.ka,LLC Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) • 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 7-7/8" • 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 Y 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. Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/ (0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0):907-793-1226/(C): 907-301-4533 /Email: guy.schwartz@alaska.gov Victoria Ferguson/Petroleum Engineer/ (0): 907-793-1247/Email: Victoria.ferguson@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236 (During normal Business Hours) Notification/Emergency Phone: 907-659-2714(Outside normal Business Hours) Page 9 Revision 0 May 2, 2014 Beaver Creek 12A Drilling Procedure Rev 0 Ililworp%Ia.ka.1.1.(: 9.0 R/U and Preparatory Work 9.1 A separate sundry will be submitted that will include the following: • MIRU workover rig. • Set BPV,remove tree. • N/U and test BOP. • Pull existing production tubing. Plug back well with cmt. • Tag &pressure test cmt plug. • Run and set a CIBP at 4800' MD. • • RDMO workover rig. 9.2 Level pad and ensure enough room for layout of rig footprint and R/U. 9.3 Layout Herculite on pad to extend beyond footprint of rig. 9.4 R/U Saxon Rig #169, spot service company shacks, spot &R/U company man&toolpusher offices. 9.5 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.6 Mix mud for 7-7/8"hole section. 9.7 Set test Plug in wellhead prior to N/U BOP to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.8 Verify 5-1/2" liners installed in mud pumps. • HHF-1000 Pumps are rated at 3572 psi(100%) with 5-1/2" liners and can deliver 370 gpm at 120 spm. This will allow us to drill the 7-7/8" hole section with(1) mud pump. Page 10 Revision 0 May 2, 2014 Beaver Creek 12A El Drilling Procedure Rev 0 Ilili»rp 11i,ka,1.1.1: 10.0 BOP N/U and Test 10.1 N/U 11"x 5M BOP as follows: • BOP configuration from Top down: 11" x 5M annular BOP/11"x 5M double ram/11"x 5M mud cross/I1"x 5M single ram. t/ • Double ram should be dressed with 2-7/8" x 5" VBR in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8" x 5"VBR. • N/U bell nipple, install flowline. 10.2 Run BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/4500 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Ensure to leave "A" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. Confirm the correct valves are opened!!! • Test VBRs on 4-1/2"test joints. 10.3 R/D BOP test assy. 10.4 Continue mixing mud for 7-7/8" hole section. 10.5 Set wearbushing in wellhead. Ensure ID of wearbushing > 7-7/8". Page 11 Revision 0 May 2,2014 Beaver Creek 12A Drilling Procedure Rev 0 tli!cog) 11a-ka.1.11: 11.0 Mud Program and Density Selection Criteria 11.1 7-7/8" Production 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 to (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 Density Viscosity Plastic Viscosity Yield Point pH HPHT 4800'—10500' 9-10 . 40-53 15-25 15-25 8.5-9.5 <_11.0 '� '51 � System Formulation: 6% KCI/ EZ Mud DP Product Concentration S Water 0.905 bbl A KC1 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) ‘itif BARAZAN D+ EZ MUD DP 1.25 ppb (as required 18 YP) 0.75 ppb(initially 0.25 ppb) DEXTRID LT 1-2 ppb PAC-L 1 ppb BARACARB 5/25/50 10 ppb(3.3 ppb of each) STEELSEAL 50/100/400 2—4 ppb BAROTROL PLUS 2 ppb Soltex 2 ppb BAROID 41 as required for a 9.0—9.5 ppg • ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) 11.2 Program mud weights are generated by reviewing data from producing & shut in offset wells, • estimated BHP's from formations capable of producing fluids or gas and formations which could require mud weights for hole stabilization. 11.3 A guiding philosophy will be that it is less risky to weight up a lower weight mud than be overbalanced and have the challenge to mitigate lost circulation while drilling ahead. Page 12 Revision 0 May 2, 2014 Beaver Creek 12A 14 Drilling Procedure Rev 0 ��I�l'llfll. la ka,I L(: 12.0 Whipstock Running Procedure 12.1 M/U window milling assembly and TIH w/4-1/2"DP off of pipe rack. • Use a 7-7/8"taper mill (or 7-7/8" mill tooth bit) and a 7-7/8" string mill above to ensure whipstock assy will pass freely. • Ensure BHA components have been inspected previously. • Caliper and drift all BHA components before running them in the hole. • Drift DP prior to RIH. • Lightly wash and ream any tight spots noted. 12.2 TIH to CIBP (4800' MD). Note that this was a wireline measurement so actual depth tagged • may vary slightly. Keep up with the#of joints picked up so we know where we are. 12.3 CBU &circ at least (1) hi-vis sweep to remove any debris created by the clean out run. Anything left in the wellbore could affect the setting of the Whipstock. 12.4 Displace to 9.0 ppg 6%KC1/PHPA fresh water based drilling fluid. • 12.5 Pressure test casing to 3000 psi/ 30 min. Chart record casing test &keep track of the amount of fluid pumped. Stage up to 3000 psi in 500 psi increments. 12.6 TOH. 12.7 Make up mills on a joint of HWDP. 12.8 RIH &set in slips. 12.9 Make up float sub, install float. 12.10 Make up UBHO sub. 12.11 Orient UBHO to starter mill. 12.12 Leave assembly hanging in the elevators, and stand back on floor. 12.13 Bring Whipstock to rig floor on the pipe skate. Do not slam into bottom of Whipstock with pipe skate. 12.14 Pick up Whipstock per Baker rep using the Baker Whipstock handling system using air hoist. Allow assy to hang while Baker Rep inspects and removes shear screws as needed and any safety screws. Page 13 Revision 0 May 2, 2014 Beaver Creek 12A Drilling Procedure Rev 0 Ilifrorp Note: Anchor should be pinned with 6 shear screws initially. Shear screws are rated for 6,630 lbs each. REMOVE 3 screws for a set down shear of 6,630 x 3=19,890 lbs. Note: Attach mills to Whipstock with (1)35k mill shear bolt 12.15 If needed, open BOP Blinds. 12.16 Run the Whipstock in the hole, install safety clamp as per Baker Rep, and install hole cover wrap. 12.17 Release pick up system at this point, Make up mills. 12.18 With the top drive,pick the assembly and position the starting mill to align with the hole in the slide. The Baker Rep will instruct the driller when the slot is lined up,the shear bolt then can be made up by the Baker Rep. 12.19 The assembly can now be picked up to ensure that the shear bolt is tight. 12.20 Remove the handling system. 12.21 Slowly run in the hole as per Baker Rep. run extremely slow through the BOP &wear bushing. 12.22 Run in hole at 1 V2 to 2 minutes per stand. 12.23 Fill every 30 stands or as needed, do not rotate or work the string unnecessarily. 12.24 Call for Baker Rep. 15— 10 stands before getting to bottom. 12.25 Orient at least 30' —45' above the CIBP. Ensure to have gyro personnel and equipment as well as a wireline unit R/U and ready. Page 14 Revision 0 May 2, 2014 Beaver Creek 12A Drilling Procedure Rev 0 Ililcorp:llu.ka, WindowMaster G2 System on TorqueMaster BTA 9 5/8"40#Csg—WindowMaster G2 On BTA BHA#1 Connection Length O_D. BOTTOM TRIP ANCHOR 4Y:IF-Box X Bottom Guide 3.42' 8.352" WINDOW MASTER WHIPSTOCK Shear Bolt X 4'A IF-Pin 18.54' 8.00" WINDOW MILL 4-1/2 Reg-Pin X Mill 1.3' 8.500" LOWER WATER MELON MILL 4-1/2 IF-Box X 4-1/2 Reg-Box 5.67' 8.375" FLEX JOINT 4-1/2 IF-Box X 4-1/2 IF-Pin 9.00' 6.375" UPPER WATER MELON MILL 4-1/2 IF-Box X4-1/2IF-Pin 6.17' 8.500" 1 JT HWDP 4-1/2 IF-Box X 4-1/2 IF-Pin 30' 6.50" MWD Survey Tool 4-1/2 IF-Box X 4-1/2 IF-Pin 6.50" UBHO 4-1/2 IF-Box X 4-1/2 IF-Pin 6.50" Bowen Lubricated Bumper Jar 4-1/2 IF-Box X 4-1/2 IF-Pin 6.250" 6 DRILL COLLARS 4-1/2 IF-Box X 4-1/2 IF-Pin 180' 6.75" 30 JTS—HWDP 4-1/2 IF-Box X 4-1/2 IF-Pin 900' 6.50" CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY Page 15 Revision 0 May 2, 2014 Beaver Creek 12A Drilling Procedure Rev 0 Ililcorp ala-ku,1.1.1: 13.0 Whipstock Setting Procedure: 13.1 With the bottom of the Whipstock 30—45' above the CIBP, measure and record P/U and S/O weights. Run gyro survey to orient Whipstock face. 13.2 Orient Whipstock to desired direction by turning DP in 1/4 round increments. P/U and S/O on DP to work all torque out (Being careful not to set BTA). Whipstock Orientation Diagram: 30R (:::: 90R Desired orientation of the Whipstock face is 30 to 90 degrees right of high side. Hole Angle at the window interval (4800' MD) is < 19 deg. The wellbore trajectory is planned to the right of the existing wellbore in an azimuth of 119 degrees. 13.3 Once Whipstock is in desired orientation, slack off and tag CIBP to set Bottom Trip Anchor. 13.4 Set down 12-15K on anchor to trip, P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by slacking off weight on the Whipstock shear bolt. (25k shear value). PYA 13.5 P/U 5-10' above top of Whipstock. T13.6 Displace to 9 ppg 6%KCUPHPA drilling fluid (if not done previously). , 13.7 Record P/U, S/O weights, and free rotation. Slack off to top of Whipstock and with light weight and low torque. Mill window. Utilize 4 ditch magnets on the surface to catch metal cuttings. Y !V 14-2 13.8 Install catch trays in shaker underflow chute to help catch iron. ro 13.9 Keep iron in separate bbls. Record weight of iron recovered on ditch magnets. Page 16 Revision 0 May 2, 2014 Beaver Creek 12A Drilling Procedure Rev 0 II ilrurp 1.IA: 13.10 Estimated metal cuttings volume from cutting window: 9-5/8"40# L-80 Cuttings Weight Window Length Casing Weight Min (lbs) Avg(lbs) Max(lbs) 17 40# 150 225 300 13.11 Drill approx. 20' rat hole to accommodate the drilling assembly. Ream window as needed to assure there is little or no drag. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 13.12 Circulate Bottoms Up until MW in= MW out. 13.13 Conduct FIT to 11 ppg EMW. • (11 —9) * 0.052 * 4706' tvd=489 psi Note: Offset field test data predicts frac gradients at the 7"window to be between 13 ppg and 15 ppg. A 11 ppg FIT results in a 2 ppg kick margin while drilling the interval with a 9 ppg fluid density. 13.14 Slug pipe and POOH. Gauge Mills for wear. 13.15 Should a second run be required pick up the following BHA. Back Up Mills Connection Length O.D. WINDOW MILL 4 '/2 REG-P X MILL 1.30 8.50 NEW LOWER WATERMELON MILL 4 1/2 IF-B X 4 %2 REG-B 5.67 8.50 FLEX JOINT 4 '/2 IF-B X 4 '/2 IF-P 9.00 4.75 UPPER WATERMELON MILL 4 '/2" IF-B X 4 '/" IF-P 6.17 8.50 FLOAT SUB 4 '/2" IF-B X 4 '/2" IF-P 3.00 4.75 XO sub and 30 jts-HWDP 4 '/2' CDS40-B X 4 '/2' IF-P 900' 5.25 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY! Page 17 Revision 0 May 2, 2014 Beaver Creek 12A Drilling Procedure Rev 0 Ililcorp.11anka, 14.0 Drill 7-7/8" Hole Section 14.1 P/U 7-7/8" directional drilling assy. 14.2 Ensure BHA Components have been inspected previously. 14.3 Drift & caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 14.4 Ensure TF offset is measured accurately and entered correctly into the MWD software. 14.5 Confirm that the bit is dressed with a TFA of 0.48 —0.61 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 275 - 350 gpm. 14.6 Motor AKO should be set at 1.15 deg. Must keep up with 2 deg/100 DLS in the build and drop sections of the wellbore. 14.7 Primary bit will be the Halliburton 7-7/8" FX55 PDC bit. Spec sheet attached on next page. Ensure to have a few mill tooth bits (IADC 117W) available on location. Page 18 Revision 0 May 2, 2014 Beaver Creek 12A II Drilling Procedure Rev 0 Hileorp la-ka,I.1A: 7J/8" (2oomm) FX55 PRODUCT SPECIFICATIONS _ Cutter Type K3-Extreme Drilling V I.ADC Code M324 Body T}pe MATRIX .r Total Cutter Count 37 4 1; Cutter Distribution ream l(m m , Face 0 22 ' `� Gauge 10 Ci i , Back Ream 2 0 Up Drill 3 0 �� Number of Lame Nozzles 0 Number of Medium Nozzles 0 Number of Small Nozzles 5 Number of Micro Nozzles 0 ,` Number of Ports 1 Size 1 0 Number of Replaceable Ports(Size) 0 • {4 Junk Slot Area(sq in) 11.54 .=t ' Co' ill? Normalized Face Volume 41.42°0 on: API Connection 4-1/2 REG.PIN s Jilt ill Recommended Make-Up Torque* 12.461-17.766 Ft•lbs. Nominal Dimensions* Make-Up Face to Nose 10,13 in-257 mm Gauge Length 2.5 in-64 mm Sleeve Length 0 in-0 mm Shank Diameter 5.75 in-146 mmJ ' Break Out Plate(Mat.4.Legac}T) 18195441040 Approximate Shipping Weight 120Lbs.-54Kg. SPECIAL FEATURES Up-Drill Cutters on Gage Pads.Back Reaming Cutters on Gage Pads. Hexagon TSP Gage.1,.'16"Relieved Gage Material 4'711778 "Bit specific recommended make-up torque is a function of the bit I.D.and actual bit sub O.D.utilized as specified in API RP7G Section A_F.2. "Design dimensions an nominal and may carp slightly on manufactured product_Halliburton Drill Bits and Scrcia,models are continuously minted and refine!. Product specifications may change without notice. C 2014 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.halllburton.com Page 19 Revision 0 May 2, 2014 Beaver Creek 12A Drilling Procedure Rev 0 Ilikurp Ala.ka,I.1A: 14.8 TIH to window. Shallow test MWD on trip in. 14.9 TIH through window, ensure Baker service rep on rig floor during this operation. • Do not rotate string while bit is across face of Whipstock. 14.10 Drill (and LWD log) 7-7/8"hole to 10500' MD using above motor assembly. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • See attached mud program for hole cleaning and LCM strategies. • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain HTHP fluid loss < 6. • Take MWD surveys every stand drilled. 14.11 Hilcorp Geologists will follow LWD log closely to determine exact TD. 14.12 At TD pump a sweep and a marker to be used as a fluid caliper to determine annulus volume for cement calculations. CBU, and pull a wiper trip back to the window. 14.13 TOH with drilling assy, handle BHA as appropriate. VI Page 20 Revision 0 May 2, 2014 Beaver Creek 12A Drilling Procedure Rev 0 Ililcorp‘18,1a,1.1.1: 15.0 Run 5-1/2" Production Casing 15.1 R/U Weatherford 5-1/2" casing running equipment. • Ensure 5-1/2"DWC/C x 4-1/2" 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. 15.2 P/U shoe joint,visually verify no debris inside joint. 15.3 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/shoe bucked on&threadlocked(coupling also thread locked). • (1) Baker locked joint. • (1) Joint with float collar bucked on pin end&threadlocked(coupling also thread locked). • (1) Joint with landing collar bucked up. • Solid body centralizers will be pre-installed on shoe joint, FC joint, and LC joint. • Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe &FC. 15.4 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 other joint to window. Leave the centralizers free floating. • Install tandem rise bow springs every other joint thereafter to the window. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 5-1/2" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 5-1/2" 12,000 ft-lbs 13,800 fl-lbs 18,700 ft-lbs Page 21 Revision 0 May 2, 2014 B Drillingeaver ProcedureCreek12A Rev 0 IIi!rorlr Ua>ku.LLf. Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWC C-HT Casing 5-1/2 in 17.00 ib.lft(0.304 in} P-110 standard Material P-110 Grade 110,000 Minimum Yield Strength (psi) 1111111111111111111111111,USA 125,000 Minimum Ultimate Strength (psi) l AN1 USA 4424 W Sam f-buston Pse y.Suite 150 Pipe Dimensions Hcust._7,T%77041 Phone:713470-320C 5.500 Nominal Pipe BodyO.D. (in) Fax:713470-3234 4.892 Nominal Pipe Body I.D.(in) E-mail:VAMUSAsalesloam-usa.con- 0.304 Nominal Wall Thickness(in) 17.00 Nominal Weight(Ibsrft) 16.89 Plain End Weight(Ibsi ft) 4.962 Nominal Pipe Body Area(sq in) Pipe Body Performance Properties 546,000 Minimum Pipe Body Yield Strength(lbs) 7,480 Minimum Collapse Pressure(psi) 10,640 Minimum Internal Yield Pressure(psi) 9,700 Hydrostatic Test Pressure(psi) Connection Dimensions 6.050 Connection O.D. (in) 4.892 Connection I.D.(in) 4.767 Connection Drift Diameter(in) I 4.13 Make-up Loss (in) 4.962 Critical Area (sq in) t 100.0 Joint Efficiency(%) Connection Performance Properties 546,000 Joint Strength(lbs) 22,940 Reference String Length(ft) 1.4 Design Factor 568,000 API Joint Strength(lbs) 546,000 Compression Rating (lbs) 7,480 API Collapse Pressure Rating(psi) 10,640 API Internal Pressure Resistance(psi) 91.7 Maximum Uniaxial Bend Rating [degrees/100 ft) Appoximated Field End Torque Values 12,000 Minimum Final Torque(ft-lbs) 13,800 Maximum Final Torque(ft-lbs) 18,700 Connection Yield Torque(ft-lbs) Page 22 Revision 0 May 2, 2014 B Drillingeaver ProcedureCreek12A Rev 0 Hilcorp Alask11.1.1.1: 15.7 Run in hole w/ 5-1/2" casing. 15.8 Fill the casing with fill up line and break circulation every 1,500 feet to the window or as the hole dictates. 15.9 Obtain slack off weight, PU weight, rotating weight and torque of the casing. 15.10 Circulate 2X bottoms up at window, ease casing thru window. 15.11 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. 15.12 Set casing slowly in and out of slips. 15.13 At approximately 4300' TMD, install 5-1/2"X 8-1/2" swell packer. Swell packer should have handling pups installed on both ends. 15.14 Swedge up and wash last 5 joints to bottom. P/U 5' off bottom. Note slack-off and pick-up weights. 15.15 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. 15.16 Reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 23 Revision 0 May 2,2014 111 B Drillingeaver PCreekrocedure12A Rev 0 11thurp \Iaska,I.1.1 16.0 Cement 5-1/2" Production Casing 16.1 Hold a pre-job safety meeting over the upcoming cmt operations. 16.2 Attempt to reciprocate the casing during cmt operations until hole gets sticky. 16.3 Pump 10 bbls 12.5 ppg MUDPUSH II spacer. 16.4 Test surface cmt lines to 4500 psi. 16.5 Pump remaining 25 bbls 12.5 ppg MUDPUSH II spacer. 