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Home My WebLink About214-060Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/23/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221123 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PAXTON 6 50133207070000 222054 8/1/2022 Yellowjacket PERF BCU-7A 50133202840100 214060 8/2/2022 Yellowjacket GPT-PERF KBU 43-07Y 50133206250000 214019 8/3/2022 Yellowjacket PERF KBU 22-06Y 50133206500000 215044 8/4/2022 Yellowjacket GPT-PERF SRU 32A-33 50133101640100 191014 8/21/2022 Yellowjacket GPT-PERF HVB 16A 50231200400100 222070 8/23/2022 Yellowjacket PERF PAXTON 10 50133206910000 220064 8/26/2022 Yellowjacket PERF HVB-16A 50231200400100 222070 8/27/2022 Yellowjacket PERF PAXTON 10 50133206910000 220064 8/29/2022 Yellowjacket PERF KALOTSA 4 50133206650000 217063 9/1/2022 Yellowjacket GPT-PERF KALOTSA 4 50133206650000 217063 9/6/2022 Yellowjacket PERF-GPT Please include current contact information if different from above. By Meredith Guhl at 9:26 am, Nov 29, 2022 T37305 T37306 T37306 T37307 T37307 T37308 T37309 T37310 T37311 T37311 T37312 BCU-7A 50133202840100 214060 8/2/2022 Yellowjacket GPT-PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.29 09:43:24 -09'00' Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/22/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221122-1 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# SRU 213-15 50133206520000 215100 6/24/2022 Yellowjacket PERF KBU 33-06X 50133205290000 203183 6/26/2022 Yellowjacket PERF BCU 7A 50133202840100 214060 6/28/2022 Yellowjacket GPT-PERF END 3-17F 50029219460600 203216 7/2/2022 Yellowjacket PERF-RETAINER KBU 32-08 50133206240000 214014 7/12/2022 Yellowjacket PERF BCU 7A 50133202840100 214060 7/15/2022 Yellowjacket GPT-PERF SRU 213-15 50133206520000 215100 7/19/2022 Yellowjacket GPT-PLUG MPU I-17 50029232120000 204098 7/19/2022 Yellowjacket TUBING CUT CLU 05RD 50133204740100 215160 7/21/2022 Yellowjacket PLUG CLU 10 50133205530000 205106 7/21/2022 Yellowjacket RCT-JET CUT SRU 213-15 50133206520000 215100 7/22/2022 Yellowjacket PERF Please include current contact information if different from above. By Meredith Guhl at 8:52 am, Nov 23, 2022 T37295 T37295 T37295 T37296 T37297 T37297 T37298 T37299 T37300 T37301 T37302 BCU 7A 50133202840100 214060 6/28/2022 Yellowjacket GPT-PERF BCU 7A 50133202840100 214060 7/15/2022 Yellowjacket GPT-PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.23 09:08:15 -09'00' 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: 09/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220928 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 07A 501332028401 214060 7/12/2022 AK E-Line CIBP GPT BCU 18RD 501332058401 222033 7/13/2022 AK E-Line Perf BCU 18RD 501332058401 222033 7/16/2022 AK E-Line GPT Perf BCU 18RD 501332058401 222033 7/23/2022 AK E-Line GPT CIBP Perf BRU 212-24 502832003700 172015 6/27/2022 AK E-Line CBL BRU 212-24 