16.6 Mix and pump 263.7 bbls of 15.3 ppg class "G" cmt per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump 35% OH excess but if fluid caliper dictates otherwise we may increase excess volumes. Cement volume is designed to give 500' of cement inside window in annulus between 9-5/8" casing and 5-1/2" casing. , 6° Cement Calculations -(t; c� ✓� 9-5/8"Casing x 5-1/2"Ann: ilk. 500' x 0.0464 = 23.2 bbls 7-7/8" off x 5-1/2"Ann+ (10500' —4800') x .0309 x 1.35 = 237.7 bbls 35%excess Shoe Track: 120' x 0.02325 = 2.8 bbl ( o`l 3 Total Volume(bbls): 23.2 +237.7 +2.8 = 263.7 bbls Total Volume(ft3): 263.7 bbls x 5.615 ft3/bbl= 1481 ft3 ''/ Total Volume(sx): 1481 ft3 / 1.35 ft3/sk= 1097 sx ' Page 24 Revision 0 May 2,2014 14 B Drillingeaver PCreekrocedure12A Rev 0 Iliicorp Alaska.1.1.1: Slurry Information: System Easy BLOK Density 15.3 lb/gal Yield 1.35 ft3/sk -� Mixed Water 5.879 gal/sk Mixed Fluid 5.879 gal/sk Expected Thickening 70 Be at 05:00 hr:mn API Fluid Loss <25 mL in 30.0 min at 155degF/ 1000 psi Code Description Concentration G Cement 94 lb/sk D046 Anti Foam 0.2%BWOC Additives D202 Dispersant 1.5%BWOC D400 Gas Control Agent 0.8%BWOC D154 Extender 8.0%BWOC 16.7 Drop wiper plug and displace with produced water. 16.8 If hole conditions allow—continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100%coverage around the pipe. 16.9 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. 16.10 Bump the plug and pressure up to 500 psi over final lift pressure. Hold pressure for 3 minutes. 16.11 Do not overdisplace by more than Y2 shoe track. Shoe track volume is 2.6 bbls. 16.12 Bleed pressure to zero to check float equipment. Watch for flow.Note amount of fluid returned after bumping plug and releasing pressure. 16.13 RD cementers and flush equipment. 16.14 WOC minimum of 12 hours, test casing to 4500 psi and chart for 30 minutes. Page 25 Revision 0 May 2,2014 B Drileaverling ProcedureCreek12A Rev 0 Rilcorp.11u.ku,1.1,1: 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 Note: Send Csg & cmt report+ "As-Run"liner tally to mmvers(&,hilcorp.com Page 26 Revision 0 May 2, 2014 Bea Drillingver ProcedureCreek12A Rev 0 Ilileorp:�lu.ku. 17.0 RDMO 17.1 Install BPV in wellhead. RILDs. 17.2 N/D BOP. 17.3 N/U temp abandonment cap. 17.4 RDMO Saxon Rig#169. 1 gIc“' ±'--- CSBL 0-11-6-1-4,11 17-- IA 7`.e-r---;7-k-0 G z -/y Page 27 Revision 0 May 2, 2014 II B Drillingeaver ProcedureCreek12A Rev 0 Ilileorp Alaska,1.1.1: 18.0 BOP Schematic ET - --, Nif ithittu ij fi Irmimir1` 1 1!1 1!11 I rpl..t ....1.1 H - !!f r1,1s1 u II 2. E. II+ LhI: 1701 :� I 1.44*. -iiI14 1 1 1 if tlittittall i 2 1/16 SM Kill Side 1 3 1/8 SM Choke Side 1.41' s, e--r-1111 f � b. i I L r l IIDITIZMUT — Gr iciG 2.63' . UT— til1tnfi 11U1 as `t . - I �� i 'Emit li lir 1.... .i+ iL 1111 rr , 1 Page 28 Revision 0 May 2,2014 Bea Drillingver ProcedureCreek12A Rev 0 rrileorp Alaska,TIC 19.0 Wellhead Schematic Beaver Creek BCri 12 Tubing hanger,CXS,11 X 5'A 20X133/8X95/8X5% left hand acme lift X5'A DWC-C susp,w/5"Type H BPV profile Tree cap Otis,5 1/16 10M FE X 935 Otis Quick Union ii ■wTwn I►+..r i. •f L, bye Valve,Swab,CIW-FC, Oc�.QF'` 0s 0�oQe 5 1/1610M FE,HWO, • `,e�yO�.a-�Cc .yOti CP 0s trim • •. Ja,5 NS1. 0 �� J(�:10��cc l\n •'f O Ja\P C • I!/ 01 Valve,Upper Master, I, CIW-FC,5 1/16 10M FE, HWO,DD trim OG Valve,Master,CIW-FC, *. s 51/1610M FE,HWO, DD trim flO r 0 M 0 Completion spool,Cactus, ® •-- ■ a I 135/85M X115M 111 I' p 111 I .®i;i�l n�+rd■. Grade Level Multibowl,Vetco MB-196, 13 5/8 3M stdd bottom X Valve,VG-200,21/16 5M FE, 13 5/8 5M FE top,w/ r_ !/ i��4�: 1 c HWO,AA trim 2-2 1/16 5M 55O I im �•� r L. _ ,�I a-1_,. I ■ ■ lei a. f Starting head, ! Vetco MB-196, ���-■■■- --•E� r 135/83M X133/8 VG-Loc 1mm� bottom,w/2-2"LPO Il 20„ 13 3/8" 9.625" 5'A" Page 29 Revision 0 May 2, 2014 B Drillingeaver ProcedureCreek12A Rev 0 Dikarp 20.0 Days vs Depth Days Vs Depth Beaver Creek # 2A 4000 -u 8000 10000 12000 0 5 10 15 20 25 Days Page 31 Revision 0 May 2, 2014 II B Drillingeaver ProcedureCreek12A Rev 0 tlilcorp Alaska,1.1A: 21.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: BCU 12A (SToutofBCU 12) FIELD: Beaver Creek SURFACE: X=315322.1 LONG: -151.0293: (BCU 12 Well) STATE: Alaska Y=2433199.0 LAT:60.6561400 BOTTOM HOLE ,X=316448.7 LONG: -151.0230738 TVD REF DATUM KB ^V� Y=2433562.2 LAT: 60.6571816 TVD REF ELEV ' 169 18.6'KB(Saxon 169) i COORD REF. SYSTEM NAD27 GROUND ELEV - 150' PROPOSED TD: 10,500'MD/10,271'7VD. KOP=4,800'MD 1._ lW Objective: Lower Beluga B18-B32 gas sands . Geo Summary/ L---- _.I. — —� Justification: The goal of the BCU 12Asidetrack is to replace the original BCU 12 lower Beluga production hole section with a new well. Production logging shows that all production from the BCU 12 well came from the Lower Beluga B23 sand. Other Beluga sands are prospective. The details of the directional plan are not critical: 1 our intent is to sidetrack the well to the East and basically mimic the original BCU 12 production hole section I' tp1� ` ANTICIPATED FORMATION TOPS&GEOHAZARDS i.`j ` .17 EXPECTED I Critical Intersection Points TOP ,y, TOP NAME FORMATION FLUID TVD(F1 TVDSS(F7) Est. -rassvre X Y Wv Y� Y +/ KOP Sterling water 4,706 -4,537 12300 psi B1 Sterling water 4,934 -4,765 , 1 0-2300 psi 315891.4 2433571.7, 20 7J, B3 Sterling water/gas 5,096 -4,927 1900-2300 psi 315949.3 2433567.9 20 / p 7 B4 Sterling water/gas 5,257 -5,088 ' 1900-2300 psi 316003.3 2433567.9 20 //l B18 Beluga gas 7,280 -7,111 1000-3300 psi 316420.4 2433564.0 30 /l B23 Beluga gas 7,696 -7,527 1000-3400 psi 316428.1 2433564.0 30 ! 5 I B24 Beluga gas 7,808 -7,639 3000-3500 psi 316431.9 2433564.0 30 B28B Beluga gas 8,142 -7,973 ' 3000-3600 psi 316435.8 2433564.0 30 B30 Beluga gas 8,265 -8,096 3000-3600 psi 316439.7 2433564.0 30 Tyonek Tyonek water 8,765 -8,596 3000-3600 psi 316447.4 2433564.0 30 TD 10,271 -10,102 See BHL above =Primary Objective =Secondary Objective TARGET RADIUS 100 ft M=I DATA COLLECTION REQUIREMENTS: Mud Logging: Full crew of4 for production hole section. 2 sets of washed&dried samples collected every 20 ft from KOP to TD. Pinder plots and sh / LVVD Data: Sperry Quad Combo • E-Line Log Data: SLB Quad Combo&XPT(formation pressures) . COMPLETION TYPE Gas lift completion ANTICIPATED RATES ARTIFICIAL LIFT EQUIPMENT OD TUBING SIZE 2-7/8" Page 31 Revision 0 May 2, 2014 14 B Drillingeaver ProcedureCreek12A Rev 0 llikrtrp ila.ka.l.l.l: 22.0 Anticipated Drilling Hazards Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material, 500 lbs SteelSeal(Angular, dual-composition carbon-based 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/viscofier as necessary. Sweep hole w/20 bbls flowzan as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain programmed mud specs. 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. 1 No abnormal temperatures or pressures are present in this hole section. Page 32 Revision 0 May 2, 2014 Beaver Creek 12A ii 1--- Drilling Procedure Rev 0 Illilcorp Alaska,1.1A: 23.0 Rig Layout MEL 1,"r ". PPE RES Z4ingiigiilli 11". AM M, .I oil _ _ _ ` ..r FF,F E TANK �_I-I_Irl=rl-� I�I I- ® - 'VIII i�il�IF _ Y, 'l •ii all 1 111- -_lug-a qn ,-;��' ..E.�E�L� 11= .-.=-=. . 10 �I�II 1_ �' E�iu i •iir Bali smarm.* __ —. n r r_�rr.•.k I 4. � ..I c M ; _, NII - :,.—=.= .—. I'� u.,, , _ — �. � ,r. '111IIIII H,�� 1111011 - _. ®_ '�� _ ----- I ' -E] i. iIIIIIIIOpa I sm ---1.kF u;,lr.e • 111111111I r P:w a,,II PI, I 1 L giP All I [iiJg:i II ___ _ --- r.-nn r�w.m T.,.r m.-amu • MNIMIN • Page 33 Revision 0 May 2,2014 11 Bea Drillingver ProcedureCreek12A Rev 0 Hilcorp Alaska,I.I.0 24.0 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 34 Revision 0 May 2,2014 II Bea Drillingver ProcedureCreek12A Rev 0 Ii h•orp Ua,ka.1.1.1: 25.0 Choke Manifold Schematic • nr. 07.24. 4342I 4152 !1 7 am" 4c3r,. Aro 4143 14.52 I�W' i4 2 7&43 0 rY��i 'I —R19 —018 4.G,..- i.f —a.,8 0.19—— S t,.��tc r0.,3niii '�i_j 419 GC A. Q79—�,..4. I mil• J �� ii 0 0.19J IC C 11 a O19J 1 7.84 0-13 •' ,�1! 1![7!1 0.C4 O 7.04 I I a13 __l915* Q an n num I �� 1 .Q I( 0.13 J 38.03 { ' w_i!_ Ill ril:h at9J ® _ 14.62 1. ,�O�P+innn' yy_�`ry�,n� 14.82^.03 I r 0.,9 edf' C \ i= 18.52 1:8_k ( ' � 53 �k;� 1 1 IN I/NW,,, 1 cog o1sJ 10 all i' r ••L f•• 10.50 '�, I FO.�A .. ! 2' wA;1114 4r,. • �c��lll q..,..„.„..,,,.„,1121,7-.-44111112111°1111 aro IT u'■ u,1—419 11 -. `\-Y2UAL 02 CHOKE AMA,m —0 .79 -4i9 O.i9 Wilmi 0.19 — --0.19 °MU.MON -.-8.34 ----"'11.82 -..^-^--14.d2... .""'.."'•14.62 14.62----B.St 4102 4142 .— 1 Y 4;'b..',,:i; 87.24 G➢ 1.LAYOUT%IN R CA09ETS !(./: `L'"".""...'.....`.... m 14: ,8' '• •: DO noru r 5nn••••` ••••• r i :t.,�c-iiirea: r.m mo «SS L. O smut rAmono.-1/rfsI sow MIt IDK Oa RAI NTA 1X-27 74-Y3511K10 MIS 11- ... "_r.�T'-'� -✓r ,� 1._ .. {I Ih-1rm4s-as-�t�oR Page 35 Revision 0 May 2, 2014 Beaver II Drilling ProcedureCreek12A 1 Rev 0 II1l1'orp 1Ia,ka,HA. 27.0 7-7/8" Hole Section MASP IIMaximum Anticipated Surface Pressure Calculation H;Icorp 7-7/8"Hole Section " Beaver Creek#12A Kenai,Alaska MD ND Planned Top: 0 0 Planned TD: 10500' 10271' Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad KOP 4,706 2050 - Water 8.4 0.436 Sterling 131 4,934 2200 Water 8.6 0.446 Sterling B3 5,096 2300 Gas/Water 8.7 0.451 Sterling 134 5,257 2300 , Gas/Water 8.4 0.438 Top Beluga B18 7,280 3300 Gas 8.7 0.453 Beluga B23 7,696 3400 Gas 8.5 0.442 Beluga B24 7,808 3500 Gas 8.6 0.448 Beluga B28B 8,142 3600 Gas 8.5 0.442 Beluga B30 8,265 3600 Gas 8.4 0.436 Tyonek 8,765 3800 Gas 8.3 0.434 Total Depth 10,271 4400 Gas 8.2 0.428 Offset Well Mud Densities Well MW range Top(ND) Bottom(ND) Date Beaver Creek 16 9.2-9.9ppg 5,200 10,900 2014 Beaver Creek 11 8.8-9.6 ppg 400 8,684 2003 Beaver Creek 13 8.5-10.4ppg 0 10,182 2003 Beaver Creek 14A 9.0-9.4ppg 5,000 9,450 2014 f `. Assumptions: - �7 v ii . 1. Maximum planned mud density for the 7-7/8"hole section is 9.5 ppg. • C> 2. Calculations assume reservoirs contain 100%gas(worsttcase). •,'"' �� ,II - 3. Calculations assume worst case event is complete evacuation of wellbore to gas. ✓ / 4. Anticipated fracture gradient at 4706'ND=12.5 ppg EMW Fracture Pressure at 8-1/2"window considering a full column of gas from window to surface: 4706(ft)x 0.65(psi/ft)= 3059 psi 3059(psi)-[0.1(psi/ft)*4706(ft)]= 2588 psi MASP from pore pressure;entire wellbore evacuated to gas from TD 10271(ft)x 0.428(psi/ft)= 4396 psi 4396(psi)-[0.1(psi/ft)*10271(ft)]= 3369 psi ✓ Summary: 1. MASP while drilling 7-7/8"production hole is governed by SIBHP minus entire wellbore evacuated to gas from TD. 2. MASP during production mode is governed by SIBHP minus entire wellbore evacuated to gas from TD. Page 37 Revision 0 May 2, 2014 Bea Drillingver ProcedureCreek12A Rev 0 liilcorp:%IaAa,HA: 28.0 Plot (NAD 27) (Governmental Sections) ECU 03 BHV ECU 18 EHL.# ECU rnU-EHL /:, Legend - BCU 12ASHL / ' BCU 12ATPH ECU 11 BHL t� /r + BCU 12ABHL (:// ' Other Surface Well Locations Other Bottom Hole Locatons---- Well Pathsfm�u Oil and Gas Unit Boundary ECU t$BHt' --- 'CU122HL- (..// `>' ECU 04 8Ht ,r s • .... iBCU 1_'A SHL — " �,'� BCU oo BHL= r-1r13CU 12A BHL� ,� A028083 /r 1 `` LBCU 12A TPH / t SOO7N01OW / i �N, 1 BCU 13 BHb CCS ! / En I @9 ECU 19 EHL( 1 BEAVER CREEK UNIT BCU 0 BHL'J BCU 14ABHL ECU 14 EHI- /I. >/ ECU 16 BHC, / � ,, r i// ` /// `� '`_.Ecui RD EHL ecus1t1. J/� ECU 15 BHLLO,/ SOO6N010W 4 A023118 ECU 02BHL! Page 38 Revision 0 May 2, 2014 B Drillingeaver ProcedureCreek12A Rev 0 Ililcorp AI -ka.IAA; 29.0 Surface Plat (As Built) (NAD 27) / SECTION 25 77N R1q.Y SECTION 33 TIN R cw —1'"--- t4I/435200.OP E:315535.64 i i I i 1 I NOTES 1) BASIS OFGEOUhIFCCO'IROLANL)NADS3 Cjp POSITION iEPOCH 2053)1S AN OPUS 4.-, z SOLUTION FROM NO5 COORDINATES Z? 1=iw STATIO\S RENICONS ARP','TM TALKETNA CORS ARP',A\D'POT3 POTATO I. POINT"I ARP'TO ESTABLISH THE POSITION Cr t-V MCI 9C 1.TI IF GEODETIC POSITION OF BCI CA. WAS DETERMINFO TO+MAVF A LATITUDE.OF u 60'38'5402777'N AND A 1 ONGITUDE OF I 151'02'22 30311W,THE ALASKA STATE PLANE COOkDI )1 ASF';ZONE 3 ARE I N=272212'39;33 X34 E=1463661 065 -} ELEV.131.31 INAV1x96) UI.'. i FAD NJ' i 21 BASIS OP VERTICAL CONTROL IS NOS BMA V50 j PIO TTOSOB LOCATED WITHIN THE KENAI SPUR HIGHWAY RIGHT OF WAY AT MILE POST 3.75 I HAVING AN ELEVATION OF 164.55 FEET NANO I 55 ACCOROI\G TO NGS PiIBLISItED DATA. i 13 COORDINATES CONVERTED TO NAD27 USING "-1i t I { CORPSCON5 CONVFR SIGN SOFTAARF F t / AS-BUILT WELL I SCU 12 i r N:2433191.639' • `�*,,mt1111 t _ E:316325.751' ,c,r 9f AC,1 tit, - LAT:60'39'22.031"N j -4 v1, — LONG -151`01'45.476�M :• 4 *, NORTH ASP ZONE 4NAD27 ; i- »rfJrfaa.., Yom— FNL=2021' ' i i�}Wm A.u�, i - EEL=451' • �'`�` '' ,i-/-.1,-"F"- 1 ; e� ELEV=149.60'(NAVD00) 711'4® ,,. � I , SECTION 33,T7N,R1OW,WA,AK 111tAt�t` I i BCU #12 WELL AS-BUILT SURFACE LOCATION (NAD27) BEAVER CREEK UNIT PAD 4 / Ell ENGINEERING-TESTING LOCATION:SECTION 33, TOWNSHIP 7 NORTH, SURV NGXA PING RANGE 10 WEST,SEWARD MERIDIAN ALASKA I Iilrorp,tlIiII .1.1.1. rF1 SQLOOTNA AK,99669 JOB?30. 143036 'liarOIC,E:001203-4210 FAX.(P37)283-3265 __ .,.. .._. ..... .. . .... . . _ DRAWN BY C.rnsutfig Inc WA'W.MCLANECG.COM BGB DATE:3127114 FIGURE: 1 Page 39 Revision 0 May 2, 2014 B Drillingeaver ProcedureCreek12A Rev 0 IIilcorp Alaska,MA: 30.0 Surface Plat (As Built) (NAD 83) SECTION 78 TN 1kITW oEc?trav 33 T.v tat r;9 11:xaaau�.aT"--_ 1:!1455'596.741! I 1 I 1 i i 1 .,a Ix f i hu Zlz L 9. NOTES m a 1) BASIS OF GEODETIC CONTROL AND NAD83 w!w Posh io (EPOCH 2003115 AN OPUS mita SOI IJTION FROV NOS COORDINATES 1 STATIONS'KEN1 CORS ARP'."Ti KA TALKEETNA CORS ARP'.AND POJ POTATO I POINT 3 ARP'TO ESIABLISH THE P0511 i ON OF cll J MCI BEA.THE GEODE!IG l'051 VON OF 5C1 i WAS DETERMINED TO HAVE A LATITUDE OF OCU j 5"3830.02777'N AND A LONGITUDE OF PAD 140.4 ! ' 151"02'22.31:01M.THE ALASKA STATE PLANE COORDINATES{ASP)ZONE 4 ARE M1=2423933.534 I E=1.953861 Cos { ELEV 111.31'(NAVDE8) i i 2) BASIS OF VERTICAL CCNVTROI IS NCS OM VFw1 2,5 t' 1 PID TT0508 LOCATED'WITHIN THE KENAI SPAR FEL HIGHWAY RIGHT OF'WAY AT 6.411.E POST 175 HAVING AN ELEVATION OF 164.55 FEET NAVD AS-BUILT V./EL I 11 ISA ACCORDING 1O NUS PUBLISHED DAIA ECU 12 1 N:2432952.527' E:1455346.552' i LAT:60"39'19.954'N I Aft{ f ~, 1j 1LONG:-151°01'53.4'94'Yt' --"7.4:-..,91-1C42,,,p � 4 ASP ZONE c NAOB:i I ..ti*4 1 *'• NORTH FEL=2824' I e i FEL=481' l !. .,-y ELEV=149.60•(NAVDSS) i rleo ts1rM P.moon/I:5 "! SECTION 33,T7N.RIOWi,SM,AK 1 ,,�..�d., _ _ i ' 1111.•` .- -E i BCU #12 WELL AS-BUILT SURFACE LOCATION (NADB3) BEAVER CREEK UNIT PAD 4 lit ' G' -"' ENNEERING•TESTING LOCATION:SECTION 33, TOWNSH/P 7 NORTH, SURVEY.N -MAPMAPPING RANGE 10 WEST,SEWARD MERIDIAN ALASKA lliliyap:1lu�1,a.LitSOLC20TWA,AK.MOO JOB NO. 143036 LiI VOICE:(01)7 1 2133-4218 FAX.(537)2f13-3265 DRAWN BY Committing Inc www.McLANLcG.cOM BGB DATE:3127/14 FIGURE: 1 Page 40 Revision 0 May 2, 2014 Hilcorp Energy Company Beaver Creek Unit Beaver Creek Unit Beaver CK Unit 12 Plan: BCU-12A V Plan: BCU-12A WP2.0 Standard Proposal Report 07 May, 2014 HALLIBURTON Sperry Drilling Services HALLIBURTON l Jtl IION lit!AILS Sec MD Inc Azi TVD +N/-S '-W Dleg TFace VSect Target 1 4800.00 18.88 51.83 4706.06 369.09 .96 0.00 0.00 240.64 Sperry Drilling 2 4820.00 20.99 55.18 4724.86 373.13 _5.44 12.00 30.00 243.37 3 4850.00 20.99 55.18 4752.87 379.27 505.27 0.00 0.00 247.94 4 5892.92 18.58 119.47 5744.97 404.45 806.64 2.00 126.24 496.34 5 7138.22 18.58 119.47 6925.34 209.17 1152.15 0.00 0.00 893.20 6 8021.09 0.93 119.47 7792.00 135.86 1281.87 2.00 -180.00 1042.20 BCU-12A Tgt 1 HI lcor�� 7 9992.61 0.93 119.47 9763.26 120.16 1309.64 0.00 0.00 1074.10 BCU-12A BHL Tgt 2 revl 8 10500.00 0.93 119.47 10270.59 116.13 1316.78 0.00 0.00 1082.30 WELL DETAILS: Beaver CK Unit 12 Ground Level: 150.10 +N/-S +E/-W Northing Easting Latittude Longitude Slot 4000- 0.00 0.00 2433191.54 315325.75 60.6561198 -151.0292990 KOP in 9 7/8"Csg;Start Dir 12°/100':4800'MD,4706.06'TVD:30°TF 4400- --- End Dir :4820'MD,4724.86'TVD -'I _---- Start Dir 2°/100':4850'MD,4752.87'TVD 4800- SURVEY PROGRAM B3- Date:2014-05-07100:00:00 Validated:Yes Version: 5200- B4- Depth From Depth To Survey/Plan Tool 166.10 4800.00 BCU 12(BCU 12) MWD -- B18 4800.00 5500.00 BCU-12A WP2.0(Plan:BCU-12A) MWD_Interp Azi+sag 5500.00 10500.00 BCU-12A WP2.0(Plan:BCU-12A) MWD+SC+sag 5600- End Dir :5892.92'MD,5744.97'TVD 6000- REFERENCE INFORMATION Co-ordinate(N/E)Reference: Well Beaver CK Unit 12,True North Vertical(TVD)Reference: BCU-12A Plan @ 168.10usft 6400- Measured Depth Reference: BCU-12A Plan @ 168.10usft Calculation Method: Minimum Curvature 6800- Start Dir 2°/100':7138.22'MD,6925.34'TVD co 95/8"___ o - °D 7200- CASING DETAILS B23 TVD MD Name Size N 10270.59 10500.00 5 1/2" 5-1/2 xt 7600- B24. BCU-12A Tgt 1 6288- End Dir :8021.09'MD,7792'TVD 2 8000- F- B30- Project: Beaver Creek Unit 8400- Site: Beaver Creek Unit Tyonek Well: Beaver CK Unit 12 3 1/2" L Wellbore: Plan: BCU-12A BCU 12 8800- BCU-12A WP2.0 Hilcorp Energy Company Calculation Method: Minimum Curvature 9200- Error System:ISCWSA Scan Method: Closest Approach 3D Error Surface: Elliptical Conic Warning Method: Error Ratio 9600- BCU-12A BHL Tgt 2 rev1 10000- 51/2"--- --------- 10400- Total Depth: 10500'MD, 10270.59'TVD BCU-12A WP2.0 10800 I I I I I I I I I I I I I I I -800 -400 0 400 800 1200 1600 2000 2400 2800 3200 Vertical Section at 120.00°(800 usft/in) 0 p g o —0 N 0 . 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W 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 I I I I I I I v Q U U o'CO 0CO 0V 0 0 0 0N o 0 00 0 0 I DD. (ui/gsn OOT)(+)quoN/(-)ginoS - o —o a>i O - '" p s., N N"' N N NH n Q --o (/J n U I Nr cn E m d H U - Z co N - o Oa 4--, ' '\ O\ , 'n o Vn U _ ` H P - \\ N - CO \ N ' - J • \ - O D CQ O - O O 0 - Z Q U N. _o 1A e� 0 o 0 0 H —o,, r I N co ^ O _ Lo `° 1 _ .. O \ H N M —o N 0, W o 0 iV N 00 _ M r O ,I+\ —$ I \ O - I Q \ fi _ Sy o • I Q rn t I I \ N cdd - O I \ O 1 I V 5 i \\ Iv-) —O .+i 1 . a R Ig <V N O U N o ,- al 00 a M 5/1 .. 5. - ~/ O 0 m W r IHI - o s o 0 O O = O 0 . Q� N -,c), 00 000 / � // _- 0 / Q / \p }, •ti Q / W L o / —vii C G cQ\5 / / Y Y C r g L 0 0�,, CO I / n - [—a UUUmo / �D —oo ca U - 1'0 R 1'o a Co 3 al 0:1 CO cs4 0 0 0 Q - C 0�_ L.0 =o y m U c> :� 'oyk Cm Pr _:!. 