502832003700 172015 7/5/2022 AK E-Line CIBP CBL TBG END 1-45 500292199100 189124 7/23/2022 AK E-Line Perf END 4-02 500292178900 188022 7/21/2022 AK E-Line Perf HVB B-16 502312004000 212133 6/23/2022 AK E-Line Drift, Plug, Cement IRU 241-01 502832018400 221076 8/5/2022 AK E-Line CBL IRU 241-01 502832018400 221076 8/9/2022 AK E-Line Perf Kalotsa 6 501332068500 219114 7/16/2022 AK E-Line Perf KTU 24-06H 501332049000 199073 7/15/2022 AK E-Line GPT Perf MPU S-34 500292317100 203130 7/5/2022 AK E-Line Drift PBU F-26C 500292198703 213045 8/4/2022 AK E-Line Patch/LDL SRU 213-15 501332065200 215100 8/3/2022 AK E-Line GPT Perf Please include current contact information if different from above. T37068 T37069 T37069 T37069 T37070 T37070 T37071 T37072 T37073 T37081 T37081 T37074 T37075 T37076 T37077 T37078 BCU 07A 501332028401 214060 7/12/2022 AK E-Line CIBP GPT Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.30 12:44:16 -08'00' 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:Ryan Rupert; Roby, David S (OGC) Cc:Donna Ambruz Subject:RE: BCU-07A AOGCC 10-403 322-308 PTD 214-060 Approved 05-20-22 Date:Wednesday, July 27, 2022 9:08:00 AM Ryan, Approval granted to add the expanded sterling perf interval proposed in your email below. Regards 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: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Wednesday, July 27, 2022 8:32 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: FW: BCU-07A AOGCC 10-403 322-308 PTD 214-060 Approved 05-20-22 Gents- Apologies for the late notice, but Hilcorp would like to expand the Sterling interval for perforating in BCU-07A. Please see below, and let me know if this is acceptable. Thank you Sundried Sterling Interval : ±5,319’ – ±5,801’ MD (±4,878’ – ±5,273’ TVD) Proposed expanded Sterling Interval: ±5,319’ – ±6,460’ MD (±4,878’ – ±5,813’ TVD) . Currently the well has a CIBP set at 6547’ MD and has 35’ of cement dump bailed on top of it, fully abandoning the Beluga Pool. Ryan Rupert Kenai Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: Donna Ambruz <dambruz@hilcorp.com> Sent: Friday, May 20, 2022 2:13 PM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Vanessa Hughes <vhughes@hilcorp.com> Subject: BCU-07A AOGCC 10-403 322-308 PTD 214-060 Approved 05-20-22 FYI – Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. 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By Anne Prysunka at 2:34 pm, Aug 23, 2022 Kaitlyn Barcelona Hilcorp Alaska, 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 or FAX to 907 564-4422 Received By: Date: Date: 07/11/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes BCU 18RD 50133205840100 222033 6/11/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/18/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/7/2022 Yellowjacket GPT-PLUG + Report BCU 24 50133206390000 214112 6/16/2022 Halliburton PPROF BCU 24 50133206390000 214112 5/23/2022 Yellowjacket GPT-PERF + Report BCU 24 