0 - - I I I I 1 1 1 1 I I I L I I I I L. i L�` o 0 0 0o o O O O O oo 0 0o 0 0 ill 4J N V OV cOM N N .�-� I tO (uyijsn OOT)(+)LIuoN/(-)4;nos Halliburton HALLI B U RTO N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 12 Company: Hilcorp Energy Company TVD Reference: BCU-12A Plan @ 168.10usft Project: Beaver Creek Unit MD Reference: BCU-12A Plan @ 168.10usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 12 Survey Calculation Method: Minimum Curvature ' Wellbore: Plan:BCU-12A Design: BCU-12A WP2.0 Project Beaver 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 Site Beaver Creek Unit Site Position: Northing: 2,430,086.36 usft Latitude: 60.6475877 From: Map Easting: 314,428.19 usft Longitude: -151.0340284 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.90° Well Beaver CK Unit 12 Well Position +N/-S 0.00 usft Northing: 2,433,191.54 usft ' Latitude: 60.6561198 +E/-W 0.00 usft Easting: 315,325.75 usft , Longitude: -151.0292990 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: `150.10 usft Wellbore Plan:BCU-12A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2013 6/30/2014 16.97 73.63 55,463 Design BCU-12A WP2.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 4,800.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 120.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +EI-W Rate Rate Rate Tool Face (usft) (0) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°1100usft) (°) 4,800.00 18.88 51.83 4,706.06 4,537.96 369.09 490.96 0.00 0.00 0.00 0.00 4,820.00 20.99 55.18 4,724.86 4,556.76 373.13 496.44 12.00 10.56 16.75 30.00 4,850.00 20.99 55.18 4,752.87 4,584.77 379.27 505.27 0.00 0.00 0.00 0.00 5,892.92 18.58 119.47 5,744.97 5,576.87 404.45 806.64 2.00 -0.23 6.17 126.24 7,138.22 18.58 119.47 6,925.34 6,757.24 209.17 1,152.15 0.00 0.00 0.00 0.00 8,021.09 0.93 119.47 7,792.00 7,623.90 135.86 1,281.87 2.00 -2.00 0.00 -180.00 9,992.61 0.93 119.47 9,763.26 9,595.16 120.16 1,309.64 0.00 0.00 0.00 0.00 10,500.00 0.93 119.47 10,270.59 10,102.49 116.13 1,316.78 0.00 0.00 0.00 0.00 5/7/2014 12:57:45PM Page 2 COMPASS 5000.1 Build 70 Halliburton HALLI BURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 12 Company: Hilcorp Energy Company TVD Reference: BCU-12A Plan @ 168.10usft Project: Beaver Creek Unit MD Reference: BCU-12A Plan @ 168.10usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 12 Survey Calculation Method: Minimum Curvature Wellbore: Plan:BCU-12A Design: BCU-12A WP2.0 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) 4,537.96 . 4,800.00 18.88 51.83 4,706.06 4,537.96 369.09 490.96 2,433,552.89 315,822.43 0.00 240.64 4,800.01 18.88 51.83 4,706.07 4,537.97 369.09 490.96 2,433,552.89 315,822.43 0.00 240.64 KOP in 9 7/8"Csg;Start Dir 12°/100':4800'MD,4706.06'TVD:30°TF 4,820.00 20.99 55.18 4,724.86 4,556.76 373.13 496.44 2,433,556.85 315,827.98 12.01 243.37 End Dir :4820'MD,4724.86'ND 1 4,850.00 20.99 55.18 4,752.87 4,584.77 379.27 505.27 2,433,562.85 315,836.90 0.00 247.94 Start Dir 2°/100':4850'MD,4752.87'TVD 4,900.00 20.42 57.49 4,799.64 4,631.54 389.07 519.97 2,433,572.42 315,851.75 2.00 255.78 5,000.00 19.36 62.49 4,893.68 4,725.58 406.10 549.39 2,433,588.99 315,881.43 2.00 272.73 5,041.73 18.97 64.73 4,933.10 4,765.00 412.19 561.66 2,433,594.89 315,893.80 2.00 280.31 B3 5,100.00 18.46 68.00 4,988.29 4,820.19 419.69 578.78 2,433,602.12 315,911.03 2.00 291.39 5,200.00 17.73 74.00 5,083.35 4,915.25 429.82 608.10 2,433,611.78 315,940.51 2.00 311.72 5,212.33 17.66 74.77 5,095.10 4,927.00 430.83 611.71 2,433,612.74 315,944.13 2.00 314.34 B4 5,300.00 17.20 80.43 5,178.75 5,010.65 436.48 637.32 2,433,617.98 315,969.83 2.00 333.70 5,380.91 16.93 85.87 5,256.10 5,088.00 439.31 660.87 2,433,620.45 315,993.42 2.00 352.67 B18 5,400.00 16.88 87.17 5,274.37 5,106.27 439.65 666.41 2,433,620.70 315,998.97 2.00 357.30 5,500.00 16.79 94.07 5,370.09 5,201.99 439.34 695.33 2,433,619.94 316,027.88 2.00 382.50 5,600.00 16.94 100.95 5,465.80 5,297.70 435.55 724.04 2,433,615.70 316,056.53 2.00 409.27 5,700.00 17.30 107.64 5,561.38 5,393.28 428.28 752.52 2,433,607.98 316,084.88 2.00 437.56 5,800.00 17.88 113.98 5,656.71 5,488.61 417.53 780.71 2,433,596.79 316,112.91 2.00 467.35 5,892.92 18.58 119.47 5,744.97 5,576.87 404.45 806.64 2,433,583.31 316,138.62 2.00 496.34 End Dir :5892.92'MD,5744.97'TVD 5,900.00 18.58 119.47 5,751.68 5,583.58 403.34 808.60 2,433,582.17 316,140.57 0.00 498.60 6,000.00 18.58 119.47 5,846.47 5,678.37 387.66 836.35 2,433,566.05 316,168.07 0.00 530.47 6,100.00 18.58 119.47 5,941.25 5,773.15 371.98 864.09 2,433,549.94 316,195.56 0.00 562.34 6,200.00 18.58 119.47 6,036.04 5,867.94 356.30 891.84 2,433,533.83 316,223.06 0.00 594.20 6,300.00 18.58 119.47 6,130.82 5,962.72 340.62 919.58 2,433,517.71 316,250.55 0.00 626.07 6,400.00 18.58 119.47 6,225.61 6,057.51 324.93 947.33 2,433,501.60 316,278.05 0.00 657.94 6,500.00 18.58 119.47 6,320.40 6,152.30 309.25 975.07 2,433,485.48 316,305.55 0.00 689.81 6,600.00 18.58 119.47 6,415.18 6,247.08 293.57 1,002.82 2,433,469.37 316,333.04 0.00 721.68 6,700.00 18.58 119.47 6,509.97 6,341.87 277.89 1,030.56 2,433,453.26 316,360.54 0.00 753.55 6,800.00 18.58 119.47 6,604.75 6,436.65 262.21 1,058.31 2,433,437.14 316,388.04 0.00 785.42 6,900.00 18.58 119.47 6,699.54 6,531.44 246.53 1,086.05 2,433,421.03 316,415.53 0.00 817.28 7,000.00 18.58 119.47 6,794.32 6,626.22 230.85 1,113.80 2,433,404.92 316,443.03 0.00 849.15 7,100.00 18.58 119.47 6,889.11 6,721.01 215.17 1,141.54 2,433,388.80 316,470.52 0.00 881.02 7,138.22 18.58 119.47 6,925.34 6,757.24 209.17 1,152.15 2,433,382.64 316,481.03 0.00 893.20 Start Dir 2°/100':7138.22'MD,6925.34'TVD 7,200.00 17.35 119.47 6,984.10 6,816.00 199.80 1,168.74 2,433,373.01 316,497.47 2.00 912.26 7,300.00 15.35 119.47 7,080.05 6,911.95 185.95 1,193.24 2,433,358.78 316,521.76 2.00 940.40 7,400.00 13.35 119.47 7,176.93 7,008.83 173.75 1,214.82 2,433,346.25 316,543.14 2.00 965.18 7,500.00 11.35 119.47 7,274.61 7,106.51 163.23 1,233.43 2,433,335.44 316,561.59 2.00 986.57 5/7/2014 12:57:45PM Page 3 COMPASS 5000.1 Build 70 Halliburton I-IALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 12 Company: Hilcorp Energy Company TVD Reference: BCU-12A Plan @ 168.10usft Project: Beaver Creek Unit MD Reference: BCU-12A Plan @ 168.10usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 12 Survey Calculation Method: Minimum Curvature Wellbore: Plan:BCU-12A Design: BCU-12A WP2.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +El-W Northing Easting DLS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) 7,111.00 7,504.58 11.26 119.47 7,279.10 7,111.00 162.79 1,234.21 2,433,334.98 316,562.36 2.00 987.46 B23 7,600.00 9.35 119.47 7,372.98 7,204.88 154.39 1,249.07 2,433,326.35 316,577.09 2.00 1,004.53 7,700.00 7.35 119.47 7,471.91 7,303.81 147.25 1,261.71 2,433,319.01 316,589.61 2.00 1,019.05 7,800.00 5.35 119.47 7,571.30 7,403.20 141.81 1,271.34 2,433,313.42 316,599.15 2.00 1,030.11 7,900.00 3.35 119.47 7,671.00 7,502.90 138.08 1,277.94 2,433,309.59 316,605.69 2.00 1,037.69 7,924.13 2.87 119.47 7,695.10 7,527.00 137.44 1,279.08 2,433,308.93 316,606.82 2.00 1,039.00 824 8,000.00 1.35 119.47 7,770.91 7,602.81 136.06 1,281.51 2,433,307.52 316,609.23 2.00 1,041.78 8,021.09 0.93 119.47 7,792.00 7,623.90 135.86 1,281.87 2,433,307.31 316,609.59 2.00 1,042.20 End Dir :8021.09'MD,7792'ND-BCU-12A Tgt 1 8,036.19 0.93 119.47 7,807.10 7,639.00 135.74 1,282.08 2,433,307.18 316,609.80 0.00 1,042.45 B28B 8,100.00 0.93 119.47 7,870.90 7,702.80 135.23 1,282.98 2,433,306.66 316,610.69 0.00 1,043.48 8,200.00 0.93 119.47 7,970.89 7,802.79 134.43 1,284.39 2,433,305.84 316,612.09 0.00 1,045.10 8,300.00 0.93 119.47 8,070.87 7,902.77 133.64 1,285.80 2,433,305.02 316,613.48 0.00 1,046.72 8,370.24 0.93 119.47 8,141.10 7,973.00 133.08 1,286.79 2,433,304.45 316,614.46 0.00 1,047.85 B30 8,400.00 0.93 119.47 8,170.86 8,002.76 132.84 1,287.21 2,433,304.21 316,614.88 0.00 1,048.33 8,493.25 0.93 119.47 8,264.10 8,096.00 132.10 1,288.52 2,433,303.44 316,616.18 0.00 1,049.84 Tyonek 8,500.00 0.93 119.47 8,270.85 8,102.75 132.05 1,288.62 2,433,303.39 316,616.28 0.00 1,049.95 8,600.00 0.93 119.47 8,370.83 8,202.73 131.25 1,290.02 2,433,302.57 316,617.67 0.00 1,051.57 8,700.00 0.93 119.47 8,470.82 8,302.72 130.45 1,291.43 2,433,301.75 316,619.07 0.00 1,053.19 8,800.00 0.93 119.47 8,570.81 8,402.71 129.66 1,292.84 2,433,300.93 316,620.46 0.00 1,054.80 8,900.00 0.93 119.47 8,670.79 8,502.69 128.86 1,294.25 2,433,300.12 316,621.86 0.00 1,056.42 9,000.00 0.93 119.47 8,770.78 8,602.68 128.07 1,295.66 2,433,299.30 316,623.25 0.00 1,058.04 9,025.90 0.93 119.47 8,796.68 8,628.58 127.86 1,296.02 2,433,299.09 316,623.62 0.00 1,058.46 BCU-12A BHL Tgt 9,100.00 0.93 119.47 8,870.77 8,702.67 127.27 1,297.07 2,433,298.48 316,624.65 0.00 1,059.66 9,200.00 0.93 119.47 8,970.76 8,802.66 126.47 1,298.47 2,433,297.66 316,626.05 0.00 1,061.27 9,300.00 0.93 119.47 9,070.74 8,902.64 125.68 1,299.88 2,433,296.84 316,627.44 0.00 1,062.89 9,400.00 0.93 119.47 9,170.73 9,002.63 124.88 1,301.29 2,433,296.03 316,628.84 0.00 1,064.51 9,500.00 0.93 119.47 9,270.72 9,102.62 124.09 1,302.70 2,433,295.21 316,630.23 0.00 1,066.13 9,600.00 0.93 119.47 9,370.70 9,202.60 123.29 1,304.11 2,433,294.39 316,631.63 0.00 1,067.75 9,700.00 0.93 119.47 9,470.69 9,302.59 122.49 1,305.52 2,433,293.57 316,633.02 0.00 1,069.36 9,800.00 0.93 119.47 9,570.68 9,402.58 121.70 1,306.92 2,433,292.76 316,634.42 0.00 1,070.98 9,900.00 0.93 119.47 9,670.66 9,502.56 120.90 1,308.33 2,433,291.94 316,635.82 0.00 1,072.60 9,992.61 0.93 119.47 9,763.26 9,595.16 120.16 1,309.64 2,433,291.18 316,637.11 0.00 1,074.10 BCU-12A BHL Tgt 2 revl 10,000.00 0.93 119.47 9,770.65 9,602.55 120.11 1,309.74 2,433,291.12 316,637.21 0.00 1,074.22 10,100.00 0.93 119.47 9,870.64 9,702.54 119.31 1,311.15 2,433,290.30 316,638.61 0.00 1,075.83 10,200.00 0.93 119.47 9,970.62 9,802.52 118.51 1,312.56 2,433,289.48 316,640.00 0.00 1,077.45 10,300.00 0.93 119.47 10,070.61 9,902.51 117.72 1,313.97 2,433,288.67 316,641.40 0.00 1,079.07 10,400.00 0.93 119.47 10,170.60 10,002.50 116.92 1,315.37 2,433,287.85 316,642.79 0.00 1,080.69 5/7/2014 12:57:45PM Page 4 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 12 Company: Hilcorp Energy Company TVD Reference: BCU-12A Plan @ 168.10usft Project: Beaver Creek Unit MD Reference: BCU-12A Plan @ 168.10usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 12 Survey Calculation Method: Minimum Curvature Wellbore: Plan:BCU-12A Design: BCU-12A WP2.0 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) 10,102.48 10,499.99 0.93 119.47 10,270.58 10,102.48 116.13 1,316.78 2,433,287.03 316,644.19 0.00 1,082.30 Total Depth:10500'MD,10270.59'TVD . 10,500.00 0.93 119.47 10,270.59 10,102.49 116.13 1,316.78 2,433,287.03 316,644.19 0.00 1,082.30 5 1/2" Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) BCU-12ABHLTgt2rev1 0.00 0.00 9,763.26 120.16 1,309.64 2,433,291.18 316,637.11 -plan hits target center -Point BCU-12ATgt 1 0.00 0.00 7,792.00 135.86 1,281.87 2,433,307.31 316,609.59 -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') (1 10,500.00 10,270.59 5 1/2" 5-1/2 7-7/8 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (1 (`) 5,212.33 5,095.10 B4 8,036.19 7,807.10 B28B 4,798.99 4,705.10 B1 5,380.91 5,256.10 B18 7,504.58 7,279.10 B23 5,041.73 4,933.10 B3 7,924.13 7,695.10 B24 8,370.24 8,141.10 B30 8,493.25 8,264.10 Tyonek 5/7/2014 12:57:45PM Page 5 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 12 Company: Hilcorp Energy Company TVD Reference: BCU-12A Plan @ 168.10usft Project: Beaver Creek Unit MD Reference: BCU-12A Plan @ 168.10usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 12 Survey Calculation Method: Minimum Curvature Wellbore: Plan:BCU-12A Design: BCU-12A WP2.0 Plan Annotations Measured Vertical Local Coordinates Depth Depth +Nl-S +EI-W (usft) (usft) (usft) (usft) Comment 4,800.01 4,706.07 369.09 490.96 KOP in 9 7/8"Csg;Start Dir 12°/100':4800'MD,4706.06'TVD:30°TF 4,820.00 4,724.86 373.13 496.44 End Dir :4820'MD,4724.86'TVD 4,850.00 4,752.87 379.27 505.27 Start Dir 2°/100':4850'MD,4752.87'TVD 5,892.92 5,744.97 404.45 806.64 End Dir :5892.92'MD,5744.97'TVD 7,138.22 6,925.34 209.17 1,152.15 Start Dir2°/100':7138.22'MD,6925.34'TVD 8,021.09 7,792.00 135.86 1,281.87 End Dir :8021.09'MD,7792'TVD 10,499.99 10,270.58 116.13 1,316.78 Total Depth:10500'MD,10270.59'TVD 5/7/2014 12:57:45PM Page 6 COMPASS 5000.1 Build 70 2 N m 0 H CD Et in 3 ... L J o a ` Ia CO t 111) I ■M N a L to O O `11 2• m N a o C m r2 g W o X d ,_ m o CU v_ g o y U of En L m , a + = C Z }� O E C �_ N d O cV y • N N y 3 V ^ d .0 , C. 7 p p D t W y Y `oL. aTD II m U }}�� • ' 10 co V Q D) U m ui m u. 0 L CI = c 0 m M G V, V W G) en N C Mco. v p W O ° o m Q m Y 2 O W• c c T Q W E U m 0 F Q C N a ge o m i a L W, LY = T co 0 0md dr O N a OO N = • O d' "4. 'ac'' m = mU � O UUUUMQ C .�' t . a- N o y m .. yo • L LW L cc' M NNT /t .. a) yr■ a 'c Lf Gi y o 1c. odrn .- N GFai ii > > > , 1 CO NCOx C >. T 11111111111 URR ma ow = ,, „ � u .T a) m a m CO U a 3i O CO a. Q m Z U 0 U as w o G• Cl) m W P4 a) a m Q N N N N N N N N N N N IC N U0 co N Cl) Cl) Cl) Cl) Cl) co (Cl Cl) Cl) N :� a CO 0II Cl)00 Cl). Cl). 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I I I [ I I I I I I I III till I I I ] I I I ' I I I 11 1 ^O J .O CD V O r a Lo N O r N N a Q (, C O li c; I: c0 N cM (Ni .- O _ R (u!/o5'Z)Joioe j uo!TeJedag d U < 7L Qe)/(22 Ojd e :t,N i ,( Well Prognosis - ( ) LPWell: BCU-12 llilcorp Ala,ka,LI) Date:5/01/2014 Well Name: BCU-12 API Number: 50-133-20530-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: May 15th, 2014 Rig: Moncla 405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 203-188 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907)331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,245 psi @ 7,701'TVD (Static survey June 2005 below bottom zone 7,884' MD) Maximum Expected BHP: — 1,245 psi @ 7,701'TVD (Static survey June 2005 below bottom zone 7,884' MD) Max.Allowable Surface Pressure: 475 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary •2��� Beaver Creek Unit#12 was drilled as a Grass roots EXCAPE monobore completion in 2004 to target gas sands in the lower Beluga formation.All 12 EXCAPE modules were perforated and fracture stimulated.A capillary string was installed to deliver foamer to alleviate liquid loading in 2009.The capillary string was pulled in Sep 2010 but a fish was left in the well.The capillary string was re-ran to a shallower depth in Oct 2010.The capillary string was pulled in Feb 2014 and soap sticks have been dropped in place of the foamer. The purpose of this work/sundry is to abandon the current perforated interval and prepare the wellbore for re- • drilling operations.A drilling permit application will be submitted separately for the sidetrack. 1 cor. ?4' wt// ccf jcs., j'n t?i4. Notes Regarding Wellbore Condition ele416.L ;14-5 elf 7;:,t itestt/y 1° jt 'j e" Mee_ Q,tq' 4, q t ajf //volt/erg .forme W. •4 • Last tag at 8,287'SLM on 2/18/14 w/a 2.50" Overshot. T4 real,sf,� 5,41 r l G PI g, firm,o y 4e. well ,Y fro to t fc Slickline Procedure: 6k pF ��feadi j (•Bless 1-124lead. 1. MIRU Slickline, PT Lubricator to 3,000 psi Hi 250 Low. I'1,,1'j r4f wt a4. /f 2. RU 2.70"gauge ring, RIH and tag fill/obstruction at+/-8,287'. 400 i✓ 10s iesfipv K. 1'(o'' 3. RU tubing stop/plug for 3-1/2"tubing, RIH and set at+/-7,210'. Bleed off tubing pressure. 444 At, 4. Dump bail 35'of cement on tubing plug(13 gallons of cement). 5. Wait on cement for 12 hours. rag 6. RU 2.50" bailer and tag top of cement. SDa 5c, *37 7. RD Slickline. -65 30 WO Rig Procedure: 8. MIRU Moncla#405 WO Rig. 9. Set BPV. ND Tree. 10. NU BOPE.Set BPV.Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/1,500 psi High(hold each valve and test for 10-min). Record ac simulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Notify BLM 48 hrs in advance of BOP test. Well Prognosis Well: BCU-12 Ilileorp Alaska,LL Date:5/01/2014 11. Bleed any pressure off tubing. Pull BPV. 12. MU landing joint and pull 10-15k tension over string weight on tubing hanger. 13. MIRU E-line. a. MU pump-in sub on 3-1/2"8RD landing joint. 14. RU 1-11/16" 6'tubing punch. 15. RIH and punch tubing at+/-5,510'-5,516' MD. POOH. 16. RU to reverse circulate out the drilling mud in the 3-1/2"x9-5/8"annulus with lease water. a. Mud weight is 9.4 ppg.Spacer is 10.0 ppg(50 bbl). b. Estimated volume is 327 bbl. 17. RU 3.5"Tubing Jet Cutter. 18. RIH and jet cut tubing at+/-5,500'MD. a. Have backup cutters on location if tubing does not part. b. Plan 2"d jet cut if control lines do not part. c. Make cut above Cement top at 6,400'. 19. RD Eline. 20. SOOH and rack back 3-1/2"tubing. a. Tubing has rigid centralizers, 1 per joint. Utilize open-faced tubing tongs. b. Rigid centralizers secured with hex-screws. Do not drop on top of annular. c. No plans to re-use the 3 recovered control lines.Secured to tubing with bands. d. Expect to find a 1/2" braided line cable on the outside of the tubing. 21. MU flat-bottom BHA w/casing scraper and RIH on 3-1/2"tubing out of derrick. 22. Tag cut tubing at+/-5,500' MD. 23. Circulate well clean w/Produced Lease Water. 24. POOH. LD 3-1/2"tubing,casing scraper and flat-bottom BHA. 25. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. 26. RU 9-5 8" P and GR/CCL tools. 27. RIH and set CIBP at+/-4,800' MD in the 9-5/8"40#casing(set 3-5 ft above a casing collar). 28. RD E-line. 29. Test casing to 2,000 psi for 30 min and chart. 30. Set BPV. ND BOPE. NU dry hole tree. Pull BPV. 31. RD Moncla#405 WO Rig. 32. Turn well over to production in preparation of moving in the Saxon#169 Drilling Rig. 33. Replace IA x OA pressure gauge if removed(9-5/8"x 13-3/8"). Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic n . BC-12 ACTUAL Pad4 SCHEMATIC 2,023' FNL,482' FEL, ttilcorp Alaska,LLC Sec. 33, T7N, R10W, S.M. Permit#: 203-188 Conductor20" K-55 133 ppf API#: 50-133-20530-00-CO Top Bottom Property Des: A-028083 MD 0' 107' KB: 21'AGL (171'KB Elevation) TVD 0' 107' Lat: 60 39' 22.118" N Long: 151' 01' 45.593" W FL' Surface Casinq Spud: 5/27/2004 13-3/8" K-55 68 ppf BTC TD Reached: 6/10/2004 r� Bottom Rig Released: 00:00 his 06/15/04 ,��Li MD o z,09 ' ND 0' 2,091' '(+3�,,,.� 16"hole Cmtw/600 sks(271 bbl)of 12.0 ppg, N Type 1 cmt, 18 sks(8 bbls)to surface Intermediate Casinq 9-5/8" L-80 40 ppf BTC ' Top Bottom MD 0' 7,160' Treo exn=6-112"OtisTVD 0' 6,978' i" yj 12-114"hole Lead Cmt w/833 sks(341 bbls)of 3 12.5 ppg,Class G, Tail Cmt w/327 sks(106 bbls) Top of 6, Cement of 13.5 ppg,Class G, 12 sks(5 bbls)to surface 4r Y:', Production Casinq Excape System Details 0 % 3-1/2" L-80 9.3 ppf EUE -BHP monitoring Green line volume ' Top Bottom and tank located from 7,149'-7,185'RKB li MD 0' 8,773' 4 TVD 0' 8,690' 44 - 44 8-112"hole Cmt w/786sks(1891 bbls)of `) 15.8 ppg,Class G Excape System Details t` t -11 Conventional flappers . , j Capillary Tubing (-*"Pulled 2/14/14"1 -Mod 1 -no flapper 3/8"OD 2205 0.049" -Ceramic flapper valves below r el Stainless Steel Wall Thickness each module as follows: Flappers MD(RKB): s Module 12-7,247 )e Module 11 -7,297' ` Module 10-7,499' System Details Module 9-7,562' -12 Excape module system Module 8-7,603' lM - control line fires modules 5-12 Module 7-7,675' i' ,/ - control line fires modules 2-4 Module 6-7,750' '' -Green control line fires module 1 Module 5-7,799' t -Ceramic flapper valves below each module Module 4-7,867' ,., . (excluding module 1) Module 3-7,908' Module 2-8,439' 4,1 ( ; Perfs(Open Hole Loci)_ Module 1 - NA '�4 MD TVD Date ...1; ( Module 12- 7,2216-7,238' 7,046-7,056' (8/12/04) Module 11 - 7,279'-7,289' 7,096-7,107' (8/12/04) I '' Module 10- 7,480'-7,490' 7,297'-7,307' (8/12/04) 4.1 Module 9- 7,543'-7,553' 7,360'-7,370' (8/11/04) ' Module 8- 7,584'-7,594' 7,401'-7,411' (8/11/04) Tag fish @ 8,287 (2/18114) Module 7- 7,656-7,666' 7,473'-7,483' (8/11/04) w/2.50"overshot l y Module 6- 7,731'-7,741' 7,548'-7,558' (8/11/04) r' Module 5- 7,780'-7,790' 7,597'-7,607' (8/11/04) r. Module 4- 7,846-7,858' 7,666-7,675' (8/11/04) Module 3- 7,889'-7,899' 7,707'-7,716' (8/11/04) Fish:@ 8,287'(Lost 8/30/10) a4 Module 2- 8,420'-8,430' 8,237'-8,247' (8/11/04) 3/4"OD X 18"cap string BHA Module 1 - 8,471-8,481' 8,288'-8,299' (8/11/04) Possibly 3-4'of 3/8"cap string TD PBTD 8,839' MD 8,736 MD 8,656'TVD 8,553'TVD Well Name&Number: Beaver Creek Unit#12 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country. USA KOP and Max Dogleg: KOP @ 2,500'/3.98° 3,439' Angle/Perfs: 1.0°42.0° Maximum Deviation: 20°e4,196' Date Completed: 08/11/04 Ground Level(above MSL): 150' RKB(above GL): 21' Revised By: Stan Porhola Downhole Revision Date: 2/18/2014 Schematic Revision Date: 2/20/2014 B�_� 2 PROPOSED • Pad 4 SCHEMATIC 2,023'FNL,482' FEL, IIilcorp Alaska.,LLC Sec. 33,T7N,R1 OW, S.M. Permit#: 203-188 Conductor20" K-55 133 ppf API#: 50-133-20530-00-GO Top Bottom Property Des: A-028083 MD 0' 107' KB: 21'AGL (171'KB Elevation) TVD 0' 107' Lat: 60° 39' 22.118" N " Long:, 151' 01' 45.593" WSurface Casing 13-3/8" K-55 68 ppf BTC Spud: 5/27/2004 .1:)p Bottom TD Reached: 6/10/2004 MD 0' 2,091' Rig Released: 00:00 hrs 06/15/C, , TVD 0' 2,091' '' 16"hole Cmtwl 600 sks(271 bbl)of 12.0 ppg, it_ Type 1 cmt, 18 sks(8 bbls)to surface Intermediate Casing Tree cxn=6-1/2"Otis 9-518" L-80 40 ppf BTC •,r Top Bottom MD 0' 7,160' Plug @ 4,800' _ 78' - 12-1//4"hole Lead Cmtw/ sks(341 bbls)of Jet Cut Tubing @ 5,500' 4 r 12.5 ppg,Class G, Tail Cmt w/327 sks(106 bbls) of 13.5 ppg,Class G, 12 sks(5 bbls)to surface Tubing Punch @ 5,510' •.i ViCit&A, 70 ,,,, 1 1- Production Casing Top of Cement 1. kl 3-112" L-80 9.3 ppf EUE @6,400'MD Twp Bottom 8rd i.A , MD 0' 8,773' TVD 0' 8,590' TubingPlug @7,210' - 8-112" hole Cmt w1 786sks(1891bbls)of Capped WI 35'Cement t ) 15.8 ppg,Class G r Z,5 W rsy Capillary Tubing ("'Pulled 2/14114"') i . 3/8"OD 2206 0.049" `r Stainless Steel Wall Thickness 11 Excape System Details s t -BHP monitoring Green line volume tank located from 7,149'-7,185'RKB - Ll- 44 System Details Excape System Details 12 Excape module system YrN 11 Conventional flappers - control line fires modules 5-12 -Mod 1 -no flapper , ' - control line fires modules 2-4 Ceramic flapper valves below ` Green control line fires module 1 each module as follows: -Ceramic flapper valves below each module i , , (excluding module 1) Flappers MD(RKB): ' Module 12-7,247 Perfs(Open Hole Lod): Module 11 -7,297' - MD ND Date Module 10-7,499' -.i Module 12- 7,225-7,238' 7,046'-7,056' (8/12104) Module 9-7,562' Module 11 - 7,279'-7,289' 7,095-7,107' (8/12/04) Module 8-7,603' 1 I Module 10- 7,480'-7,490' 7,297'-7,307' (8/12/04) Module 7-7,675' Module 9- 7,543'-7,553' 7,360'-7,370' (8/11/04) Module 6-7,750' Module 8- 7,584'-7,594' 7,401'-7,411' (8/11/04) Module 5-7,799' Module 7- 7,655-7,666' 7,473'-7,483' (8/11/04) Module 4-7,867' Module 6- 7,731'-7,741' 7,548'-7,558' (8/11/04) Module 3-7,908' ' Module 5- 7,780'-7,790' 7,597'-7,607' (8/11/04) Module 2-8,439' Module 1 - NA Module 4- 7,845-7,858' 7,665-7,675' (8/11/04) Module 3- 7,889'-7,899' 7,707'-7,716' (8/11/04) ' Module 2- 8,420'-8,430' 8,237'-8,247' (8/11/04) Tag fish @ 8,287' (2/18114) Module 1 - 8,471'-8,481' 8,285-8,299' (8/11/04) wl 2.50"overshot TD PBTD Fish:@ 8,287'(Lost 8/30/10) 8,839'MD 8,736 MD 3/4"OD X 18"cap string BHA 8,656'TVD 8,553'TVD Possibly 3-4'of 3/8"cap string Well Name&Number: Beaver Creek Unit#12 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA KOP and Max Dogleg: KOP @ 2,500'/3.98° 3,439' Angle/Perfs:I 1.0°-32.0° Maximum Deviation: 20°l 4,196' Date Completed: 08/11/04 Ground Level(above MSL): 150' RKB(above GL): 21' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 512/2014 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, May 21, 2014 2:01 PM 5.. tci �. To: 'Monty Myers'; Kevin Eastham ,�/� Cc: David Duffy /': e-x.c Subject: RE: Beaver Creek Unit 12A digital surveys �M.k� �f � ,,r3/47-(a/ / y s '-I— ,'( `!� Monty, Kevin, David: •,�n I plotted the Beluga perforations shown on the BCU 9 schematic diagram in my workstation, and they appear to lie closer than 1320'to the Beluga interval anticipated in BCU 12A. Is this correct? If so, why wouldn't an exception to spacing requirements be needed for BCU 12A? Thanks, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies(a)alaska.gov. From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Saturday, May 17, 2014 6:56 AM To: Davies, Stephen F (DOA); Kevin Eastham Cc: David Duffy Subject: RE: Beaver Creek Unit 12A digital surveys Good morning Steve! Here is the most current schematic for BCU 9 that I could find. Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Friday, May 16, 2014 6:08 PM To: Kevin Eastham; Monty Myers Cc: David Duffy Subject: RE: Beaver Creek Unit 12A digital surveys Kevin, Monty: 1 According to AOGCC's well history file for BCU 9 (Permit 192-122), perforations in the Beluga still appear to be open. Could Hilcorp please provide a current wellbore schematic diagram for BCU 9? Are any perforations in BCU 9 open to the Beluga? If so,what is the distance from those open perforations to the planned perforations in BCU 12A? Thanks, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.daviesc alaska.gov. From: David Duffy [mailto:dduffy@hilcorp.com] Sent: Friday, May 16, 2014 2:11 PM To: Davies, Stephen F (DOA) Cc: Monty Myers; Kevin Eastham Subject: RE: Beaver Creek Unit 12A digital surveys Steve, The attached plat demonstrates why no spacing exception is required for Beaver Creek 12A. The nearest well open in the Beluga Gas Pool is 1547' away. Current pool rules require spacing of at least 1320'. The distance to the nearest property where ownership is different (unit boundary) is 4484'. If you have any additional questions, please contact either Kevin Eastam (907-777-8316) or me. Thanks, David Duffy, Landman Hilcorp Alaska, LLC Direct: 907-777-8414 Cell: 907-301-2629 dduffy@hilcorp.com This email may contain confidential and / or privileged information and is intended for the recipient(s)only. In the event you receive this message in error, please notify me and delete the message. From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Friday, May 16, 2014 12:57 PM To: Monty Myers; David Duffy Subject: RE: Beaver Creek Unit 12A digital surveys Monty, Thank you for the survey data spreadsheet. I appreciate your help. Could Hilcorp please provide justification as to why a spacing exception is not required for the BCU 12A redrill? Thanks, Steve D. 2 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Thursday, May 15, 2014 3:18 PM To: Davies, Stephen F (DOA); Schwartz, Guy L (DOA) Subject: Beaver Creek Unit 12A digital surveys Good afternoon gents! The Beaver Creek Unit 12A permit was submitted yesterday for your review. Attached are the digital surveys for you to use in your files. If you need anything else for the permit, please do not hesitate to ask. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 3 U a a J.1 b . 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TRANSMITTAL LETTER CHECKLIST WELL NAME: „i 1./ eli-e_e-4- (L T /-4 PTD: ,2_14--/CJ 70 Development _Service Exploratory _Stratigraphic Test _Non-Conventional FIELD: jib. POOL: � -67de--\1L "`fir I Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 MC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 MC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Logging also required for this well: Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 MC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 II El Co oN o5 Q �o a U) a > c o C, N N a E O co 2 o 0 Z 0 o > o c. _ p a E u) E' O w a 3' (a O N : • a)0. a 2 MO U 0. 8. 4. co > o LL, CO R).CD I- N o a) 0, . E N Q a) 3 p0, Y. '3 0- O- N N 0 CD CD v a) = N• O O > co V X' In to _a °o) c 3 0, 3 = E, o E co v. _ a)' o •C c p O c co , _ L..' c a) co O v a) -3 vi: CoNO a) � 13 m apo `r_ c �° v M' •( E ar a) co a) a) c, w n �° ai 0 c = E rn o CM p • CO 3 a) m Q a) 0 m 0 a) o �, y a p V a s 0. w 0 N n U) a) C 0 d N N >. U N 0' 0 U) Co. 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To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Hilcorp Alaska, LLC Beaver Creek Field BCU-12A FINAL WELL REPORT DML LOGGING DATA Provided by: Approved by: Kevin Eastham Compiled by: James Adams Distribution: John Serbeck Debra Bomar TD Date: July 7, 2014 Dylan Muller BCU 12A 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................2 1.1 Equipment Summary ......................................................................................................................2 1.2 Crew................................................................................................................................................2 2 WELL DETAILS .....................................................................................................................................3 2.1 Well Summary.................................................................................................................................3 2.2 Hole Data........................................................................................................................................3 2.3 Well Synopsis .................................................................................................................................3 2.4 Daily Activity Summary...................................................................................................................4 3 GEOLOGICAL DATA.............................................................................................................................6 3.1 Lithostratigraphy .............................................................................................................................6 3.2 Lithologic Details.............................................................................................................................7 3.3 Connection Gases ........................................................................................................................16 3.4 Trip Gases ....................................................................................................................................16 3.5 Sampling Program / Sample Dispatch..........................................................................................17 4 DRILLING DATA..................................................................................................................................18 4.1 Directional Survey Data................................................................................................................18 4.2 Bit Record.....................................................................................................................................21 4.3 Mud Record ..................................................................................................................................22 5 DAILY REPORTS ................................................................................................................................23 Enclosures: 2” / 100’ Formation Log (MD/TVD) 5” / 100’ Formation Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) Final Data CD BCU 12A 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Mudlogging Unit Computer System Canrig: 3 HP Compaq Workstations (DML, RigWatch, and Sample Catcher) 0 Ditch Gas Canrig: (2) QGM Gas Traps (with High RPM Electric-Powered Agitators) Canrig: E-Series FID THA Analysis and Chromatography. 0 Pason EDR All Drilling Parameters 0 Block Height / Depth Pason WITS Feed 0 Hookload / WOB Pason WITS Feed 0 RPM Pason WITS Feed 0 Torque Pason WITS Feed 0 Return Flow Pason WITS Feed 0 Pit Volumes Pason WITS Feed 0 Mud Gain/Loss Pason WITS Feed 0 Pump Pressure Pason WITS Feed 0 Pump Strokes Pason WITS Feed 0 Rate of Penetration Calculated from Block Position tracking 0 Mud Flow In Calculated from Pump Output/Rate tracking 0 1.2 Crew Unit Number : ML030 Unit Type : Arctic Steel Skid Unit Mudloggers Years*1 Days*2 Sample Catchers Years*1 Days*2 Technician Days Dylan Muller 3 12 Don Thibodeaux 30 9 James Adams 2 12 Debbie Bomar 3 9 *1 Years experience as Mudlogger. *2 Days at well site. BCU 12A 3 2 WELL DETAILS 2.1 Well Summary Well: BCU – 12A API Number: 50-13320530-01-00 Field: Beaver Creek Unit Surface Co-Ordinates: 2024’ FNL, 481’ FEL, SEC 33, T7N, R10W, SM, AK Borough: Kenai Borough, AK Primary Target: Depth: Beluga B18 - B32 State: Alaska TD Depth: 9800’MD / 9547’TVD Rig Name / Type: Saxon 169/Double Suspension Date: n/a Primary Target: Beluga Permit to Drill: 214070 Spud Date: 06/29/2014 Ground Elevation: 150.00’ AMSL Completion Status: Run 5 1/2” Casing RKB Elevation: 168.60’ AMSL Classification: Development Gas Secondary Target: Depth: N/A TD Formation: Beluga TD Date: 07/6/2014 Days Drilling: 8 Days Testing: 0 2.2 Hole Data Maximum Depth Shoe Depth Hole Section MD (ft) TVD (ft) TD Formation Mud Wt (ppg) Dev. (o inc) Casing/ Liner MD (ft) TVD (ft) FIT (ppg) 7.875” 9800’ 9547’ Beluga 9.30 2.45 5 1/2” 2.3 Well Synopsis Beaver Creek #12A is a sidetrack to replace the original Beaver Creek #12 lower Beluga production hole section with a new well. Production logging shows that all production from the BCU12 well came from the Lower Beluga sand. Other Beluga sands are prospective. The intent is to sidetrack the well to the east and mimic the original BCU12 production hole section. The new well will utilize the existing casing program down to 4770’ MD. BCU 12A 4 2.4 Daily Activity Summary June 28, 2014: Finish testing BOPs. Make up milling BHA, pick up drill pipe and RIH; tagged bottom at 4791’. Circulate bottoms up with water and displaced to 6% KCl/PHPA mud. Performed casing test to 3000 PSI; test passed. June 29, 2014: Made up milling BHA and whipstock. Run into the hole to 4754’ to orient whipstock. Set anchor at 4769’. Milled out window from 4769’ to 4810. Pumped high viscosity sweep with no increase in cuttings. Performed FIT to 11.00 ppg EMW. TOW @ 4769’, BOW 4786’. 