50133206390000 214112 5/26/2022 Yellowjacket GPT-PERF + Report BCU 7A 50133202840100 214060 6/21/2022 Yellowjacket CBL BCU 7A 50133202840100 214060 6/15/2022 Yellowjacket GAMMA RAY + Report BRU 232-26 50283200770000 184138 5/25/2022 Yellowjacket CBL CLU 01RD 50133203230100 203129 5/19/2022 Yellowjacket PERF + Report CLU 01RD 50133203230100 203129 5/24/2022 Yellowjacket PERF + Report CLU 09 50133205440000 204161 5/27/2022 Yellowjacket PERF + Report CLU-1RD 50133203230100 203129 5/28/2022 Halliburton PPROF + Report END 1-17A 50029221000100 196199 5/26/2022 Halliburton LDL END 1-45 50029219910000 189124 5/23/2022 Halliburton LDL + Report END 3-17F 50029219460600 203216 6/15/2022 AK E-Line PLUG CUT FALLS CREEK 3 50133205240000 203102 6/4/2022 Yellowjacket PERF + Report HVB B-16 50231200400000 212133 6/14/2022 AK E-Line CIBP KALOTSA 1 50133206570000 216132 7/7/2022 Yellowjacket PERF + Report KBU 11-07 50133205560000 205165 6/16/2022 Yellowjacket GPT-PERF + Report KBU 11-07 50133205560000 205165 6/20/2022 Yellowjacket GPT-PERF + Report KBU 33-06X 50133205290000 203183 6/22/2022 Yellowjacket CBL MPU B-28 50029235660000 216027 5/27/2022 Halliburton LDL MPU B-28 50029235660000 216027 5/27/2022 Halliburton MFC + Report MPU B-30 50029235710000 216153 5/18/2022 Halliburton PERF MPU E-06 50029221540000 191048 5/28/2022 Halliburton MFC + Report Kaitlyn Barcelona Hilcorp Alaska, 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 or FAX to 907 564-4422 Received By: Date: MPU E-35 50029236150000 218152 6/15/2022 Halliburton MFC + Report MPU L-50 50029235550000 215132 6/24/2022 Read COIL FLAG PAXTON 10 50133206910000 220064 5/27/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton RBT PBU GNI-03 50029228200000 197189 6/25/2022 Read CALIPER PBU GNI-03 50029228200000 197189 6/25/2022 Read TEMP-PRESS PBU K-01 50029209980000 183121 6/21/2022 Halliburton PPROF + Report PBU M-13A 50029205220100 201165 5/27/2022 Halliburton TMD3D-WFL + Report PBU NGI-05 50029201960000 176014 6/7/2022 Halliburton CAST PBU W-01A 50029218660100 203176 6/8/2022 Halliburton RBT SRU 241-33 50133206630000 217047 6/13/2022 Yellowjacket PERF SRU 241-33B 50133206960000 221053 5/25/2022 Halliburton TEMP-PRESS SRU 32A-33 50133101640100 191014 6/11/2022 AK E-Line PPROF Please include current contact information if different from above. BCU 18RD PTD:222-033 T36747 BCU 24 PTD:214-112 T36748 BCU 7A PTD:214-060 T36749 BRU 232-26 PTD:184-138 T36750 CLU 01RD PTD:203-129 T36751 CLU 09 PTD: 204-161 T36752 CLU1RD PTD:203-129 T36751 END 1-17A PTD:196-199 T36753 END 1-45 PTD:189-124 T36754 END 3-17F PTD:203-216 T36755 Falls Creek 3 PTD:203-102 T36756 HVB B-16 PTD:212-133 T36757 Kalosta 1 PTD:216-132 T36758 KBU 11-7 PTD:205-165 T36759 KBU 33-06X PTD:203-183 T36760 MPU B-28 PTD:216-027 T36761 MPU B-30 PTD:216-153 T36762 MPU E-06 PTD: 191-048 T36763 MPU E-35 PTD:218-152 T36764 MPU L-50 PTD:215-132 T36765 Paxton 10 PTD:220-064 T36766 PBU C-24B PTD:212-063 T36767 PBU GNI-03 PTD:197-189 T36768 PBU K-01 PTD:183-121 T36769 PBU M-13A PTD:201-165 T36770 PBU NGI-05 PTD:176-014 T36771 PBU W-01A PTD:203-176 T36772 SRU 241-33 PTD:217-047 T36773 SRU 241-33B PTD:221-053 T36774 SRU 32A-33 PTD: 191-014 T36775 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.12 12:56:51 -08'00' 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW:HGQHVGD\-XQH$0 7RHGKRRWHU#JPDLOFRP &F5HJJ-DPHV%2*& 6XEMHFW5(+LOFRUS5LJWHVWUHSRUW $WWDFKPHQWV+LOFRUS5HYLVHG[OV[ )ROORZ8S)ODJ)ROORZXS )ODJ6WDWXV)ODJJHG Ě͕ /ΖǀĞĂƚƚĂĐŚĞĚƚŚĞƌĞǀŝƐĞĚƌĞƉŽƌƚǁŝƚŚƚŚĞƐĞĐŚĂŶŐĞƐ͘WůĞĂƐĞƵƉĚĂƚĞǇŽƵƌĐŽƉǇ͘ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ KE&/Ed/>/dzEKd/͗dŚŝƐĞͲŵĂŝůŵĞƐƐĂŐĞ͕ŝŶĐůƵĚŝŶŐĂŶǇĂƚƚĂĐŚŵĞŶƚƐ͕ĐŽŶƚĂŝŶƐŝŶĨŽƌŵĂƚŝŽŶĨƌŽŵƚŚĞůĂƐŬĂKŝů ĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ;K'Ϳ͕^ƚĂƚĞŽĨůĂƐŬĂĂŶĚŝƐĨŽƌƚŚĞƐŽůĞƵƐĞŽĨƚŚĞŝŶƚĞŶĚĞĚƌĞĐŝƉŝĞŶƚ;ƐͿ͘/ƚŵĂǇ ĐŽŶƚĂŝŶĐŽŶĨŝĚĞŶƚŝĂůĂŶĚͬŽƌƉƌŝǀŝůĞŐĞĚŝŶĨŽƌŵĂƚŝŽŶ͘dŚĞƵŶĂƵƚŚŽƌŝǌĞĚƌĞǀŝĞǁ͕ƵƐĞŽƌĚŝƐĐůŽƐƵƌĞŽĨƐƵĐŚŝŶĨŽƌŵĂƚŝŽŶŵĂǇ ǀŝŽůĂƚĞƐƚĂƚĞŽƌĨĞĚĞƌĂůůĂǁ͘/ĨǇŽƵĂƌĞĂŶƵŶŝŶƚĞŶĚĞĚƌĞĐŝƉŝĞŶƚŽĨƚŚŝƐĞͲŵĂŝů͕ƉůĞĂƐĞĚĞůĞƚĞŝƚ͕ǁŝƚŚŽƵƚĨŝƌƐƚƐĂǀŝŶŐŽƌ ĨŽƌǁĂƌĚŝŶŐŝƚ͕ĂŶĚ͕ƐŽƚŚĂƚƚŚĞK'ŝƐĂǁĂƌĞŽĨƚŚĞŵŝƐƚĂŬĞŝŶƐĞŶĚŝŶŐŝƚƚŽǇŽƵ͕ĐŽŶƚĂĐƚWŚŽĞďĞƌŽŽŬƐĂƚϵϬϳͲϳϵϯͲ ϭϮϰϮŽƌƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀ͘ ͲͲͲͲͲKƌŝŐŝŶĂůDĞƐƐĂŐĞͲͲͲͲͲ &ƌŽŵ͗ĞĚŚŽŽƚĞƌϮϵϱΛŐŵĂŝů͘ĐŽŵфĞĚŚŽŽƚĞƌϮϵϱΛŐŵĂŝů͘ĐŽŵх ^ĞŶƚ͗dƵĞƐĚĂǇ͕:ƵŶĞϮϴ͕ϮϬϮϮϳ͗ϯϵWD dŽ͗ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗Z͗,ŝůĐŽƌƉZŝŐηϰϬϭϲͲϭϱͲϮϬϮϮƚĞƐƚƌĞƉŽƌƚ zĞƐŝƚƐŚŽƵůĚŚĂǀĞďĞĞŶW dŚĂŶŬzKh ͲͲͲͲͲKƌŝŐŝŶĂůDĞƐƐĂŐĞͲͲͲͲͲ &ƌŽŵ͗ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗dƵĞƐĚĂǇ͕:ƵŶĞϮϴ͕ϮϬϮϮϰ͗ϮϮWD dŽ͗ĞĚŚŽŽƚĞƌϮϵϱΛŐŵĂŝů͘ĐŽŵ ^ƵďũĞĐƚ͗Z͗,ŝůĐŽƌƉZŝŐηϰϬϭϲͲϭϱͲϮϬϮϮƚĞƐƚƌĞƉŽƌƚ Ě͕ dŚĞηϭZĂŵƐǁĂƐůĞĨƚŝŶĐŽŵƉůĞƚĞ͖ƐŚŽƵůĚƚŚĂƚďĞĂΗWΗ͍ůƐŽ͕ƚŚĞ/ŶƐŝĚĞZĞĞůǀĂůǀĞƐƋƵĂŶƚŝƚǇǁĂƐϬƐŽ/ĐŚĂŶŐĞĚƚŚĂƚƚŽϭ͘ %HDYHU&UHHN8QLW$ 37' dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ KE&/Ed/>/dzEKd/͗dŚŝƐĞͲŵĂŝůŵĞƐƐĂŐĞ͕ŝŶĐůƵĚŝŶŐĂŶǇĂƚƚĂĐŚŵĞŶƚƐ͕ĐŽŶƚĂŝŶƐŝŶĨŽƌŵĂƚŝŽŶĨƌŽŵƚŚĞůĂƐŬĂKŝů ĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ;K'Ϳ͕^ƚĂƚĞŽĨůĂƐŬĂĂŶĚŝƐĨŽƌƚŚĞƐŽůĞƵƐĞŽĨƚŚĞŝŶƚĞŶĚĞĚƌĞĐŝƉŝĞŶƚ;ƐͿ͘/ƚŵĂǇ ĐŽŶƚĂŝŶĐŽŶĨŝĚĞŶƚŝĂůĂŶĚͬŽƌƉƌŝǀŝůĞŐĞĚŝŶĨŽƌŵĂƚŝŽŶ͘dŚĞƵŶĂƵƚŚŽƌŝǌĞĚƌĞǀŝĞǁ͕ƵƐĞŽƌĚŝƐĐůŽƐƵƌĞŽĨƐƵĐŚŝŶĨŽƌŵĂƚŝŽŶŵĂǇ ǀŝŽůĂƚĞƐƚĂƚĞŽƌĨĞĚĞƌĂůůĂǁ͘/ĨǇŽƵĂƌĞĂŶƵŶŝŶƚĞŶĚĞĚƌĞĐŝƉŝĞŶƚŽĨƚŚŝƐĞͲŵĂŝů͕ƉůĞĂƐĞĚĞůĞƚĞŝƚ͕ǁŝƚŚŽƵƚĨŝƌƐƚƐĂǀŝŶŐŽƌ ĨŽƌǁĂƌĚŝŶŐŝƚ͕ĂŶĚ͕ƐŽƚŚĂƚƚŚĞK'ŝƐĂǁĂƌĞŽĨƚŚĞŵŝƐƚĂŬĞŝŶƐĞŶĚŝŶŐŝƚƚŽǇŽƵ͕ĐŽŶƚĂĐƚWŚŽĞďĞƌŽŽŬƐĂƚ ϵϬϳͲϳϵϯͲϭϮϰϮŽƌƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀ͘ ͲͲͲͲͲKƌŝŐŝŶĂůDĞƐƐĂŐĞͲͲͲͲͲ &ƌŽŵ͗ĞĚŚŽŽƚĞƌϮϵϱΛŐŵĂŝů͘ĐŽŵфĞĚŚŽŽƚĞƌϮϵϱΛŐŵĂŝů͘ĐŽŵх ^ĞŶƚ͗DŽŶĚĂǇ͕:ƵŶĞϮϬ͕ϮϬϮϮϳ͗ϭϯD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх͖KK' WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗,ŝůĐŽƌƉZŝŐηϰϬϭϲͲϭϱͲϮϬϮϮƚĞƐƚƌĞƉŽƌƚ hd/KE͗dŚŝƐĞŵĂŝůŽƌŝŐŝŶĂƚĞĚĨƌŽŵŽƵƚƐŝĚĞƚŚĞ^ƚĂƚĞŽĨůĂƐŬĂŵĂŝůƐǇƐƚĞŵ͘ ŽŶŽƚĐůŝĐŬůŝŶŬƐŽƌŽƉĞŶĂƚƚĂĐŚŵĞŶƚƐƵŶůĞƐƐǇŽƵƌĞĐŽŐŶŝǌĞƚŚĞƐĞŶĚĞƌĂŶĚŬŶŽǁƚŚĞĐŽŶƚĞŶƚŝƐƐĂĨĞ͘ WůĞĂƐĞƐĞĞƚŚĞƚĞƐƚƌĞƉŽƌƚĨŽƌhϬϳϲͲϭϱͬϮϮdŚĂŶŬǇŽƵĚ,ŽŽƚĞƌzŽƵƌŵĞƐƐĂŐĞŝƐƌĞĂĚǇƚŽďĞƐĞŶƚǁŝƚŚƚŚĞ ĨŽůůŽǁŝŶŐĨŝůĞŽƌůŝŶŬ ĂƚƚĂĐŚŵĞŶƚƐ͗ ,ŝůĐŽƌƉZŝŐηϰϬϭϲͲϭϱͲϮϬϮϮ EŽƚĞ͗dŽƉƌŽƚĞĐƚĂŐĂŝŶƐƚĐŽŵƉƵƚĞƌǀŝƌƵƐĞƐ͕ĞͲŵĂŝůƉƌŽŐƌĂŵƐŵĂǇƉƌĞǀĞŶƚƐĞŶĚŝŶŐŽƌƌĞĐĞŝǀŝŶŐĐĞƌƚĂŝŶƚǇƉĞƐŽĨĨŝůĞ ĂƚƚĂĐŚŵĞŶƚƐ͘ŚĞĐŬǇŽƵƌĞͲŵĂŝůƐĞĐƵƌŝƚǇƐĞƚƚŝŶŐƐƚŽĚĞƚĞƌŵŝŶĞŚŽǁĂƚƚĂĐŚŵĞŶƚƐĂƌĞŚĂŶĚůĞĚ͘ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:401 DATE: 6/15/22 Rig Rep.: Rig Phone: 907-283-2580 Operator: Op. Phone:907-283-2580 Rep.: E-Mail Well Name: PTD #22140600 Sundry #322-308 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250-2500 Annular:250-2500 Valves:250-2500 MASP:2233 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.NA Ball Type 2P Standing Order Posted P Misc.NA Inside BOP 2P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"5m P Pit Level Indicators PP #1 Rams 1 2-7/8X5" VBR P Flow Indicator NA NA #2 Rams 1 BLINDS P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2-1/16 P Inside Reel valves 1P HCR Valves 1 2-1/16 FP Kill Line Valves 3 2-1/16 P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)2050 P Quantity Test Result 200 psi Attained (sec)22 P No. Valves 8P Full Pressure Attained (sec)80 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 0NA Nitgn. Bottles # & psi (Avg.): 6 @ 2150 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:4.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 6/13/22 8:59 Waived By Test Start Date/Time:6/15/2022 13:00 (date) (time)Witness Test Finish Date/Time:6/15/2022 17:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Tested with 2-7/8 & 3-1/2 test joints, tested gas alarms, FP HCR valve, ( flushed and Cycled valve retest Good) Annular closeing time 20 sec, VBR rams 7 sec, Blind rams 6 sec, HCR 2sec Chris Hannevold Hilcorp Alaska Ed Hooter BCU-07A Test Pressure (psi): howard.hooter@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0615_BOP_Hilcorp401_BCU-07A 9 9 9 9 9 9 9 9 9 9 9 9 9 MEU -5HJJ FP FP HCR valve, Annular closeing time 20 sec, VBR rams 7 sec, Blind rams 6 sec, HCR 2sec 5HJJ-DPHV%2*& )URP:DGH+XGJHQV&:DGH+XGJHQV#KLOFRUSFRP! 6HQW7KXUVGD\-XQH30 7R5HJJ-DPHV%2*& &F%URRNV3KRHEH/2*& 6XEMHFW5(>(;7(51$/@5(+$.%&8$%23(7HVW5HSRUW $WWDFKPHQWV+$.[OV[ ZĞǀŝƐĞĚdĞƐƚ&ŽƌŵǁŝƚŚĐŽƌƌĞĐƚĞĚƚŝŵĞƚŽĨƵůůƉƌĞƐƐƵƌĞĂƚƚĂŝŶĞĚ͘ dŚĂŶŬƐ͕ tĂĚĞ,ƵĚŐĞŶƐ tĞůů^ŝƚĞDĂŶĂŐĞƌ ;ϵϬϯͿ ϯϯϭͲϲϳϭϭʹ ǁĂĚĞ͘ŚƵĚŐĞŶƐΛŚŝůĐŽƌƉ͘ĐŽŵ &ƌŽŵ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗tĞĚŶĞƐĚĂǇ͕:ƵŶĞϮϮ͕ϮϬϮϮϰ͗ϰϳWD dŽ͗tĂĚĞ,ƵĚŐĞŶƐͲ;ͿфtĂĚĞ͘,ƵĚŐĞŶƐΛŚŝůĐŽƌƉ͘ĐŽŵх Đ͗ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗΀ydZE>΁Z͗,<ϰϬϭͬhͲϬϳͬKWdĞƐƚZĞƉŽƌƚϲͲϴͲϮϮ dŝŵĞƚŽ&ƵůůWƌĞƐƐƵƌĞ;ĐĐƵŵƵůĂƚŽƌƐĞĐƚŝŽŶŽĨĨŽƌŵͿŝƐĂƉƉĞĂƌƐƚŽďĞĂƚǇƉŽ͘WůĞĂƐĞƉƌŽǀŝĚĞƚŚĞĐŽƌƌĞĐƚƚŝŵĞ͘dŚĂŶŬǇŽƵ͘ :ŝŵZĞŐŐ ^ƵƉĞƌǀŝƐŽƌ͕/ŶƐƉĞĐƚŝŽŶƐ K' ϯϯϯt͘ϳƚŚǀĞ͕^ƵŝƚĞϭϬϬ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ϵϬϳͲϳϵϯͲϭϮϯϲ &ƌŽŵ͗tĂĚĞ,ƵĚŐĞŶƐͲ;ͿфtĂĚĞ͘,ƵĚŐĞŶƐΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗^ĂƚƵƌĚĂǇ͕:ƵŶĞϭϭ͕ϮϬϮϮϳ͗ϮϱD dŽ͗KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх Đ͗ϰϬϭKфϰϬϭΛĂůůĂŵĞƌŝĐĂŶŽŝůĨŝĞůĚ͘ĐŽŵх͖ŽŶŶĂŵďƌƵǌфĚĂŵďƌƵǌΛŚŝůĐŽƌƉ͘ĐŽŵх͖:ƵĂŶŝƚĂ>ŽǀĞƚƚ фũůŽǀĞƚƚΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗,<ϰϬϭͬhͲϬϳͬKWdĞƐƚZĞƉŽƌƚϲͲϴͲϮϮ WůĞĂƐĞƐĞĞĂƚƚĂĐŚĞĚKWdĞƐƚZĞƉŽƌƚϲͲϴͲϮϮ͘ dŚĂŶŬƐ͕ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH %HDYHU&UHHN8QLW$ 37' tĂĚĞ,ƵĚŐĞŶƐ tĞůů^ŝƚĞDĂŶĂŐĞƌ ,<ZŝŐϰϬϭ ;ϵϬϯͿ ϯϯϭͲϲϳϭϭʹ ǁĂĚĞ͘ŚƵĚŐĞŶƐΛŚŝůĐŽƌƉ͘ĐŽŵ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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:401 DATE: 6/8/22 Rig Rep.: Rig Phone: 907-283-2580 Operator: Op. Phone:907-238-2580 Rep.: E-Mail Well Name: PTD #22140600 Sundry #322-308 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250-2500 Annular:250-2500 Valves:250-2500 MASP:2233 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.NA Ball Type 2P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11" 5M P Pit Level Indicators PP #1 Rams 1 -7/8"x5" VBR's 5M P Flow Indicator NA NA #2 Rams 1 Blinds 5M P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2-1/16" 5M P Inside Reel valves 0NA HCR Valves 1 2-1/16" 5M P Kill Line Valves 3 2-1/16" 5M FP Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)2125 P Quantity Test Result 200 psi Attained (sec)21 P No. Valves 8P Full Pressure Attained (sec)74 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 0NA Nitgn. Bottles # & psi (Avg.): 6 x 2150 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:3.5 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 6-6-22/06:38am Waived By Test Start Date/Time:6/8/2022 7:00 (date) (time)Witness Test Finish Date/Time:6/8/2022 10:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Hilcorp Tested with 2-7/8" and 3-1/2" test joint, Tested gas alarms. FP on Kill Line Valve #1 during low test, cycled valve, sequential test was good. Annular closing time with 2-7/8" TJ 23 sec. VBR closing time 5 sec. Blinds closing time 5 sec. HCR closing time 2 sec. Chris Hannevold Hilcorp Alaska Wade Hudgens BCU-07A Test Pressure (psi): wade.hudgens@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0608_BOP_Hilcorp401_BCU-07A 9 9 9 9 9 9 9 9 9 9 9 9 9 -5HJJ FP FP on Kill Line Valve #1 during low test, Annular closing time with 2-7/8" TJ 23 sec. VBR closing time 5 sec. Blinds closing time 5 sec. HCR closing time 2 sec. 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:Jacob Flora To:McLellan, Bryan J (OGC) Cc:Juanita Lovett Subject:BCU 7A CBL - AOGCC 10-403 322-308 PTD 214-060 Approved 05-20-22 Date:Tuesday, June 21, 2022 1:52:05 PM Attachments:BCU 7A CBL FINAL.pdf BCU 7A CBL FINAL.las BCU-07A Schematic 06-20-22.pdf Hello Bryan, Attached is the CBL for BCU-07A of the cemented 3.5 tubing. It looks pretty good, our next step is to MITIA to 2500 psi per the Sundry. I updated the WBD and attached also. Please advise if you see any issues, Thanks, Jake From: Roy Wright <rwright@yjosllc.com> Sent: Tuesday, June 21, 2022 12:38 PM To: Jacob Flora <Jake.Flora@hilcorp.com> Subject: [EXTERNAL] BCU 7A CBL Jake, here's the CBL for BCU 7A, cement top was 2545' and TD is 7139' Thanks Roy 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. Updated byJMF 06-20-22 