262.5 pounds of metal cuttings recovered. Pumped 10.5 ppg dry job and tripped out of hole from 4760’ to 3963. June 30, 2014: Tripped out of the hole, laid down milling assembly, made up bottom hole assembly. Ran back into the hole. Picked up drill pipe to 4810’ and drilled ahead to 5079’. July 1, 2014: Continued drilling ahead from 5069’ to 5301’. Appeared to have lost returns; picked up off bottom and killed pumps; well held static with no losses. Resolved problem with flow paddle and drilled ahead to 5311’. Pumped high viscosity sweep with a 100% increase in mostly clay cuttings. Continued drilling to 5600’ and pumped a 20 bbl high viscosity sweep with a 100% increase in cuttings. Drilled ahead to 5997’ and pumped another sweep with 100% increase in cuttings at shakes. All cuttings consisted of pea sized clay and fine coal with occasional slivers of coal. Conducted a wiper trip and drilled ahead. July 2, 2014: Drilled ahead to 6336’ and pumped a 20 bbl high viscosity sweep and observed an increase in cuttings; mostly clay with some coal. Drilled ahead to 6500’ and pumped 20bbl high viscosity sweep with 25% increase in cuttings. Had difficulties sliding and drilled ahead to 6553’ and pumped a 20 bbl, 10 ppb WALL-NUT/CON DET/ high viscosity sweep and attempted to slide. Decision made at 6614’ to mix WALL-NUT a sack at one sack every ten minutes in to suction pit while sliding but this was ineffective. Decision was made to add 2% lubricants to the mud. Drilled to 6870’ and pumped a 20 bbl high viscosity sweep and observed a 25% increase in cuttings. Continued to drill ahead. July 3, 2014: Drilled ahead to 6988’ and pumped a 20 bbl high viscosity sweep with 25% increase in cuttings. Wiper trip to clean up the hole at 6025’. Singled back to bottom with no fill and drilled ahead to 7234. Pumped a 20 bbl high viscosity sweep and observed no increase in cuttings. Drilled ahead to 7483’ and pumped a 20 bbl high viscosity sweep and observed a 10% increase in cuttings. July 4, 2014: Drilled ahead to 7740’ and pumped a 20 bbl high viscosity sweep with 25% increase in cuttings: mostly clay and sand. Increased lubricant concentration in mud to assist with sliding. Continued to drill ahead. July 5, 2014: Drilled ahead to 8167’ pumped a 20 bbl high viscosity sweep prior to wiper trip. Observed a 25% increase in cuttings. Short tripped to 7046’ without incident. Ran back into the hole with no issues and no fill. Picked up and drilled ahead to 8473’. Pumped a 20 bbl high viscosity sweep. BCU 12A 5 July 6, 2014 Pumped a 20 bbl Hi-Vis sweep at 8788' and observed a 100% increase in cuttings (clays and sands). Continued drilling ahead T/9034' and pumped another 20 bbl Hi-Vis sweep- 50% increase in cuttings (mostly small clay with some fine coal). Drilled ahead to 9096'- circulated 4400 strokes. Short-tripped up to last short trip depth of 8100' with tight spots @ 8428', 8290' and 8224'. Ran back to bottom with no issues and had 24' fill. Continued drilling ahead T/9343' and pumped a 20 bbl Hi-Vis sweep; observed no increase in cuttings drilling ahead at time of reporting. . July 7, 2014 Continued drilling ahead to 9657' and pumped a 20 bbl Hi-Vis sweep; observed a 50% increase in cuttings (fine clay with sands and an increase in coal (50%)). Drilled ahead to TD @ 9800'. Pumped 20 bbl Hi- Vis/WALL-NUT sweep- no increase in cuttings at shaker and sweep returned on time. Short-tripped to window. Had several tight spots, but were able to work through without reaming. July 8, 2014 Pumped a 20 bbl Hi-Vis Walnut Sweep and observed a 150% increase in cuttings (large increase in BB sized coals and golf ball sized claystone). Pumped another 20 bbl Hi-Vis sweep 4400 strokes behind the first to help clean the hole again and observed a 50% increase in cuttings (coal is BB sized with sands). Decision was made to TOOH and mad pass F/9564' T/5000' currently at 5458' at time of reporting. Sample catchers released. July 9, 2014 Mad passed T/5027' and flow checked; no flow/losses. TIH on elevators T/8127' and circulated out 1106 units of gas. TIH T/9485' and washed to bottom; encountered 16' of fill. Pumped a 20 bbl Hi-Vis pill; observed a 100% increase in cuttings. Decision was made to POOH - pulled 5 stands and flow checked, hole was static. Pumped a 20 bbl dry job and started POOH while L/D DP sideways; L/D DP sideways at time of reporting. July 10, 2014 Finished LD DP and MWD tools. Changed upper rams for running casing and tested/troubleshoot; RIH w/ 5" casing at time of reporting. July 11, 2014 Finished LD DP and MWD tools. Changed upper rams for running casing and tested/troubleshoot; RIH w/ 5" casing at time of reporting. BCU 12A 6 3 GEOLOGICAL DATA 3.1 Lithostratigraphy All tops were provided by Hilcorp geologist John Serbeck. PROGNOSED OBSERVED FORMATION MD (ft) TVD (ft) TVDSS (ft) MD (ft) TVD (ft) SSTVD (ft) Sterling (KOP) 4800 4706 -4537 4786 4693 4523 Sterling (B1) 5041 4934 -4765 5050 4941 -4771 Sterling (B3) 5212 5096 -4927 5205 4918 5088 Sterling (B4) 5382 5257 -5088 5397 5271 5101 Beluga (B18) 7462 7280 -7111 7475 7250 -7080 Beluga (B23) 7878 7696 -7527 7895 7666 -7496 Beluga (B24) 7990 7808 -7639 8014 7785 -7615 Beluga (B28B) 8325 8142 -7973 8323 8094 -7924 Beluga (B30) 8448 8265 -8096 8458 8229 -8059 Tyonek 8948 8765 -8596 8992 8763 -8593 BCU 12A 7 3.2 Lithologic Details Sand (4820' - 4840') = Light olive gray; predominantly fine-grained; well to very well sorted; angular to subrounded; sphericity low to moderate; unconsolidated; dominate white to bluish white quartz with secondary micro-fragments of coal and lithic clasts. Tuffaceous claystone (4840' - 4870') = Medium dark gray to dark gray; crumbly to pulverulent tenacity; earthy to planar fracture; massive ctgs habit; dull to earthy luster; silty to clayey texture. Sand / sandstone (4870' - 4940') = Dark gray, some medium gray to light and some dark olive gray; medium to fine grained; well to very sorted; angular to subrounded; sphericity predominantly moderate with secondary lows and highs; unconsolidated; grain supported with tuffaceous silt matrix; dominant quartz with secondary dark gray lithic clasts; quartz grains translucent and white to bluish white with secondary sparse micro-fragments of coal and lithic clasts. Tuffaceous siltstone (4940' - 4990') = Predominantly dark gray, trending toward olive black; incohesive; predominantly pulverulent, some crumbly to crunchy; hackly and earthy fracture; massive cuttings habit; dull to earthy luster; silty to clayey texture; massive structure; hydrophilic. Carbonaceous shale/coal (4990' - 5040') = Dark gray to grayish black, moderate reddish brown moderate brown; and light brown; brittle to pulverulent tenacity; fracture earthy and hackly; ctgs habit tabular to wedgelike; luster earthy with occasional frosted; texture smooth to gritty due to sand inclusions; massive structure and thin bed interbedding with coal. Tuffaceous siltstone (5050' - 5080') = Medium dark gray; very hydrophilic and expansive; difficult to determine texture, ctgs habit; pulverulent to sectile tenacity; earthy fracture; earthy to dull luster. Tuffaceous claystone (5080' - 5180') = Medium dark grey to dark grey to olive black to brownish grey to medium grey; sectile to crumbly tenacity; often hydrophilic and difficult to determine physical properties when visible; blocky to planar to earthy fracture, massive to tabular cuttings habit; earthy to dull luster; smooth to granular texture do to sand inclusions; massive structure; very tuffaceous and very arenaceous; varying abundance of micro coal/carbonaceous shale fragments; sand inclusions lower fine to lower medium, dominant quartz, secondary lithic clasts. Sand / tuffaceous sandstone (5180' - 5260') = Medium dark grey to olive grey; upper very fine to lower medium grains; moderately to well sorted; well rounded to subrounded, trace subangular to angular; sphericity moderate to very; mostly unconsolidated, trace tuffaceous sandstone clasts; easily friable, tuff to tuffaceous siltstone matrix supported; noncalcareous; dominant quartz, secondary lithic clasts; quartz translucent with trace green and moderate reddish orange staining, some pale yellowish orange; lithic clasts medium dark grey. Coal (5260’ - 5300') = Black to brownish black; brittle to crunchy; blocky to conchoidal, trace earthy fracture; blocky to platy cuttings habit; earthy to vitreous luster; smooth to silty texture; moderate off gassing. BCU 12A 8 Tuffaceous siltstone (5300' - 5340') = Predominantly dark gray, some black and greenish black; dominant pulverulent tenacity, some range to crumbly; fracture is earthy and occasionally blocky; cuttings habit tabular to wedgelike; luster is earthy, some have slight frosted luster; texture is smooth to silty; structure is massive; trace ash; some show sparse micro laminates of coal; increasingly tuffaceous and more hydrated with increased depth; also, increasingly arenaceous with depth. Tuffaceous claystone (5360' - 5420') = Medium dark gray to olive gray; tenacity crumbly to sectile; irregular to blocky fracture; cuttings habit massive to platy; luster dull to earthy; texture mostly smooth, some sucrosic and granular; structure massive; some bonded with arenaceous siltstone. Sand (5420' - 5460') = Medium dark gray with some dark gray; upper fine to upper medium grains; well sorted; angular to subrounded; sphericity moderate to low; unconsolidated; dominate white to bluish quartz with multiple secondary colors; microfragments of lithic clasts. Tuffaceous sandstone (5460' - 5520') = Light olive grey to olive black and dark grey; lower fine to upper medium grains, trace lower and upper coarse; poorly sorted; dominant well rounded, secondary subrounded; sphericity very high to moderate; easily friable with abundant unconsolidated; grain supported with tuff/ash matrix; dominant quartz grains, secondary lithic clasts and some volcanic glass; abundant colors from greenish grey to moderate red and moderate reddish brown and volcanic glasses translucent moderate yellow; non calcareous. Tuffaceous sandstone (5520' - 5640') = Quartz and lithics, fine to med grain, fair to poorly sorted, angular to sub rounded, mod sphericity, friable with abundant unconsolidated grains, grain supported with tuff and ash matrix, quartz grains with lithic fragments, light to medium grey matrix, white quartz grains with some iron oxide staining, clasts light olive grey-light greenish grey, mod reddish orange to mod reddish brown. Trace volcanic glass, glauconite. Tuffaceous sandstone (5640' - 5740') = Quartz and lithics, fine to med grain, fair to poorly sorted, angular to sub rounded, mod sphericity, friable with abundant unconsolidated grains, grain supported with tuff and ash matrix, quartz grains with lithic fragments, light to medium grey matrix, white quartz grains with some iron oxide staining, clasts light olive grey to light greenish grey, mod reddish orange to mod reddish brown. Trace volcanic glass, glauconite, trace hydrothermal quartz. Tuffaceous sandstone (5740' - 5820') = Quartz and lithics, fine to coarse grain fair to poorly sorted, subangular to subrounded, moderate sphericity, friable, firm with abundant unconsolidated grains, grain supported with tuff and ash matrix. Quartz grains with lithic fragments, light to medium grey matrix. White, clear to opaque quartz grains, clasts light olive, grey to light greenish grey, mod reddish brown. Trace volcanic glass, glauconite, hydrothermal quartz. Non-calcareous. Tuffaceous sandstone (5820' - 5900') = Quartz and lithics, fine to coarse grain fair to poorly sorted, subangular – sub rounded, moderate sphericity, friable to firm with abundant unconsolidated grains grain supported with tuff and ash matrix quartz grains with lithic fragments, light to medium grey matrix. White, clear to opaque quartz grains, clasts light olive, grey to light greenish grey, mod reddish brown, pale yellowish orange. Trace hydrothermal quartz. Non-calcareous. Tuffaceous sandstone 70%, siltstone 30% (5900' - 5980). = Quartz and lithics, fine to coarse grain, poorly sorted, sub-angular to sub rounded, mod sphericity, friable with abundant unconsolidated grains. Grain supported with tuff and ash matrix. Clear to opaque quartz BCU 12A 9 grains, clasts light olive, grey to light greenish grey, mod reddish brown, pale yellowish orange siltstone: pulverulent, planar, platy cuttings habit, dull to earthy luster, silty to clayey texture, massive. Light grey to light brownish grey. Non-calcareous. Trace volcanic glass. Siltstone/tuffaceous siltstone (6000' - 6020') = Dominantly medium dark gray with some dark gray; pulverulent tenacity; hackly to earthy fracture; massive cuttings habit for tuffaceous, more tabular and wedge like for non-tuffaceous siltstone; luster earthy to slightly frosted; texture silty to smooth; structure massive for tuffaceous, thin to massive for non- tuffaceous. Tuffaceous sandstone (6020' - 6060') = Medium dark gray with some medium bluish gray and dark gray; matrix supported; lower very fine to upper medium grains; poorly sorted; well to subrounded with trace subangular; sphericity poor to moderate, secondary discoidal; sandstone easily friable; tuffaceous siltstone matrix; very argillaceous; dominant quartz; secondary lithic clasts with abundant unconsolidated grains. Tuffaceous siltstone (6060' - 6120') = Medium dark gray with some medium bluish gray and dark gray; pulverulent to sectile tenacity; earthy fracture; massive cuttings habit for tuffaceous, tabular and wedge like for non-tuffaceous; luster earthy to slightly frosted; texture smooth to silty; massive structure, less tuffaceous thin to massive; hydrophilic tuffaceous; sparse micro fragmented inclusions including coal; more tuffaceous with increased depth. Sparse ash. Sand (6120' - 6240’) = Medium dark grey to slightly olive grey; upper very fine to upper medium grains; poor to slightly moderate sorting; well rounded to subrounded; sphericity high to moderate, secondary to trace prismoidal; unconsolidated, disaggregated; 60% quartz, 40% lithic clasts, dark grey to medium dark grey, trace visible tuff/ash matrix sand clasts; non calcareous. Tuffaceous siltstone (6200' - 6280') = Medium dark gray to dark gray and bluish gray, bluish gray increasing with depth; pulverulent to sectile tenacity; earthy fracture; massive cuttings habit, dull to earthy luster; smooth to gritty texture, grit due to tuffaceous silty matrix; massive structure; hydrophilic; sparse microfragments including coal; increasing small amounts of ash; and increasing amounts of sand with depth. Sand (6280' - 6300') = Medium bluish gray some medium dark gray, and less dark gray; upper very fine to medium grains, predominantly upper fine to fine; poorly sorted; angular to subrounded; sphericity high to moderate; unconsolidated; 50% quartz, 40% dark coal and obsidian; 10% other colors of clasts; strong presence of tuff/ash matrix; non-calcareous. Sandstone (6300' - 6400') = Dominantly medium dark gray, some dark gray and medium bluish gray; supported in silt and ash matrix; lighter hued grains from upper very fine to upper fine; darker grains from upper very fine to lower medium; poorly sorted; well to subangular; sphericity low to moderate; sandstone hydrophilic and very tuffaceous easily friable; quartz 50%a, secondary lithic clasts 50% dominated by coal microfragments; very sparse shale in 6380 sample. Sandstone (6400' - 6500') = Light bluish gray to med gray, grain supported in silt and ash matrix with unconsolidated grains. Very fine to coarse, poorly sorted, subrounded to angular, low – mod sphericity. 50% clear to opaque quartz, 50% other lithic clasts with coal, trace shale and pale yellowish orange and light brown lithic fragments. Trace tuffaceous siltstone at 6460' and 6480'. Trace coal at 6500'. BCU 12A 10 Tuffaceous sandstone 80% (6520' - 6580') = Gray to medium gray, grain supported in silt and ash matrix with abundant unconsolidated grains. Very fine to coarse poorly sorted subrounded to angular, low to moderate sphericity. Grains 50% clear to opaque quartz, 50% lithic clasts. Tuffaceous siltstone 20% clasts. Pulverulent to malleable, earthy fracture, massive habit, dull to earthy luster, silty to gritty texture, massive structure. Light to medium gray. Trace siltstone with fine laminae. Non-calcareous. Nut plug added to mud. Tuffaceous sandstone 70%, tuffaceous siltstone 30% (6600 - 6700) = Gray to medium gray grain supported in silt and ash matrix with abundant unconsolidated grains. Fine to coarse, poorly sorted, subrounded to angular, low to mod sphericity. Siltstone: mushy to pasty, pulverulent to malleable, earthy fracture, massive habit, dull to earthy luster, clayey to gritty texture, massive structure with some laminae. Light to medium gray with some black and dark gray to black and dark green grains. Fines downward. Non-calcareous. Tuffaceous sandstone (6700 - 6720') = Dominantly medium dark gray with some dark gray and some medium bluish gray; supported in highly hydrophilic silty matrix; lower very fine to upper fine grained; poor to moderate sorting; subangular to rounded; subprismoidal to discoidal sphericity; easily friable sandstone; silty ashy matrix is mushy and pasty; dominant quartz, with secondary lithic clasts and abundant coal microfragments. Tuffaceous siltstone (6740' - 6800') = Dominantly medium dark gray with dark gray and bluish gray; pulverulent to sectile tenacity; earthy fracture; dull to frosted luster; dominantly silty texture, but ranges from gritty to smooth; massive structure; hydrophilic and tuffaceous silty matrix; sparse microfragments, commonly coal; and increasing amounts of ash. Occasional claystone and hard ash. Sand (6800' - 6860') = Medium dark gray with increasing dark gray and less bluish gray; upper fine to lower coarse grained; very poorly sorted; subangular to rounded; wide range of sphericity from subprismoidal to discoidal; highly unconsolidated; white, bluish white, and very light gray colors, equivalent amount of coal microfragments; and a multitude of other colored sand grains mostly in white to gray to black hues. Ash content is increasing and visible in sand and microfragments, and larger specimens. Siltstone (6860' - 6900') = Medium dark with some dark gray and medium bluish gray; tenacity crunchy to brittle, some sectile; irregular fracture; cuttings habit irregular; earthy to frosted luster; silty to granular texture; massive structure; color is primarily a dark reddish brown; when fractured and additional pressure is applied, it break into numerous individual grains. Tuffaceous sandstone (6900' - 6980') = Medium dark gray w/dark gray and medium bluish gray, medium bluish gray becoming prominent in 6960' to 6980' range; upper very fine to upper medium with some lower coarse grains; poor to moderate sorting; rounded to subangular subprismoidal to discoidal sphericity; easily friable; silty ashy matrix; quartz with secondary lithic clasts and coal microfragments; increasing amounts of greenish gray to medium bluish gray siltstone and claystone; still seeing some dark reddish brown siltstone, but not as pronounced as the greens/blues. Tuffaceous sandstone (6980' - 7040') = Medium gray to medium bluish gray with some dark gray; upper very fine to lower medium grained; poor sorting; rounded to subangular; sphericity subprismoidal to subdiscoidal; easily friable; silty ashy matrix; quartz with lithic clasts primarily white to black, with coal microfragments reduced amount of green/blue siltstones no evidence of reddish brown siltstones. BCU 12A 11 Tuffaceous sandstone (7020' - 7080') = Medium gray trending toward medium dark gray due to coal microlithics, less medium bluish gray due to reduced blue/green siltstones and claystone; upper very fine to upper medium grained; poor sorting; rounded to subangular; sphericity subprismoidal to subdiscoidal easily friable; increased mottled appearance due to silty and white ash matrix; quartz with lithic clasts mostly white to black as in grayscale, with coal microfragments; very sparse tuffaceous claystone in blue/green hues sparse plastically deformed and crenulated siltstone with oil stains; no fluorescence or other oil indicators. Tuffaceous sandstone 50%, tuffaceous siltstone 50% (7080’ - 7200') = Light to medium gray some greenish to bluish grey, fine to med grained, poorly sorted, subrounded to subangular, mod sphericity, friable. Matrix supported w. Ash and silt. Siltstone: light to med gray, pasty – mushy, pulverulent, earthy fracture, nodular cuttings habit, earthy luster, gritty to granular texture, massive to fissile. Trace coal. Fines downward. Tuffaceous sandstone 40%, tuffaceous siltstone 60% (7220' - 7300') = Light to medium gray, some mod olive brown, fine to med grained, poorly sorted, subrounded to subangular, mod sphericity, friable. Matrix supported w. Ash and silt. Siltstone: light to med gray, pasty – mushy, pulverulent, earthy fracture, nodular cuttings habit, earthy luster, gritty to granular texture, massive to fissile. Trace coal at 7240. Unconsolidated grains starting at 7280'. Coarsening downward. Copious unconsolidated clear quartz grains at 7280'; med grained, medium to coarse, fair sorting, subangular to angular, mod sphericity. Tuffaceous siltstone 70%, tuffaceous sandstone 30% (7320' - 7400') = Light to med gray mod olive brown, pasty to mushy, pulverulent, earthy fracture, nodular cuttings habit, earthy luster, gritty to granular texture, massive to fissile. Some showing fine laminations. Sandstone light to medium gray, fine to med grained, mod sorted, subrounded to subangular, mod sphericity, friable. Matrix supported with ash and silt. Some unconsolidated quartz and black/dark grey and reddish brown lithics. Tuffaceous siltstone (7400 - 7440') = Medium dark gray and dark greenish gray; dominantly pulverulent, ranges to sectile; earthy fracture; cuttings habit massive, tabular, wedge like, elongated, some curved; dull to frosted luster; gritty to smooth texture, mostly silty; massive to thin structure with increasing amounts of fissility; some coal fragments, mostly microfragments; tuffaceous specimens hydrophilic. Sand (7440' - 7500') = Medium dark gray with dark gray and dark greenish gray; grains from upper medium to lower very fine, most grains within upper/lower fine; poorly sorted; subangular to rounded; subprismoidal sphericity, ranging to subdiscoidal; unconsolidated; ranging from white to black; light at 60% and coal grains 40%; ashy and silty matrix, very hydrophilic. Sandstone (7500' - 7540') = Primarily dark gray, ranges from medium dark gray to grayish black and dark bluish gray; ashy tuffaceous matrix; grains upper very fine to lower coarse, the larger grains are held in the more tuffaceous hydrophilic specimens; poorly sorted; well rounded to subangular; spherical to discoidal sphericity; unconsolidated; easily friable; secondary lithic clasts and coal microfragments. Tuffaceous siltstone (7540' - 7600') = Medium dark gray to medium bluish gray hydrophilic tuffaceous specimens are pulverulent, firmer specimens sectile; earthy fracture, firmer to irregular or blocky fracture; cuttings habit massive, firmer specimens commonly tabular, wedgelike and elongated; luster earthy to frosted with oolitic appearance; texture silty to clayey; structure massive to thin in the less hydrated, l more hydrated often fissile; sparse dark greenish gray to grayish black, highly fissile specimens. BCU 12A 12 Tuffaceous sandstone (7600 - 7660') = Dominantly medium dark gray with some dark gray and some medium bluish gray; supported in highly hydrophilic very silty, slightly ashy, cohesive matrix; matrix is mushy and pasty and holding larger grains; poor to moderate sorting; subangular to rounded; subprismoidal to discoidal sphericity; easily friable; dominant quartz with secondary lithic clasts, including coal microfragments; in color, grains range from whites to grays to blacks. Sand (7660' - 7680') = Medium dark gray to medium bluish gray, with a bit of dark gray; grains predominantly upper fine, but range from lower coarse to lower very fine; poorly sorted; angular to rounded; subprismoidal to discoidal sphericity; unconsolidated; translucent to white to light grays to blacks; 45% quartz; 45% coal; 10% light gray lithic clasts; sparse shale. Tuffaceous sandstone (7680 - 7760') = Dark gray to dusky blue; silty, slightly ashy hydrophilic matrix; upper very fine to lower medium grained; well rounded to subangular; subprismoidal to discoidal sphericity; unconsolidated; translucent / whites /grays/blacks; primarily quartz with lithic microclasts and coal. Coal (7760 - 7800) = Grayish black with some dusky blue; dense to crunchy; splintery to conchoidal fracture. Cuttings habit bladed and elongated, some platy and tabular; vitreous luster; smooth to silty texture; laminar to massive structure; mostly visible as micro-fragments and as grains in sand and siltstones with some larger individual specimens. Tuffaceous siltstone (7820 - 7900') = Light - dark gray, mushy to curdy, pulverulent to malleable, earthy fracture, massive cuttings habit, earthy to dull luster, clayey to smooth texture, massive structure with some showing laminae. Tuffaceous sandstone = dark to med gray, fine to medium grained, fair to poor sorting, subrounded to subangular, moderate sphericity. Some unconsolidated grains: clear and opaque quartz, dark grey to black and dark brown lithics. Traces coal. Tuffaceous siltstone (7920 - 7980') = Light - dark gray, some light olive grey, mushy to curdy, pulverulent - malleable, earthy luster dull luster, clayey smooth, massive structure with some laminae. Some dark to light gray claystone. Sandstone: = dark to medium gray, matrix supported with silt and ash, fine to med grained, fair to poor sorting, subrounded to subangular, moderate sphericity. Some unconsolidated quartz and dark lithics. Trace coal through out with large pieces at 7960'. Coal (7980' - 8000') = Medium dark gray black; tough, dense, brittle, crunchy tenacity; splintery, irregular fracture; cuttings habit platy, scaly, tabular, wedge-like, elongated, bladed; luster vitreous texture silty; most of the coal looks like it has been shattered - very splintery; most smaller than the tuffaceous siltstone and sandstone within the sample tray. Fewer quartz sands and clastic microclasts. Tuffaceous siltstone (8000' - 8080') = Medium bluish gray, medium gray, and medium dark gray - no predominance; hydrophilic, seeing some harder non-tuffaceous siltstone; tuffaceous are pulverulent, firmer are sectile; earthy fracture; cuttings habit massive; luster earthy to frosted, commonly oolitic appearance; texture granular to clayey; massive structure, harder specimens occasionally have microlaminae banding; some specimens are crenulated; few microfragments of coal. Tuffaceous siltstone (8080' - 8160') = Medium dark gray; hydrophilic; pulverulent; firmer are sectile; earthy fracture; cuttings habit massive; BCU 12A 13 luster frosted to earthy; texture silty to clayey; structure massive, some banded and fissile. Few clastic microclasts, sparse coal. Tuffaceous siltstone/siltstone (8160' - 8220') = Medium dark gray to gray; hydrophilic in an ashy silty matrix tuffaceous is pulverulent, siltstone is getting harder and is sectile to brittle earthy fracture; massive cuttings habit for tuffaceous, some siltstone tabular, wedgelike, elongated and bladed; luster mostly frosted; silty to clayey texture. Tuffaceous siltstone (8240' - 8320') = Light dark gray, mushy to curdy, pulverulent to malleable, earthy to dull luster, clayey to smooth texture, massive structure w. Some laminae. Some dark to light gray claystone. Sandstone: = dark to med gray, matrix supported with silt and ash, fine to med grained, fair to poor sorting, subrounded to sub-angular, moderate sphericity. Some unconsolidated quartz and dark lithic sand. Trace coal, black carbonaceous shale throughout. Trace dark olive siltstone at 8320'. Tuffaceous siltstone (8320' - 8400') = Light dark gray, mushy to curdy, pulverulent to crumbly, earthy to dull luster, clayey to gritty texture, massive structure w. Some laminae. Some dark to light gray claystone. Sandstone: = light to dark gray, matrix supported with silt and ash, fine to med grained, fair to poor sorting, sub-rounded to sub-angular, moderate sphericity. Unconsolidated quartz sand from 8340' to 8360'. Trace coal, black carbonaceous shale throughout. Trace yellowish gray tuft at 8400. Tuffaceous siltstone (8420' - 8500') = Light to dark gray, mushy to curdy, pulverulent to crumbly, earthy-dull luster, clayey to gritty texture, massive structure with some laminae. Some dark to light gray claystone. Sandstone: = light to dark gray, matrix supported with silt and ash, fine to med grained, fair to poor sorting, sub-rounded to sub-angular, moderate sphericity. Unconsolidated quartz sand fine to coarse, trace coal, black carbonaceous shale throughout. Tuffaceous siltstone (8520' - 8600') = Light to dark gray, some light olive gray, mushy- curdy, malleable-crunchy, earthy - dull luster, clayey-gritty texture, massive w some laminae. Some sandstone: light to dark gray, matrix supported with ash and silt fine-medium grained, fair sorting, sub-rounded to sub-angular, moderate sphericity. Some unconsolidated grains: opaque quartz, black or dark gray and grayish orange irregular grains. Around 10% bituminous coal at 8580. Trace carbonaceous shale throughout. Tuffaceous siltstone/siltstone (8600' - 8660') = Primarily medium dark gray, with dark gray to medium gray; the more tuffaceous siltstone is curdy, mushy, and pasty, the nontuffaceous is tacky; tenacity pulverulent; earthy fracture; massive cuttings habit; earthy to frosted luster; clayey to silty texture; massive structure, some fissile; sparse carbonaceous shale; some siltstone is tabular, elongated, and fissile with occasional coal laminae. Most of sample is in a silty matrix, some matrix is silt and ash-based; some coal is present. Coal (8660' - 8680') = Grayish black to dense to crunchy; splintery fracture; luster vitreous; texture smooth; thin structure; some brownish black carbonaceous shale present. Tuffaceous claystone (8680' - 8700') = Dark gray to medium dark gray; tacky consistency; pulverulent to sectile; earthy and irregular fracture; cuttings habit primarily elongated and tabular; luster dull and earthy with some Carbonaceous shale (8700' - 8780') = Medium dark gray to grayish black; pulverulent to crumbly; earthy and irregular fracture; massive cuttings habit; frosted to earthy luster; smooth to silty texture; structure often banded with coal laminae; color BCU 12A 14 varies but predominantly brownish gray; sparse coal and sand present in the sample. Carbonaceous shale content increases with depth. Sand (8800' - 8860') = Grayish black to black; coal grains predominantly upper very fine to lower fine, quartz and clastic sand ranges from upper very fine to lower medium in size; well to moderate sorted; very angular to rounded - coals the first, quartz the latter; prismoidal to discoidal; unconsolidated; coal 50%, quartz 50%; quartz translucent to white to light grays, coal black, vitreous, and shattered in appearance. Reduced coal grains in 8840' to 70% quartz and 30% co some carbonaceous shale. Coal (8860' - 8880') = Grayish black to dense to crunchy; splintery fracture; luster vitreous; texture smooth; thin structure; some brownish black carbonaceous shale present, along with tuffaceous siltstone. Claystone (8880' - 8920') = Medium gray dark gray; plastic; tacky; malleable to sectile; earthy to blocky fracture; cuttings habit tabular to massive; luster; dull and earthy luster; smooth to silty Tuffaceous siltstone (8920' - 8960') = Medium gray to medium dark gray; pulverulent, firmer are sectile; earthy fracture; massive cuttings habit; luster frosted to earthy; texture silty to clayey; structure massive; sparse claystone and carbonaceous shale. Coal (8960' - 9000') = Grayish black to dense to crunchy; splintery fracture; luster vitreous; texture smooth; thin structure; some brownish black. Some tuffaceous siltstone and sparse siltstone and carbonaceous shale. Tuffaceous sandstone (9020 – 9100) = Very light gray to light gray. Quartz, fine to medium grain size, fair to poor sorting, subrounded to subangular, sub prismoidal to subdiscoidal, frosted grains. Soft to friable, silica cement, grain supported. Some tuffaceous siltstone. Medium gray to medium dark gray; pulverulent, firmer are sectile; earthy fracture; massive cuttings habit; luster frosted to earthy; texture silty to clayey; structure massive; sparse claystone and carbonaceous shale. Abundant coal at 9040' and 9100. Trace coal in all samples. Trace carbonaceous shale. Tuffaceous siltstone (9120' - 9200') = Light to dark gray, some light olive gray, mushy to curdy, malleable to crunchy, earthy to dull luster, clayey to gritty texture, massive w some laminae. Some sandstone: light to dark gray, matrix supported with ash and silt fine to medium grained, fair sorting, sub-rounded to sub-angular, moderate sphericity. Some unconsolidated grains: opaque quartz, black or dark gray and grayish orange irregular grains. Approximately 10% to 20% bituminous coal at 9160 and 9180'. Abundant brownish gray and olive gray at 9200'. Tuffaceous siltstone (9220' - 9240') = Bituminous coal >50%. Abundant tuffaceous sandstone: very light gray to light gray. Quartz, fine to medium grain size, fair to poor sorting, subrounded to subangular, sub prismoidal to sub to discoidal, frosted grains. Soft to friable, silica cement, grain supported. Some tuffaceous siltstone as above. Tuffaceous siltstone (9240' - 9260') = Mostly medium gray, some medium dark gray; pasty and tacky; pulverulent to sectile; earthy and blocky fracture; cuttings habit massive, siltstone with more clay more tabular and elongated; luster earthy and frosted; texture clayey and silty; structure massive, the hydrophilic specimens are often fissile, sparse coal laminae; coal and carbonaceous shale also present, as is tuffaceous claystone. BCU 12A 15 Coal (9260' - 9300') = Black to brownish black, dark gray; brittle to crunchy; irregular, splintery fracture; luster vitreous, some frosty due to silt; smooth to silty texture; structure - it all looks shattered, thin to massive. Carbonaceous shale (9300' - 9320') = Primarily medium dark gray; multiple tenacities: tough, dense, brittle, crumbly, crunchy, pulverulent; mostly earthy fracture; cuttings habit massive in smaller specimens, larger pieces are tabular and wedgelike, elongated; luster earthy; texture silty to gritty; structure massive; tuffaceous claystone increasing. Tuffaceous sandstone (9320' - 9420') = Medium light gray to medium gray; lower very fine to upper very fine grained; well to fair sorted; rounded to subangular; spherical to discoidal; ashy silty matrix; quartz 90% coal 5% 5% mixture of ash and lithic clasts. Coal (9420' - 9440') = Black to brownish black, dark gray; brittle to crunchy; irregular, splintery fracture; luster vitreous, some frosty due to silt; smooth to silty texture; structure - it all looks shattered, thin to massive. Tuffaceous siltstone (9440' - 9500') = Medium gray to medium dark gray, some dark gray; pulverulent tenacity; less tuffaceous range to crumbly; earthy fracture; cuttings habit massive; earthy and frosted luster; texture silty; structure massive; ashy, coal present. Tuffaceous sandstone (9500' - 9540') = Medium light gray to medium dark gray; lower very fine to upper very fine grained; well to fair sorted; rounded Carbonaceous shale (9540' - 9560') = Medium gray with dark salt and pepper appearance; crunchy to pulverulent; earthy and irregular fracture; cuttings habit massive, larger pieces are elongated, tabular and wedge like; luster earthy; texture silty to polished; structure massive Coal (9560' - 9580') = Black to brownish black, dark gray; brittle to crunchy; irregular, splintery fracture; luster vitreous, some frosty due to silt; smooth to silty texture; structure thin to massive. Tuffaceous sandstone (9580' - 9660') = Medium light gray to medium dark gray; lower very fine to upper very fine grained; well to fair sorted; rounded to subangular; spherical to discoidal; easily friable to firm; very ashy matrix primarily quartz secondary coal fragment. Sample 9660 has 20% unconsolidated sand. Sand (9660' - 9700') = Medium dark gray; lower very fine to lower medium; predominantly fine grained; angular to subrounded, subprismoidal to discoidal sphericity; unconsolidated; dominant translucent, white, light gray quartz, some coal and ash grains; tuffaceous sandstone medium gray with some infrequent ashy laminae/banding. Tuffaceous siltstone (9700' 9740') = Medium light gray to medium dark gray pulverulent tenacity; less tuffaceous pulverulent to crumbly; earthy fracture; cuttings habit massive; earthy and frosted luster; texture silty; Coal (9760' - 9780') = Black; brittle to crunchy; irregular and splintery fracture; vitreous luster, some frosting due to silt; smooth to silty texture; structure thin to massive. BCU 12A 16 Tuffaceous sandstone (9780' - 9800') = Medium to light gray to medium dark gray; very fine to med grain, mod sorted, rounded to subangular, spherical to discoidal; friable to firm, ashy matrix primarily quartz with some coal. 3.3 Connection Gases 200 units = 1% Methane Equivalent Measured Depth (feet) Subsea Total Vertical Depth (feet) Gas over background (units) Measured Depth (feet) Subsea Total Vertical Depth (feet) Gas over background (units) 9095 8926.4 900 9160 8991.4 140 9220 9051.4 250 9285 9116.4 726 9345 9176.4 215 9525 9356.4 350 9595 9426.4 130 9655 9486.4 55 3.4 Trip Gases 200 units = 1% Methane Equivalent Measured Depth (feet) Trip to (feet) Maximum Gas (Units) Pumps Off Time (hours) 9714 Casing Trip Gas 1318 BCU 12A 17 3.5 Sampling Program / Sample Dispatch Set Type / Purpose Frequency* Interval Dispatched to A, B Washed and dried reference samples 20 ft 4820 ft – 9800 ft Debra Oudean Hilcorp Alaska LLC 3800 Centerpoint Drive Suite #100 Anchorage AK 99503 (907) 777-8337 Sample frequency may be locally altered according to drill rate constraints and zones of interest. SAMPLE TYPE STARTING DEPTH ENDING DEPTH Washed and dried 20' 4800' 5900' Washed and dried 20' 5900' 6860' Washed and dried 20' 6860' 7740' Washed and dried 20' 7740' 8700' Washed and dried 20' 8700' 9800' TD NUMBER OF BOXES 2 sets of five boxes each 10 boxes total REMARKS: 250 SAMPLE BAGS PER SET 500 TOTAL SAMPLE BAGS TOTAL OF TWO SETS FROM: 4800' TO 9800' BC U 1 2 A 18 4 D R I L L I N G D A T A 4. 1 D i r e c t i o n a l S u r v e y D a t a Me a s u r e d De p t h ( f t ) In c . (o ) Az i . (o ) Tr u e V e r t i c a l De p t h ( f t ) No r t h i n g (f t ) Ea s t i n g (f t ) Ve r t i c a l Se c t i o n ( f t ) Dogleg Rate (o /100ft) 48 3 9 . 6 8 1 9 . 9 9 6 0 . 0 4 4 7 4 3 . 3 2 3 7 6 . 2 1 5 0 2 . 7 9 2 4 7 . 3 3 4 . 1 2 49 0 3 . 1 8 1 9 . 7 4 6 7 . 4 9 4 8 0 3 . 0 5 3 8 5 . 7 4 5 2 2 . 1 1 2 5 9 . 2 9 4 49 6 5 . 0 3 2 0 . 1 6 7 4 . 5 1 4 8 6 1 . 2 3 9 2 . 5 8 5 4 2 . 0 3 2 7 3 . 1 2 3 . 9 3 50 2 7 . 3 2 0 . 3 3 8 1 . 1 8 4 9 1 9 . 6 3 3 9 7 . 1 1 5 6 3 . 0 6 2 8 9 . 0 7 3 . 7 1 50 8 9 . 2 8 2 0 . 2 5 8 2 . 5 5 4 9 7 7 . 7 6 4 0 0 . 1 5 5 8 4 . 3 4 3 0 5 . 9 8 0 . 7 8 51 5 1 . 1 1 9 . 7 9 8 1 . 9 4 5 0 3 5 . 8 5 4 0 3 6 0 5 . 3 1 3 2 2 . 7 1 0 . 8 2 52 1 3 . 9 7 1 8 . 9 7 8 1 . 6 5 5 0 9 5 . 1 6 4 0 5 . 9 8 6 2 5 . 9 6 3 3 9 . 1 1 1 . 3 1 52 7 4 . 8 1 1 8 . 8 8 8 0 . 8 5 5 1 5 2 . 7 1 4 0 8 . 9 8 6 4 5 . 4 6 3 5 4 . 4 9 0 . 4 5 53 3 8 . 6 6 1 8 . 0 4 8 1 . 2 8 5 2 1 3 . 2 7 4 1 2 . 1 2 6 6 5 . 4 3 3 7 0 . 2 2 1 . 3 3 53 9 9 . 7 6 1 7 . 8 8 8 0 . 4 7 5 2 7 1 . 3 9 4 1 5 . 1 1 6 8 4 . 0 3 3 8 4 . 8 3 0 . 4 9 54 6 2 . 0 6 1 7 . 7 3 8 3 . 9 7 5 3 3 0 . 7 1 4 1 7 . 6 9 7 0 2 . 9 3 9 9 . 8 8 1 . 7 3 55 2 4 . 5 3 1 7 . 3 5 8 9 . 3 9 5 3 9 0 . 2 8 4 1 8 . 7 9 7 2 1 . 6 7 4 1 5 . 5 9 2 . 6 8 55 8 7 . 5 6 1 7 . 3 6 9 3 . 7 1 5 4 5 0 . 4 4 4 1 8 . 2 8 7 4 0 . 4 6 4 3 2 . 1 1 2 . 0 4 56 4 6 . 9 3 1 7 . 2 9 9 7 . 0 8 5 5 0 7 . 1 2 4 1 6 . 6 2 7 5 8 . 0 5 4 4 8 . 1 8 1 . 6 9 57 1 0 . 2 1 1 7 . 6 6 1 0 0 . 5 6 5 5 6 7 . 4 8 4 1 3 . 7 7 7 6 . 8 2 4 6 5 . 8 9 1 . 7 5 57 7 2 . 6 6 1 7 . 4 1 0 4 . 7 5 6 2 7 . 0 3 4 0 9 . 6 7 9 5 . 1 6 4 8 3 . 8 3 2 . 0 4 58 3 4 . 4 1 1 6 . 8 9 1 1 1 . 4 3 5 6 8 6 . 0 5 4 0 3 . 9 7 8 1 2 . 4 5 5 0 1 . 6 1 3 . 3 2 58 9 3 . 5 3 1 7 . 1 1 1 6 . 8 1 5 7 4 2 . 5 9 3 9 6 . 9 2 8 2 8 . 2 5 1 8 . 7 8 2 . 6 8 59 5 8 . 7 1 7 . 3 1 1 2 0 . 8 2 5 8 0 4 . 8 4 3 8 7 . 6 3 8 4 5 . 0 8 5 3 8 . 0 5 1 . 8 5 60 1 7 . 7 9 1 6 . 7 1 1 2 1 . 3 2 5 8 6 1 . 3 5 3 7 8 . 7 1 8 5 9 . 8 8 5 5 5 . 3 3 1 . 0 5 60 7 9 . 9 1 6 . 4 6 1 2 1 . 1 5 9 2 0 . 8 8 3 6 9 . 5 2 8 7 5 . 0 5 5 7 3 . 0 5 0 . 4 2 61 4 2 . 4 3 1 6 . 4 3 1 1 9 . 7 9 5 9 8 0 . 8 5 3 6 0 . 5 5 8 9 0 . 3 1 5 9 0 . 7 5 0 . 6 62 0 4 . 1 6 1 5 . 7 3 1 2 0 . 1 6 6 0 4 0 . 1 6 3 5 2 . 0 1 9 0 5 . 1 2 6 0 7 . 8 5 1 . 1 5 62 6 6 . 4 3 1 6 . 2 3 1 2 0 . 7 9 6 1 0 0 . 0 3 3 4 3 . 3 1 9 1 9 . 8 9 6 2 4 . 9 9 0 . 8 5 63 2 8 . 5 8 1 7 . 9 1 1 1 9 . 2 5 6 1 5 9 . 4 4 3 3 4 . 2 9 3 5 . 6 9 6 4 3 . 2 3 2 . 8 63 9 0 . 9 6 1 7 . 9 2 1 1 8 . 6 9 6 2 1 8 . 7 9 3 2 4 . 9 9 5 2 . 4 8 6 6 2 . 4 2 0 . 2 8 BC U 1 2 A 19 Me a s u r e d De p t h ( f t ) In c . (o ) Az i . (o ) Tr u e V e r t i c a l De p t h ( f t ) No r t h i n g (f t ) Ea s t i n g (f t ) Ve r t i c a l Se c t i o n ( f t ) Dogleg Rate (o /100ft) 64 5 3 . 3 2 1 7 . 2 3 1 1 7 . 6 4 6 2 7 8 . 2 4 3 1 6 . 0 1 9 6 9 . 0 8 6 8 1 . 2 4 1 . 2 2 65 1 4 . 1 9 1 6 . 6 3 1 1 8 . 5 6 3 3 6 . 4 7 3 0 7 . 6 8 9 8 4 . 7 2 6 9 8 . 9 5 1 . 0 7 65 7 6 . 5 8 1 6 . 6 5 1 1 9 . 8 5 6 3 9 6 . 2 5 2 9 8 . 9 7 1 0 0 0 . 3 2 7 1 6 . 8 2 0 . 6 2 66 3 8 . 1 7 1 6 . 1 2 1 1 9 . 9 2 6 4 5 5 . 3 4 2 9 0 . 3 1 1 0 1 5 . 3 8 7 3 4 . 1 9 0 . 8 6 67 0 1 . 1 8 1 6 . 7 3 1 2 1 . 3 3 6 5 1 5 . 7 8 2 8 1 . 2 3 1 0 3 0 . 7 1 7 5 2 1 . 1 6 67 6 2 . 7 1 8 . 2 3 1 2 1 . 6 5 6 5 7 4 . 4 5 2 7 1 . 5 8 1 0 4 6 . 4 6 7 7 0 . 4 8 2 . 4 4 68 2 4 . 5 9 1 7 . 7 3 1 2 2 . 6 8 6 6 3 3 . 3 2 2 6 1 . 4 1 1 0 6 2 . 6 4 7 8 9 . 5 7 0 . 9 6 68 8 7 . 9 7 1 7 . 2 8 1 2 1 . 3 6 6 9 3 . 7 7 2 5 1 . 3 1 1 0 7 8 . 8 8 0 8 . 6 2 0 . 9 7 69 4 7 . 7 5 1 6 . 7 1 1 2 1 . 2 6 6 7 5 0 . 9 4 2 4 2 . 2 4 1 0 9 3 . 7 4 8 2 6 . 0 9 0 . 9 5 70 1 0 . 0 8 1 6 . 1 1 2 1 . 5 6 8 1 0 . 7 3 2 3 3 . 0 7 1 1 0 8 . 7 7 8 4 3 . 6 8 0 . 9 8 70 7 1 . 6 7 1 5 . 7 3 1 2 1 . 6 3 6 8 6 9 . 9 6 2 2 4 . 2 3 1 1 2 3 . 1 6 8 6 0 . 5 7 0 . 6 71 3 3 . 6 1 5 . 6 3 1 2 1 . 8 8 6 9 2 9 . 5 8 2 1 5 . 4 2 1 1 3 7 . 3 9 8 7 7 . 3 0 . 1 9 71 9 5 . 3 5 1 4 . 9 9 1 2 3 . 2 3 6 9 8 9 . 1 4 2 0 6 . 6 5 1 1 5 1 . 1 3 8 9 3 . 5 8 1 . 1 9 72 5 7 . 9 1 4 . 2 6 1 2 3 . 7 3 7 0 4 9 . 6 6 1 9 7 . 9 4 1 1 6 4 . 3 1 9 0 9 . 3 5 1 . 1 8 73 2 0 . 2 3 1 3 . 9 1 2 4 . 3 7 1 1 0 . 1 2 1 8 9 . 4 6 1 1 7 6 . 8 7 9 2 4 . 4 7 0 . 6 2 73 8 1 . 9 3 1 3 . 7 3 1 2 3 . 0 6 7 1 7 0 . 0 4 1 8 1 . 2 9 1 1 8 9 . 1 3 9 3 9 . 1 8 0 . 5 5 74 4 5 . 5 3 1 2 . 5 8 1 2 3 . 1 7 2 3 1 . 9 7 1 7 3 . 3 9 1 2 0 1 . 2 6 9 5 3 . 6 3 1 . 8 1 75 0 6 . 3 9 1 2 . 3 2 1 2 3 . 3 7 7 2 9 1 . 4 1 6 6 . 2 1 2 1 2 . 2 4 9 6 6 . 7 3 0 . 4 4 75 6 9 . 0 3 1 1 . 3 1 1 2 0 . 5 7 3 5 2 . 7 1 1 5 9 . 4 1 2 2 3 . 1 1 9 7 9 . 5 4 1 . 8 6 76 3 1 . 9 2 1 1 . 1 7 1 2 0 . 5 4 7 4 1 4 . 3 9 1 5 3 . 1 8 1 2 3 3 . 6 7 9 9 1 . 8 0 . 2 2 76 9 3 . 5 5 9 . 4 5 1 1 9 . 1 4 7 4 7 5 . 0 2 1 4 7 . 6 8 1 2 4 3 . 2 3 1 0 0 2 . 8 3 2 . 8 2 77 5 6 . 1 9 9 . 3 2 1 1 6 . 6 4 7 5 3 6 . 8 3 1 4 2 . 9 1 2 5 2 . 2 6 1 0 1 3 . 0 3 0 . 6 8 78 1 6 . 2 7 7 . 9 8 1 1 6 . 4 1 7 5 9 6 . 2 2 1 3 8 . 8 7 1 2 6 0 . 3 4 1 0 2 2 . 0 5 2 . 2 3 78 7 5 . 1 1 7 . 2 1 1 9 . 4 6 7 6 5 4 . 5 5 1 3 5 . 2 4 1 2 6 7 . 2 1 1 0 2 9 . 8 2 1 . 4 9 79 4 0 . 6 6 5 . 4 3 1 2 0 . 4 9 7 7 1 9 . 7 1 3 1 . 6 4 1 2 7 3 . 4 6 1 0 3 7 . 0 3 2 . 7 1 80 0 3 . 6 1 2 . 7 3 1 1 0 . 3 2 7 7 8 2 . 4 8 1 2 9 . 6 1 1 2 7 7 . 4 3 1 0 4 1 . 4 8 4 . 4 2 80 6 5 . 5 5 2 . 0 5 1 1 3 . 8 7 7 8 4 4 . 3 7 1 2 8 . 6 5 1 2 7 9 . 8 3 1 0 4 4 . 0 4 1 . 1 2 81 2 7 . 4 4 0 . 6 1 1 2 2 . 2 1 7 9 0 6 . 2 4 1 2 8 . 0 3 1 2 8 1 . 1 2 1 0 4 5 . 4 7 2 . 3 4 81 8 7 . 5 2 0 . 5 4 7 6 . 1 6 7 9 6 6 . 3 2 1 2 7 . 9 2 1 2 8 1 . 6 7 1 0 4 5 . 9 9 0 . 7 6 82 4 8 . 3 8 0 . 4 3 1 2 6 . 9 2 8 0 2 7 . 1 7 1 2 7 . 8 5 1 2 8 2 . 1 3 1 0 4 6 . 4 3 0 . 7 83 1 0 . 2 5 0 . 5 6 1 3 1 . 9 1 8 0 8 9 . 0 4 1 2 7 . 5 1 1 2 8 2 . 5 4 1 0 4 6 . 9 5 0 . 2 2 BC U 1 2 A 20 Me a s u r e d De p t h ( f t ) In c . (o ) Az i . (o ) Tr u e V e r t i c a l De p t h ( f t ) No r t h i n g (f t ) Ea s t i n g (f t ) Ve r t i c a l Se c t i o n ( f t ) Dogleg Rate (o /100ft) 83 7 4 . 2 4 0 . 7 7 1 2 6 . 7 8 8 1 5 3 . 0 3 1 2 7 . 0 5 1 2 8 3 . 1 1 1 0 4 7 . 6 9 0 . 3 4 84 3 7 . 0 2 0 . 6 5 1 0 2 . 2 4 8 2 1 5 . 8 1 2 6 . 7 2 1 2 8 3 . 8 1 0 4 8 . 4 4 0 . 5 2 84 9 8 . 9 6 0 . 7 5 1 3 1 . 7 8 2 7 7 . 7 4 1 2 6 . 3 7 1 2 8 4 . 4 5 1 0 4 9 . 1 8 0 . 6 85 6 2 . 4 4 0 . 6 8 1 1 1 . 1 3 8 3 4 1 . 2 1 1 2 5 . 9 6 1 2 8 5 . 1 1 1 0 4 9 . 9 5 0 . 4 2 86 2 3 . 7 4 1 . 1 8 1 2 8 . 7 3 8 4 0 2 . 5 1 2 5 . 4 4 1 2 8 5 . 9 4 1 0 5 0 . 9 4 0 . 9 3 86 8 6 . 3 3 0 . 8 2 1 1 4 . 8 8 8 4 6 5 . 0 8 1 2 4 . 8 4 1 2 8 6 . 8 5 1 0 5 2 . 0 2 0 . 6 9 87 4 8 . 4 6 0 . 9 5 1 1 2 . 3 7 8 5 2 7 . 2 1 1 2 4 . 4 6 1 2 8 7 . 7 3 1 0 5 2 . 9 7 0 . 2 2 88 1 0 . 9 3 1 . 2 1 1 0 3 . 2 7 8 5 8 9 . 6 7 1 2 4 . 1 1 1 2 8 8 . 8 5 1 0 5 4 . 1 2 0 . 5 88 7 2 . 8 4 1 . 2 7 1 1 5 . 5 6 8 6 5 1 . 5 6 1 2 3 . 6 7 1 2 9 0 . 1 1 0 5 5 . 4 3 0 . 4 4 89 3 5 . 0 4 1 . 8 3 1 0 1 . 9 5 8 7 1 3 . 7 4 1 2 3 . 1 6 1 2 9 1 . 7 1 0 5 7 . 0 6 1 . 0 7 89 9 5 . 2 1 2 1 0 5 . 9 1 8 7 7 3 . 8 8 1 2 2 . 6 8 1 2 9 3 . 6 5 1 0 5 8 . 9 9 0 . 3 6 90 5 7 . 1 3 1 . 9 2 1 0 1 . 1 8 8 8 3 5 . 7 6 1 2 2 . 1 8 1 2 9 5 . 7 1 0 6 1 . 0 2 0 . 2 9 91 1 8 . 9 8 1 . 0 8 9 2 . 6 4 8 8 9 7 . 5 9 1 2 1 . 9 5 1 2 9 7 . 3 1 0 6 2 . 5 2 1 . 4 91 8 1 . 9 1 . 2 1 9 5 . 2 8 8 9 6 0 . 5 1 2 1 . 8 6 1 2 9 8 . 5 6 1 0 6 3 . 6 5 0 . 2 2 92 4 5 . 0 9 1 . 8 6 8 2 . 8 9 9 0 2 3 . 6 6 1 2 1 . 9 3 1 3 0 0 . 2 4 1 0 6 5 . 0 8 1 . 1 5 93 0 7 . 7 4 1 . 5 6 9 4 . 4 1 9 0 8 6 . 2 9 1 2 1 . 9 9 1 3 0 2 . 1 1 0 6 6 . 6 6 0 . 7 3 93 6 7 . 5 4 2 . 0 7 9 0 . 5 1 9 1 4 6 . 0 5 1 2 1 . 9 2 1 3 0 3 . 9 9 1 0 6 8 . 3 3 0 . 8 8 94 3 1 . 3 3 1 . 7 7 1 0 2 . 8 3 9 2 0 9 . 8 1 1 2 1 . 6 9 1 3 0 6 . 1 1 0 7 0 . 2 7 0 . 8 94 9 3 . 0 2 2 . 0 7 9 9 . 6 2 9 2 7 1 . 4 6 1 2 1 . 2 9 1 3 0 8 . 1 3 1 0 7 2 . 2 3 0 . 5 2 95 5 5 . 1 9 1 . 7 6 1 1 0 . 7 9 3 3 3 . 6 1 2 0 . 7 7 1 3 1 0 . 1 3 1 0 7 4 . 2 2 0 . 7 7 96 1 5 . 2 2 2 . 3 2 1 0 4 . 7 3 9 3 9 3 . 5 9 1 2 0 . 1 3 1 3 1 2 . 1 7 1 0 7 6 . 3 1 96 7 9 . 4 8 2 . 1 9 1 0 8 . 8 1 9 4 5 7 . 8 1 1 9 . 4 1 3 1 4 . 5 9 1 0 7 8 . 7 6 0 . 3 2 97 4 0 . 1 5 2 . 0 1 1 1 9 . 7 3 9 5 1 8 . 4 3 1 1 8 . 5 1 3 1 6 . 6 1 1 0 8 0 . 9 6 0 . 7 2 97 6 1 . 7 6 2 . 4 5 1 2 1 . 1 8 9 5 4 0 . 0 2 1 1 8 . 0 8 1 3 1 7 . 3 3 1 0 8 1 . 8 1 2 . 0 5 BC U 1 2 A 21 4. 2 B i t R e c o r d Bi t S i z e M a k e Ty p e SN Je t s TF A De p t h In De p t h Ou t Fo o t a g e Dr i l l e d Bi t Ho u r s Av g . RO P (f t / h r ) Av g . WO B (kl b s ) Av g . RP M Avg. PP (psi) Grade 1 8 . 5 B H C m i l l b i t 4 7 9 1 ’ 4 8 1 0 ’ 1 9 n / a 2 7 . 8 7 5 H D B S MM 5 5 12 4 6 0 6 5 1 5x 1 2 4 8 1 0 ’ 9 8 0 0 ’ 4 9 9 0 ’ 1 0 4 . 6 4 4 8 ’ n / a 4 - 4 - B T - A - X - 1 - C T - T D BC U 1 2 A 22 4. 3 Mu d R e c o r d Co n t r a c t o r : H a l l i b u r t o n / B a r o i d Mu d T y p e : H a l l i b u r t o n / H D B S M N Da t e De p t h (f t ) MW (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) So l s (% ) O/ W Ra t i o Sd (% ) MB T (p p b eq . ) pH Al k (P m ) Cl (mg/L) Ca (mg/L) 06 / 2 8 / 1 4 4 7 9 1 9 . 0 5 0 9 1 5 6 / 8 / 1 0 6 . 2 2 . 4 0 . 0 / 9 5 . 0 n / a 9 . 1 0 . 2 5 3 1 0 0 0 6 0 06 / 2 9 / 1 4 4 8 1 0 9 . 0 5 7 1 2 2 0 7 / 1 1 / 1 5 5 . 9 2 . 3 0 . 0 / 9 5 . 1 n / a 9 . 1 0 . 2 5 3 1 5 0 0 1 4 0 06 / 3 0 / 1 4 5 0 6 9 9 . 0 5 5 1 1 2 0 7 / 1 0 / 1 3 5 . 4 2 . 3 0 . 0 / 9 5 . 0 n / a 9 . 7 0 . 2 0 3 2 5 0 0 8 0 07 / 0 1 / 1 4 6 1 1 4 9 . 0 5 6 1 1 3 2 3 7 / 1 1 / 1 6 5 . 6 2 . 8 0 . 0 / 9 4 . 6 1 . 0 8 . 8 0 . 2 0 3 1 0 0 0 1 6 0 07 / 0 2 / 1 4 6 9 4 0 6 7 4 4 6 1 1 6 2 0 6 / 9 / 1 2 4 . 4 3 . 4 2 . 0 / / 9 2 0 1 . 5 9 . 3 0 . 4 0 3 2 0 0 0 8 0 07 / 0 3 / 1 4 7 6 0 8 9 . 1 0 5 5 1 3 1 9 6 / 8 / 1 1 4 . 5 3 . 0 1 . 0 / 9 3 . 2 1 . 5 9 . 3 0 . 4 5 3 5 0 0 0 8 0 07 / 0 4 / 1 4 8 1 1 4 9 . 1 0 5 6 1 6 2 2 6 / 9 / 1 2 4 . 0 3 . 3 2 . 0 / 9 2 . 1 2 . 0 8 . 5 1 . 0 0 3 2 0 0 0 6 0 07 / 0 5 / 1 4 8 7 8 9 9 . 2 0 5 6 1 6 2 0 6 / 8 / 1 1 3 . 5 4 . 0 0 . 5 / 9 2 . 9 2 . 0 8 . 5 0 . 2 5 3 2 0 0 0 6 0 07 / 0 6 / 1 4 9 4 8 5 9 . 3 0 5 1 1 6 2 1 6 / 8 / 1 1 3 . 6 4 . 6 0 . 1 / 9 2 . 6 2 . 5 8 . 5 0 . 2 0 3 3 0 0 0 8 0 07 / 0 7 / 1 4 9 8 0 0 9 . 3 0 5 3 1 5 2 0 6 / 9 / 1 2 3 . 3 4 . 6 0 . 0 / 9 2 . 7 2 . 5 8 . 5 0 . 4 0 3 3 0 0 0 8 0 07 / 0 8 / 1 4 9 8 0 0 9 . 4 5 5 4 1 5 2 1 6 / 1 0 / 1 5 3 . 3 5 . 8 0 . 0 / 9 1 . 7 3 . 7 9 . 0 0 . 3 0 3 1 0 0 0 8 0 07 / 0 9 / 1 4 9 8 0 0 9 . 5 5 2 1 4 1 9 5 / 9 / 1 2 3 . 3 6 . 1 0 . 0 / 9 1 . 5 4 . 0 8 . 2 0 . 2 5 3 0 0 0 0 8 0 07 / 1 0 / 1 4 9 8 0 0 9 . 4 5 5 0 3 0 1 9 5 / 8 / 1 0 3 . 8 6 . 0 0 . 0 / 9 1 . 6 4 . 0 8 . 3 0 . 3 0 3 0 0 0 0 8 0 07 / 1 1 / 1 4 9 8 0 0 9 . 4 5 5 0 1 3 1 9 5 / 8 / 1 0 3 . 8 6 0 . 0 / 9 1 . 6 4 8 . 3 0 . 3 0 3 0 0 0 0 8 0 Ab b r e v i a t i o n s MW = M u d W e i g h t V I S = F u n n e l V i s c o s i t y P V = P l a s t i c V i s c o s i t y Y P = Y i e l d P o i n t Ge l s = G e l S t r e n g t h F L = F i l t r a t e L o ss F C = F i l t e r C a k e S o l s = S o l i d s O/ W = O i l t o W a t e r r a t i o S d = S a n d c o n t e n t C l = C h l o r i d e s C a = H a r d n e s s BCU 12A 23 5 DAILY REPORTS HilcorpAlaskaLLC DAILY WELLSITE REPORT BCU-12A REPORT FOR: J grubb / J Greco DATE: June 28, 2014 DEPTH 4791' PRESENT OPERATION: POOH TIME: 2359 YESTERDAY 4791' 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH N/A BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED N/A 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 FLUIDS REPORT DEPTH MD/ TVD MW VIS PV YP Gels FL FC SOL NAF/W SD MBT pH ALK Cl- Ca+ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 240u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A PRESENT LITHOLOGY N/A DAILY ACTIVITY SUMMARY Finished testing BOPs. Prep to RIH. M/U milling BHA and RIH picking up DP. Tag BP @ 4,791'. CBU w/ water. Displaced to 6% KCL/PHPA mud. Performed casing test to 3,000 PSI: passed. POOH at time of report. CANRIG PERSONNEL ON BOARD: 3 __DAILY COST: $ 2690.00 REPORT BY: D Muller HilcorpAlaskaLLC DAILY WELLSITE REPORT BCU-12A REPORT FOR: J Grubb / J Greco DATE: Jun 29, 2014 DEPTH 4809' PRESENT OPERATION: POOH TIME: 23:59 YESTERDAY 4791' 24 HOUR FOOTAGE 18' CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5 BHC mill bit 4791 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 31.5 @ 4805' 7.3 @ 4809' 18.2 7.29742 FT/HR SURFACE TORQUE 6406 @ 4796' 4940 @ 4801' 5819.6 5273.93994 FT-LBS WEIGHT ON BIT 0 @ 4809' 0 @ 4809' 0.0 0.00000 KLBS ROTARY RPM 88 @ 4797' 82 @ 4791' 90.7 85.05000 RPM PUMP PRESSURE 1062 @ 4797' 1010 @ 4807' 1095.1 1024.44995 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 4810/4715 MW 9.0 VIS 57@80 PV 12@80 YP 20 Gels 7/11/15 FL 5.9 FC 1/2 SOL 2.3 NAF/W 0.0/95.1 SD MBT pH 9.1@80 ALK 0.25 Cl- 31500 Ca+ 140 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 16 @ 4808' 10 @ 4799.00000 13.4 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 3179 @ 4809' 0 @ 4809' 3179 CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A PRESENT LITHOLOGY N/A DAILY ACTIVITY SUMMARY Continue TOOH to surface. M/U millingBHA and whipstock. RIH T/ 4,754',orient whipstock, set anchor @ 4,769'.Milled out window F/ 4,769' - T/ 4,810'.Pumped hi-vis sweep, no increase incuttings. Performed FIT to 11.0 ppgEMW. TOW @ 4,769', BOW @ 4,786'.262.5 lbs metal cuttings recovered.Pumped 10.5 ppg dry job and TOOH F/4,760' - T/ 3,963'. TOOH at time of report.. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $ 2690.00 REPORT BY: Bomar; Muller HilcorpAlaskaLLC DAILY WELLSITE REPORT BCU-12A REPORT FOR: J. GRECCO, J. GRUBB DATE: Jun 30, 2014 DEPTH 5079' PRESENT OPERATION: DRILLING AHEAD TIME: 2359 YESTERDAY 4810' 24 HOUR FOOTAGE 269' CASING INFORMATION 9.625" @ 4769' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" BHC mill bit 4791' 4810' 19' SWAP BITS 2 7.875" Haliburton MM55 12460651 5x12 4810' New DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 188.5 @ 5076 13.3 @ 5025 97.0 18.21695 FT/HR SURFACE TORQUE 5483 @ 5035 4090 @ 4831 3138.0 5451.68994 FT-LBS WEIGHT ON BIT 11 @ 4888 1 @ 4831 5.8 5.40000 KLBS ROTARY RPM 38 @ 4978 5 @ 4879 20.9 37.25000 RPM PUMP PRESSURE 1546 @ 5035 1321 @ 5065 1434.4 1438.45996 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 5069/4958 MW 9 @ 78 VIS 55 PV 11 YP 20 Gels 7/10/13 FL 5.4 FC 1/2 SOL 2.3 NAF/W 0.0/95.0 SD MBT pH 9.7@78 ALK .20 Cl- 32500 Ca+ 80 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 31 @ 4959' 1 @ 4816 14.1' TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 6830 @ 4961' 223 @ 4816 2822.7 CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND 25 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY STERLING FORMATION PRESENT LITHOLOGY TUFFACEOUS SILTSTONE 80%; TUFFACEOUS CLAYSTONE 20% DAILY ACTIVITY SUMMARY TOOH; L/D MILLING ASSMBLY; M/U BHA ; RIH P/U DP T/4810'; DRILLING AHEAD. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $ 2690.00 REPORT BY: BOMAR HilcorpAlaskaLLC DAILY WELLSITE REPORT BCU-12A REPORT FOR: J GRECCO; J GRUBB DATE: Jul 01, 2014 DEPTH 6088' PRESENT OPERATION: DRILLING AHEAD TIME: 23:59 YESTERDAY 5079' 24 HOUR FOOTAGE 1009 CASING INFORMATION 9.625" @ 4769' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 2 7.875" Haliburton MM55 12460651 5x12 4810' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 263.6 @ 5324' 1.2 @ 5682' 116.6 78.99908 FT/HR SURFACE TORQUE 7115 @ 5923' 81 @ 5446' 5215.2 6819.81006 FT-LBS WEIGHT ON BIT 20 @ 5948' 1 @ 5108' 7.9 11.95 KLBS ROTARY RPM 80 @ 5968' 1 @ 5948' 61.9 78.11 RPM PUMP PRESSURE 1957 @ 6067' 1295 @ 5101' 1585.4 1913.32996 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 6114'/5954' MW 9.05 VIS 61 PV 13@120 YP 23 Gels 7/11/16 FL 5.6 FC 1/2 SOL 2.8 NAF/W 0.0/94.6 SD .15 MBT 1 pH 8.8 ALK .2 Cl- 31000 Ca+ 160 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 351 @ 5215' 2 @ 5949' 61.5 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 87482 @ 5215' 745 @ 5949' 11950.9 CONNECTION GAS HIGH ETHANE (C-2) 127 @ 5216' 0 @ 5921' 9.0 CONNECTION GAS: AVG PROPANE (C-3) 14 @ 5964' 0 @ 5921' 0.2 CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY STERLING PRESENT LITHOLOGY TUFFACEOUS SILTSTONE/SANDSTONE/SAND/MICROFRAGMENTS COAL DAILY ACTIVITY SUMMARY Continued drilling ahead F/5,069'T/5,301', appeared to have lostreturns. P/U and killed pumps, well heldstatic with no losses;troubleshoot/fixed flow paddle.Continued drilling ahead T/5,311',pumped hi-vis sweep; 100% increasein cuttings mostly clay. Continueddrilling T/5600' and pumped another 20bbl Hi-Vis sweep; 100% increase incuttings. Continued drilling aheadT/5997' and pumped another sweep-100% increase in cuttings at shakers.All cuttings from sweeps consisting ofpea-sized clay and fine coal with anoccasional sliver of coal. Wiper tripped. Now drilling ahead at time of report. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $ 3180 REPORT BY: BOMAR HilcorpAlaskaLLC Beaver Creek Unit DAILY WELLSITE REPORT BCU-12A REPORT FOR: J GRECCO AND J GRUBB DATE: Jul 02, 2014 DEPTH 6940' PRESENT OPERATION: DRILLING AHEAD TIME: 23:59 YESTERDAY 6088' 24 HOUR FOOTAGE 852' CASING INFORMATION 9.625 @4769' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 2 7.875" HALLIB URTON MM55 12460651 5 X 12 4810' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 142.2 @ 6569' 0.6 @ 6524' 74.2 22.7' FT/HR SURFACE TORQUE 8306 @ 6662' 707 @ 6756' 6093 7432.5' FT-LBS WEIGHT ON BIT 27 @ 6586' 0 @ 6722' 9.4 4.9' KLBS ROTARY RPM 89 @ 6732' 0 @ 6756' 61.2 60.4' RPM PUMP PRESSURE 2170 @ 6818' 55 @ 6802' 1849.6 1960.52 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 6940'/6744' MW 9.1 VIS 61 PV 16 YP 20 Gels 6/9/12 FL 4.4 FC 1/2 SOL 3.4 NAF/W 2/92 SD .15 MBT 1.5 pH 9.3 ALK .4 Cl- 32000 Ca+ 80 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 726 @ 6113.00000 4 @ 6887 68.4 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 174763 @ 6113 1369 @ 6739 13054.1 CONNECTION GAS HIGH n/a ETHANE (C-2) 565 @ 6113 1 @ 6259 15.9 CONNECTION GAS: AVG n/a PROPANE (C-3) 32 @ 6113 0 @ 6152 0.5 CONNECTION GAS: CURRENT n/a BUTANE (C-4) 17 @ 6677 0 @ 6521 1.1 CURRENT AVG BACKGROUND 20 PENTANE (C-5) 28 @ 6517 0 @ 6554 1.9 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY STERLING PRESENT LITHOLOGY TUFFACEOUS SANDSTONE/SILTSTONE/SAND/ASH/MICROFRAGMENTS COAL DAILY ACTIVITY SUMMARY Continued drilling ahead T/6336' and pumped a 20 bbl Hi-Vis sweep; observed a 100% increase in cuttings (mostly clay with minimal coal). Drilled ahead T/6500' and pumped 20 bbl Hi-Vis sweep- 25% increase in cuttings. Having issues sliding. Drilled ahead T/6553' and pumped a 20 bbl, 10 ppb WALLNUT/CON DET/Hi- Vis sweep as we attempted to slide- no increase in cuttings at shakers and some help with sliding. Decision made at 6614' to mix WALL-NUT at 10 minutes a sack into suction pit while sliding- did not help sliding. Decision made to add 2% lubes to the mud. Drilled T/6870' and pumped a 20 bbl Hi-Vis sweep; observed a 25% increase in cuttings (mostly clay and sands). Continued drilling ahead @ time of reporting. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: 3180 REPORT BY: BOMAR HilcorpAlaskaLLC Beaver Creek Unit DAILY WELLSITE REPORT BCU-12A REPORT FOR: J GRECCO, J GRUBB DATE: Jul 03, 2014 DEPTH 7625' PRESENT OPERATION: DRILLING AHEAD TIME: 23:59 YESTERDAY 6940' 24 HOUR FOOTAGE 685' CASING INFORMATION 9.625 @4769' 4810' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7445.53 12.58 123.10 7231.97 7506.39 12.32 123.37 7291.40 7569.03 11.31 120.50 7352.71 7631.92 11.17 120.54 7414.39 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 2 7.875" HALLIB URTON MM55 12460651 5 X 12 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 144.0 @ 7173' 2.3 @ 7262' 49.2 66.6 FT/HR SURFACE TORQUE 8764 @ 7558' 7238 @ 6988' 7628.2 8693.26 FT-LBS WEIGHT ON BIT 145 @ 7608' 0 @ 7168' 8.2 5.24 KLBS ROTARY RPM 88 @ 7183' 54 @ 7415' 65.7 69.13 RPM PUMP PRESSURE 2174 @ 7613' 1720 @ 7421' 1890.3 2166.24 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 7608/7390 MW 9.1 VIS 55 PV 13 YP 19 Gels 6/8/11 FL 4.5 FC 1/2 SOL 3 NAF/W 1/93.2 SD 0.15 MBT 1.5 pH 9.3 ALK 0.45 Cl- 35000 Ca+ 80 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 94 @ 7240 1 @ 7436.00000 17.4 TRIP GAS CUTTING GAS 0 @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 28895 @ 7240 385 @ 7436 4225.8 CONNECTION GAS HIGH ETHANE (C-2) 21 @ 7240 0 @ 7269 0.3 CONNECTION GAS: AVG PROPANE (C-3) 12 @ 7184 0 @ 7220 0.6 CONNECTION GAS: CURRENT BUTANE (C-4) 19 @ 7269 0 @ 7189 1.2 CURRENT AVG BACKGROUND 20u PENTANE (C-5) 6 @ 7157 0 @ 7128 0.2 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY BELUGA PRESENT LITHOLOGY TUFFACEOUS SILTSTONE 40% SILTSTONE 30% TUFFACEOUS SANDSTONE 20% SANDSTONE 10% DAILY ACTIVITY SUMMARY Drilled ahead T/6988 and pumped a 20 bbl Hi-Vis sweep; observed a 25% increase in cuttings. Cleaned up the hole and Wiper tripped T/6025 – no issues. Singled back to bottom with no issues and no fill. Drilled ahead T/7234' and Pumped 20 bbl Hi-Vis sweep- no increase in cuttings. Continued drilling ahead T/7483' and pumped a 20 bbl Hi-Vis sweep; observed a 10% increase in cuttings. Drilling ahead at time of reporting. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $3180 REPORT BY: BOMAR HilcorpAlaskaLLC Beaver Creek Unit DAILY WELLSITE REPORT BCU-12A REPORT FOR: J Grecco, J Grubb DATE: Jul 04, 2014 DEPTH 8114' PRESENT OPERATION: Drilling Ahead TIME: 23:59 YESTERDAY 7625' 24 HOUR FOOTAGE 489' CASING INFORMATION 7.625 @ 4769'810' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 2 7.875" Halliburton MM55 12460651 5 X 12 4810' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 108.7 @ 7738' 0.9 @ 7861' 41.1' 23.96' FT/HR SURFACE TORQUE 9201 @ 7695' 568 @ 7861' 7040.4 0.0 FT-LBS WEIGHT ON BIT 37 @ 7678' 0 @ 7946' 4.8 10.57 KLBS ROTARY RPM 88 @ 7909' 2 @ 7930' 61.8 0.00 RPM PUMP PRESSURE 2258 @ 7967' 1721 @ 7795' 2043.7 1923.2 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 8114'/7892' MW 9.1 VIS 56 PV 16 YP 22 Gels 6/9/12 FL 4 FC 1/2 SOL 3.3 NAF/W 2/92.1 SD 0.05 MBT 2 pH 8.5 ALK 1 Cl- 32000 Ca+ 60 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 133 @ 8026.00000 1 @ 7866.00000 26.4 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 62805 @ 7735' 605 @ 7866' 8174u CONNECTION GAS HIGH ETHANE (C-2) 32 @ 7738' 0 @ 7784' 1.0 CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND 22u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga PRESENT LITHOLOGY Tuffaceous Siltstone; Tuffaceous Sandstone; Sparse Tuffaceous Claystones and Siltstone; Sparse Clast and Coal Microfragments DAILY ACTIVITY SUMMARY Continued drilling ahead T/7740' and pumped a 20 bbl Hi-Vis sweep; observed a 25% increase in cuttings (clay and sands). Increased lubeconcentration to help with sliding and adding additional lube prior to sliding as needed - continuing to drill ahead at time of reporting. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $3180 REPORT BY: Bomar HilcorpAlaskaLLC Beaver Creek Unit DAILY WELLSITE REPORT BCU-12A REPORT FOR: J Grecco and J Grubb DATE: Jul 05, 2014 DEPTH 8789' PRESENT OPERATION: Drilling Ahead TIME: 23:59 YESTERDAY 8114' 24 HOUR FOOTAGE 675 CASING INFORMATION 9.625 @ 4,769 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 2 7.875 Halliburton / HDBS MM55 5x12 4810' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 103.4 @ 8710' 2.2 @ 8215' 45.6 28.56' FT/HR SURFACE TORQUE 10181 @ 8752' 248 @ 8123' 8856.1 9158.09' FT-LBS WEIGHT ON BIT 147 @ 8785' 0 @ 8180' 10.5 0.0 KLBS ROTARY RPM 88 @ 8726' 0 @ 8123' 76.9 88.07 RPM PUMP PRESSURE 2293 @ 8613' 1861 @ 8177' 2102.2 2182.24 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 8,789 / 8,568 MW 9.20@96 VIS 56 PV 16 YP 20 Gels 6/8/11 FL 3.5 FC 1/2 SOL 4 NAF/W 0.5/92.9 SD 0.05 MBT 2 pH 8.5 ALK 0.25 Cl- 32000 Ca+ 60 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 90 @ 8406' 3 @ 8619' 22.3 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 35840 @ 8405' 1600 @ 8167' 5220.1 CONNECTION GAS HIGH ETHANE (C-2) 17 @ 8405' 0 @ 8440' 0.3 CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) 16 @ 8405' 0 @ 8521' 0.5 CURRENT AVG BACKGROUND 13 PENTANE (C-5) 29 @ 8555' 0 @ 8284' 1.4 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga, approaching Tyonek PRESENT LITHOLOGY Tuffaceous Siltstone/Sandstone/Claystone; Siltstone/Claystone; Carbonaceous Shale; Sparse Coal DAILY ACTIVITY SUMMARY Drilled ahead T/8167' and pumped a 20 bbl Hi-Vis sweep prior to wiper tripping; StoS showed a 50% increase in cuttings. Short-tripped T/7046' without issue. Ran back to bottom with no issues and no fill. Picked up drilling ahead T/8473' and pumped a 20 bbl Hi-Vis sweep- 25% increase in cuttings at shakers (mostly small clay with a little coal). Continued drilling ahead T/8788' and pumped a 20 bbl Hi-Vis sweep; waiting on sweep to come back at time of reporting. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $3180 REPORT BY: BOMAR HilcorpAlaskaLLC Beaver Creek Unit DAILY WELLSITE REPORT BCU-12A REPORT FOR: J Grubb and J Grecco DATE: Jul 06, 2014 DEPTH 9485' PRESENT OPERATION: Drilling Ahead TIME: 23:59 YESTERDAY 8789' 24 HOUR FOOTAGE 696' CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 2 7.875 Halliburton / HDBS MM55 5x12 4810' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 152.8 @ 9420' 4.8 @ 9310' 48.2 88.5 FT/HR SURFACE TORQUE 11248 @ 9398' 9050 @ 9102' 9711.5 10697.7 FT-LBS WEIGHT ON BIT 153 @ 9476' 2 @ 9068' 5.7 8.5 KLBS ROTARY RPM 88 @ 9097' 33 @ 9476' 81.2 81.6 RPM PUMP PRESSURE 2407 @ 9414' 1807 @ 9035' 2128.7 2309.2 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 9,485 / 9,263 MW 9.3@98 VIS 51 PV 16 YP 21 Gels 6/8/11 FL 3.6 FC 1/2 SOL 4.6 NAF/W 0.1/92.6 SD MBT 2.5 pH 8.5 ALK .2 Cl- 33000 Ca+ 80 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1052 @ 8971 8 @ 9175 114.8 TRIP GAS CUTTING GAS @ @ WIPER GAS 900u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 507955 @ 9035 1346 @ 9175 26554.0 CONNECTION GAS HIGH 726u ETHANE (C-2) 956 @ 9035 0 @ 8847 34.5 CONNECTION GAS: AVG 350u PROPANE (C-3) 442 @ 9035 0 @ 9364 12.6 CONNECTION GAS: CURRENT 163u BUTANE (C-4) 63 @ 9035 0 @ 8847 2.1 CURRENT AVG BACKGROUND 35u PENTANE (C-5) 13 @ 9115 0 @ 9237 1.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY Tuffaceous siltstone; tuffaceous sandstone; carbonaceous shale; occasional coals. DAILY ACTIVITY SUMMARY Pumped a 20 bbl Hi-Vis sweep at 8788' and observed a 100% increase in cuttings (clays and sands). Continued drilling ahead T/9034' and pumped another 20 bbl Hi-Vis sweep- 50% increase in cuttings (mostly small clay with some fine coal). Drilled ahead CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $3180 REPORT BY: Bomar HilcorpAlaskaLLC Beaver Creek Unit DAILY WELLSITE REPORT BCU-12A REPORT FOR: J SWEETSIR; J GRECCO DATE: Jul 07, 2014 DEPTH 9800' PRESENT OPERATION: Circulating hi-vis sweep TIME: 23:59 YESTERDAY 9485' 24 HOUR FOOTAGE 315' CASING INFORMATION 9.625 @ 4,769 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9615.22' 2.32 104.73 9393.59' 9679.48' 2.19 108.81 9457.8' 9740.15' 2.01 119.73 9518.43' 9761.76' 2.45 121.18 9540.02' 9800' 2.45 121.18 9578.23' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 2 7.875 Halliburton / HDBS Mn 5x12 4810' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 121.0 @ 9691' 2.7 @ 9738' 61.5 90.457 FT/HR SURFACE TORQUE 12324 @ 9638' 10149 @ 9568' 10157.8 11390.58 FT-LBS WEIGHT ON BIT 162 @ 9780' 3 @ 9658' 13.1 22.27 KLBS ROTARY RPM 88 @ 9783' 75 @ 9548' 74.8 77.11 RPM PUMP PRESSURE 2418 @ 9692' 2080 @ 9497' 2091.7 2341.73 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 9,800 / 9,578 MW 9.30@88 VIS 53 PV 15 YP 20 Gels 6/9/12 FL 3.3 FC 1/2 SOL 4.6 NAF/W 0.0/92.7 SD MBT 2.5 pH 9.2 ALK 0.4 Cl- 33000 Ca+ 80 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 492 @ 9533.00000 24 @ 9725.00000 66.0 TRIP GAS CUTTING GAS @ @ WIPER GAS 900 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 77144 @ 9533' 4064 @ 9800' 16361.4 CONNECTION GAS HIGH 726 ETHANE (C-2) 127 @ 9533' 0 @ 9799' 22.1 CONNECTION GAS: AVG 266 PROPANE (C-3) 40 @ 9533' 0 @ 9703' 4.9 CONNECTION GAS: CURRENT BUTANE (C-4) 8 @ 9533' 0 @ 9562' 0.1 CURRENT AVG BACKGROUND 210 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY TD at 9800'. Tuffaceous sandstone, quartz sand, coal, and carbonaceous shale. DAILY ACTIVITY SUMMARY Continued drilling ahead T/9657' and pumped a 20 bbl Hi-Vis sweep; observed a 50% increase in cuttings (fine clay with sands and an increase in coal (50%)). Drilled ahead to TD @ 9800'. Pumped 20 bbl Hi-Vis/WALL-NUT sweep- no increase in cuttings at shaker and sweep returned on time. Short-tripped to window. Had several tight spots, but were able to work through without CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $3180 REPORT BY: BOMAR HilcorpAlaskaLLC Beaver Creek Unit DAILY WELLSITE REPORT BCU-12A REPORT FOR: J SWEETSIR; J GRECCO DATE: Jul 08, 2014 DEPTH 9800' PRESENT OPERATION: POOH / MAD pass TIME: 23:59 YESTERDAY 9800' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625 @ 4,769 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9615.22' 2.32 104.73 9393.59' 9679.48' 2.19 108.81 9457.8' 9740.15' 2.01 119.73 9518.43' 9761.76' 2.45 121.18 9540.02' 9800' 2.45 121.18 9578.23' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 2 7.875 Halliburton / HDBS Mn 5x12 4810' 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 FLUIDS REPORT DEPTH MD/ TVD 9,800 / 9,578 MW 9.45 @ 80 VIS 54 PV 15 YP 21 Gels 6/10/15 FL 3.3 FC 1/2 SOL 5.8 NAF/W 0.0/91.7 SD MBT 3.7 pH 9.0 ALK 0.30 Cl- 31000 Ca+ 80 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 854 @ 9760' @ 23:45 Off bottom gas @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND pumps off PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY TD at 9800'. Tuffaceous sandstone, quartz sand, coal, and carbonaceous shale. DAILY ACTIVITY SUMMARY Pumped a 20 bbl Hi-Vis Walnut Sweep and observed a 150% increase in cuttings (large increase in BB sized coals and golf ball sized claystone). Pumped another 20 bbl Hi-Vis sweep 4400 strokes behind the first to help clean the hole again and observed a 50% increase in cuttings (coal is BB sized with sands). Decision was made to TOOH and mad pass F/9564' T/5000' currently at 5458' at time of reporting. Sample catchers released CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $3180 REPORT BY: D Muller HilcorpAlaskaLLC Beaver Creek Unit DAILY WELLSITE REPORT BCU-12A REPORT FOR: J SWEETSIR; J GRECCO DATE: Jul 09, 2014 DEPTH 9800' PRESENT OPERATION: POOH TIME: 23:59 YESTERDAY 9800' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625 @ 4,769 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9615.22' 2.32 104.73 9393.59' 9679.48' 2.19 108.81 9457.8' 9740.15' 2.01 119.73 9518.43' 9761.76' 2.45 121.18 9540.02' 9800' 2.45 121.18 9578.23' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 2 7.875 Halliburton / HDBS Mn 5x12 4810' 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 FLUIDS REPORT DEPTH MD/ TVD 9,800 / 9,578 MW 9.5 @ 80 VIS 52 PV 14 YP 19 Gels 5/9/12 FL 3.3 FC 1/2 SOL 6.1 NAF/W 0.0/91.5 SD MBT 4.0 pH 8.2 ALK 0.25 Cl- 30000 Ca+ 80 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS 1120 8137' @ 0500 hrs CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND pumps off PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY TD at 9800'. Tuffaceous sandstone, quartz sand, coal, and carbonaceous shale. DAILY ACTIVITY SUMMARY Mad passed T/5027' and flow checked; no flow/losses. TIH on elevators T/8127' and circulated out 1106 units of gas. TIH T/9485' and washed to bottom; encountered 16' of fill. Pumped a 20 bbl Hi-Vis pill; observed a 100% increase in cuttings. Decision was made to POOH - pulled 5 stands and flow checked, hole was static. Pumped a 20 bbl dry job and started POOH while L/D DP sideways; L/D DP sideways at time of reporting. CANRIG PERSONNEL ON BOARD: 3 __DAILY COST: $2200 REPORT BY: D Muller HilcorpAlaskaLLC Beaver Creek Unit DAILY WELLSITE REPORT BCU-12A REPORT FOR: J SWEETSIR; J GRECCO DATE: Jul 10, 2014 DEPTH 9800' PRESENT OPERATION: RIH with casing TIME: 23:59 YESTERDAY 9800' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625 @ 4,769 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9615.22' 2.32 104.73 9393.59' 9679.48' 2.19 108.81 9457.8' 9740.15' 2.01 119.73 9518.43' 9761.76' 2.45 121.18 9540.02' 9800' 2.45 121.18 9578.23' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 2 7.875 Halliburton / HDBS Mn 5x12 4810' 9800' 4990' 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 FLUIDS REPORT DEPTH MD/ TVD 9,800 / 9,578 MW 9.45 @ 80 VIS 50 PV 13 YP 19 Gels 5/8/10 FL 3.8 FC 1/2 SOL 6.0 NAF/W 0.0/91.6 SD MBT 4.0 pH 8.3 ALK 0.3 Cl- 30000 Ca+ 80 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS 1120 8137' @ 0500 hrs CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND pumps off PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY TD at 9800'. Tuffaceous sandstone, quartz sand, coal, and carbonaceous shale. DAILY ACTIVITY SUMMARY Finished LD DP and MWD tools. Changed upper rams for running casing and tested/troubleshoot; RIH w/ 5" casing at time of reporting. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $2200 REPORT BY: D Muller HilcorpAlaskaLLC Beaver Creek DAILY WELLSITE REPORT BCU-12A REPORT FOR: Sweetsir; Pederson DATE: Jul 07, 2014 DEPTH 9800' PRESENT OPERATION: Cementing Casing TIME: 2359 YESTERDAY 9800' 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625 @ 4769' 5" @ 9759.8' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED Open Ended 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 FLUIDS REPORT DEPTH MD/ TVD 9,800 / 9,578 MW 9.5 VIS 50 PV 14 YP 19 Gels 5/8/10 FL 3.8 FC 1/2 SOL 6 NAF/W 0.0/91.6 SD 6.39 MBT 4.2 pH 8.2 ALK 0.25/2.40 Cl- 29000 Ca+ 80 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 1318 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finished LD DP and MWD tools. Changed upper rams for running casing and tested/troubleshoot; RIH w/5" casing at time of reporting. CANRIG PERSONNEL ON BOARD: 2 __DAILY COST: $2200 REPORT BY: BOMAR