SCHEMATIC BCU-7A Pad 7 PTD: 214-060 API: 50-133-20284-01-00 Completed 6/18/2022 PBTD = 7155’ / TVD = ______ TD = 9,800’ / TVD = 8,929’ RKB to GL = 18.5’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sterling D1Y 2,910' 2,924' 2,898' 2,911' 14' 06/18/22 Isolated Sterling D1X 2,974' 2,979' 2,957' 2,962' 5' 06/18/22 Isolated Sterling D1 3,018' 3,020' 2,997' 2,999' 2' 06/18/22 Isolated Sterling ±5,319' ±5,801' ±4,878' ±5,273' ±482' Future Proposed Beluga ±6,558' ±7,136' ±5,893' ±6,369' ±574' Future Proposed Isolated Perfs on Page 2 OPEN HOLE / CEMENT DETAIL 20” 26” Hole: 518bbls of Class G cement pumped (BC-07 parent - 1976) 13-3/8” 17-1/2” Hole: 13.5ppg class G, 6/8/76 CBL shows good cement up to at least 2100’ 9-5/8” 12-1/4” hole: Cemented through a DV collar below BC-07A’s KOP. Cemented with 1600sxs class G. Got 500 sxs back to surface. (BC-07 parent - 1976) 5-1/2” 7-7/8” hole: Cemented with 245bbls 11.5ppg followed by 100bbls 15.3ppg tail. 7/3/14 USIT shows Good cement up to 2180’ MD and free pipe above 1850’ MD 3-1/2” Cemented with 60 bbls 15.3 ppg cement, TOC at 2545’ (6/21/22 CBL) CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 30” Conductor 310 LP-B Surf 30' 20” Surface casing 133 K-55 Vetco 18.73” Surf 2072’ 13-3/8" Int Casing 68 K-55 BTC 12.415” Surf 2214’ 13-3/8" Int Casing 72 N-80 BTC 12.347” 2214’ 2336’ 9-5/8” Int Casing 47 N-80 BTC 8.681” Surf 2336’ 5-1/2” Prod Casing 17 P-110 DWC/C-HT 4.892” Surf 9767’ TUBING DETAIL 3-1/2” Tubing 9.2 L-80 IBT & Supermax 2.992 Surf 7161’ 5-1/2” No. Depth (MD) ID Item 1 1,869’ 4.892” Swell Packer 2 2,344’ Dual string exit through 9-5/8” and 13-3/8” casings 3 2521’ 2.980” Tripoint packer 4 7,200’ CIBP with 36’ cement: ToC = 7164’ MD (3/26/20) 5 8,393’ Quadco Straddle Patch (15’) 8394’ – 8,409’ MD (1/25/20) 6 8,544’ CIBP (11/5/19) 7 8,750’ CIBP with 5’ cement: ToC = 8745’ MD (3/16/16) 8 9,110’ CIBP (7/23/14). 35’ cmt on top of fill on 3/16/16: ToC = 9052’ 13-3/8” and 9-5/8” 4 5 6 7 8 20” RA Tags: 2998, 5727, 8536, 8678, 8999, 9188 Max inc: 40 deg at 3472’ MD Max DLS: 8 deg/100’ at 2729’ MD 1 2 No commingling of Sterling and Beluga without plug at 6508’ & 35’ cmt per BLM 3 Updated by DMA 05/13/22 PROPOSED BCU-7A Pad 7 PTD: 214-060 API: 50-133-20284-01-00 ISOLATED PERFORATIONS PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status M_Bel 7,242' 7,252' 6,458' 6,466' 10' Isolated B-16 8,015' 8,026' 7,166' 7,177' 11' Isolated B-16 8,016' 8,026' 7,167' 7,177' 10' Isolated SR_LBGT 8,074' 8,081' 7,224' 7,230' 7' Isolated SR_LBGT 8,075' 8,081' 7,225' 7,230' 6' Isolated B-17 8,127' 8,142' 7,275' 7,290' 15' Isolated B-19 8,245' 8,255' 7,390' 7,400' 10' Isolated B-20 8,289' 8,299' 7,433' 7,443' 10' Isolated B-20 8,396' 8,406' 7,538' 7,547' 10' Patched (1/25/20) B-21 8,451' 8,456' 7,592' 7,597' 5' Isolated B-21 LWR 8,496' 8,506' 7,636' 7,646' 10' Isolated B-22 8,560' 8,575' 7,699' 7,714' 15' Isolated (11/5/19) LB-23 8,610' 8,620' 7,748' 7,758' 10' Isolated (11/5/19) LB-25 8,708' 8,728' 7,845' 7,864' 20' Isolated (11/5/19) LB-26 8,770' 8,780' 7,906' 7,916' 10' Isolated (3/16/16) LB-27 8,820' 8,830' 7,955' 7,965' 10' Isolated 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ƚƌŽƵďůĞǌŽŶĞƚŽŚĞĂůůŽƐƐĞƐ͕ĂŶĚͬŽƌĂŝĚŝŶŵŝůůŝŶŐ͘ ϭϯ͘DhϯͲϭͬϮ͟ůŝŶĞƌĂƐƐĞŵďůǇ ϭϰ͘ZƵŶϯͲϭͬϮ͟ůŝŶĞƌĂƐƐĞŵďůǇĂŶĚůĂŶĚŽŶƚŽƉĨŝƐŚĂƐĚĞĞƉĂƐƉŽƐƐŝ ďůĞƚŽĂůůŽǁĨŽƌŵĂǆŝŵƵŵĂĐĐĞƐƐƚŽ ĞůƵŐĂƐĂŶĚƐ ϭϱ͘ĞŵĞŶƚϯͲϭͬϮ͟ůŝŶĞƌŝŶƉůĂĐĞ Ă͘WůĂŶŶĞĚdŽŝŶϯͲϭͬϮ͟ǆϱͲϭͬϮ͟ĂŶŶƵůƵƐĂƚϭϴϱϬ͛D ď͘ĞŵĞŶƚǀŽůƵŵĞŽĨΕϲϬďďůƐ ϭϲ͘^ĞƚWsŽƌdt ϭϳ͘EKWƐ͕EhƚƌĞĞ ϭϴ͘ZDKƌŝŐϰϬϭ $IORDW VKRH ZLOO EH UXQ LQ WKH ERWWRP RI WKH DVVHPEO\ SHU 5 5XSHUW EMP &HQWUDOL]HUV ZLOO EH UXQ SHU 5 5XSHUW EMP ĞŵĞŶƚǀŽůƵŵĞŽĨΕϲϬďďůƐ tĞůů͗hͲϬϳ ZtKZĞĐŽŵƉůĞƚĞ ŽŵƉůĞƚŝŽŶƉƌŽĐĞĚƵƌĞ ϭ͘D/ZhͲůŝŶĞĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ Ϯ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ ϯ͘>ŽŐ>ŽĨϯͲϭͬϮ͟ƉƌŽĚƵĐƚŝŽŶůŝŶĞƌĨƌŽŵWdƚŽƐƵƌĨĂĐĞ Ă͘^ĞŶĚƌĞƐƵůƚƐƚŽK' ď͘EĞĞĚƚŽĞŶƐƵƌĞǁĞŚĂǀĞĐĞŵĞŶƚŝƐŽůĂƚŝŽŶďĞƚǁĞĞŶƚŚĞĞůƵŐĂĂŶĚ^ƚĞƌůŝŶŐWŽŽůƐͬW͛Ɛ Đ͘DĂǇďĞƌƵŶŽŶŵĞŵŽƌǇ^>͕ŽƌĞͲĐŽŝů͕d ϰ͘ZDK> ϱ͘D/dͲdƚŽϮϱϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐ;ĐŚĂƌƚĞĚͿ ϲ͘D/dͲ/ŽĨϯͲϭͬϮ͟ǆϱͲϭͬϮ͟ƚŽϮϱϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐ Ă͘ŽĞƐŶŽƚŶĞĞĚƚŽďĞĐŚĂƌƚĞĚ ď͘KŬĂǇŝĨĨĂŝůƐ͕ĂƐϱͲϭͬϮ͟ǆϵͲϱͬϴ͟ǁŝůůďĞŽƵƌŵŽŶŝƚŽƌĂďůĞĂŶŶƵůƵƐ Đ͘/ĨĨĂŝůƐ͕,ŝůĐŽƌƉǁŝůůEKdƉƌŽĚƵĐĞƚŚĞ^ƚĞƌůŝŶŐƵƉƚŚĞϯͲϭͬϮ͟ǆϱͲϭͬϮ͟ĂŶŶƵůƵƐ͕ŶŽƌǁŝůůƚŚĞ ƐƵƌĨĂĐĞƉŝƉŝŶŐďĞĐŽŶĨŝŐƵƌĞĚƚŽĚŽƐŽ ;DĂǇĞůĞĐƚƚŽƐǁĂďǁĂƚĞƌŽĨĨ͘dͿ ϳ͘D/ZhŽŝůĞĚdƵďŝŶŐ ϴ͘dĞƐƚKWƚŽϮϱϬƉƐŝůŽǁĂŶĚϯϱϬϬƉƐŝŚŝŐŚ ϵ͘Z/,ǁŝƚŚĐŽŝůƚƵďŝŶŐƚŽWd͕ũĞƚǁĞůůĚƌǇǁŝƚŚEŝƚƌŽŐĞŶ;ĞǆƉĞĐƚĞĚtsΕϲϮďďůƐͿ ϭϬ͘KŶĐĞǁĞůůŝƐĚƌǇ͕ƚƌĂƉŶŝƚƌŽŐĞŶƉƌĞƐƐƵƌĞƉĞƌKĨŽƌƉĞƌĨŽƌĂƚŝŶŐ ϭϭ͘ZDKŽŝůĞĚdƵďŝŶŐ $2*&& $SSURYDO RI &%/ UHVXOWV UHTXLUHG EHIRUH SHUIRUDWLQJ EMP ŽĞŶƐƵƌĞǁ (LWKHU WKH [ DQQXOXV RU WKH [ DQQXOXV PXVW SDVV DQ 0,7,$ WR SVL EMP ĐĞŵĞŶƚŝƐŽůĂƚŝŽŶďĞƚǁĞĞŶƚŚĞĞůƵŐĂĂŶĚ ^ƚĞƌůŝŶŐWŽŽůƐͬ tĞůů͗hͲϬϳ ZtKZĞĐŽŵƉůĞƚĞ Ͳ>ŝŶĞWĞƌĨƉƌŽĐĞĚƵƌĞ;ĞůƵŐĂͿ ϭϮ͘D/ZhͲůŝŶĞĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ ϭϯ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ ϭϰ͘Z/,ĂŶĚƉĞƌĨŽƌĂƚĞƚŚĞĞůƵŐĂϱʹĞůƵŐĂϭϭƐĂŶĚƐĨƌŽŵцϲ͕ϱϱϴ͛ʹцϳ͕ϭϯϲ͛D Ă͘цϲ͕ϯϲϭ͛ʹцϲ͕ϯϲϵ͛ds ď͘ůůƐĂŶĚƐǁŝƚŚŝŶƚŚĞĞůƵŐĂWŽŽůͬW ϭϱ͘ZDK> dŚĞĞůƵŐĂWŽŽůͬWŵƵƐƚďĞĨƵůůǇWΘ͛ĚďĞĨŽƌĞŽƉĞŶŝŶŐĂŶǇ^ƚĞƌůŝŶŐƉĞƌĨƐ͘tĞĂƌĞEKdĂƵƚŚŽƌŝǌĞĚĨŽƌ ĐŽŵŝŶŐůŝŶŐŝŶƚŚŝƐǁĞůů͘/ĨĐŽŵŝŶŐůŝŶŐĚĞƐŝƌĞĚ͕,ŝůĐŽƌƉǁŝůůƐ ƵďŵŝƚĂƐĞƉĂƌĂƚĞƐƵŶĚƌǇĂƚƚŚĂƚƚŝŵĞ͘ Ͳ>ŝŶĞWĞƌĨƉƌŽĐĞĚƵƌĞ;^ƚĞƌůŝŶŐͿ ϭϲ͘D/ZhͲůŝŶĞĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ ϭϳ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ ϭϴ͘ZhŶŝƚƌŽŐĞŶĂŶĚƉƵƐŚǁĂƚĞƌďĂĐŬŝŶƚŽĨŽƌŵĂƚŝŽŶ ϭϵ͘Z/,ĂŶĚƐĞƚϯͲϭͬϮ͟/WϱϬ͛ĂďŽǀĞƚŽƉƉĞƌĨƚŽŝƐŽůĂƚĞĂůůĞůƵŐĂƉĞƌĨƐ ϮϬ͘ƵŵƉďĂŝůĂƚůĞĂƐƚϯϱ͛ŽĨĐĞŵĞŶƚŽŶƚŽƉŽĨ/W Ϯϭ͘Z/,ĂŶĚƉĞƌĨŽƌĂƚĞƚŚĞ^ƚĞƌůŝŶŐϬʹ^ƚĞƌůŝŶŐϲƐĂŶĚƐĨƌŽŵцϱ͕ϯϭϵ͛Ͳцϱ͕ϴϬϭ͛D Ă͘цϰ͕ϴϳϴ͛ʹцϱ͕Ϯϳϯ͛ds ď͘ůůƐĂŶĚƐǁŝƚŚŝŶƚŚĞ^ƚĞƌůŝŶŐWŽŽůͬW ϮϮ͘ZDK> ŽŶƚŝŶŐĞŶĐǇĂĚĚŝƚŝŽŶĂů>WůƵŐͬƉĂƚĐŚ;ƐͿ Ϯϯ͘D/ZhͲůŝŶĞĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ Ϯϰ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ Ϯϱ͘ZhŶŝƚƌŽŐĞŶĂŶĚƉƵƐŚǁĂƚĞƌďĂĐŬŝŶƚŽĨŽƌŵĂƚŝŽŶ Ϯϲ͘ŽŶĨŝƌŵǁĂƚĞƌůĞǀĞůŝƐďĞůŽǁŝŶƚĞƌǀĂůƚŽŝƐŽůĂƚĞĂŶĚƐĞƚϯͲϭͬϮ͟ƉůƵŐŽƌƉĂƚĐŚ͘ /ĨƵƐŝŶŐĂ/W͕ŝƚŵƵƐƚďĞƐĞƚϱϬ͛ĂďŽǀĞƉĞƌĨ͕ĂŶĚŚĂǀĞϯϱ͛ĐĞŵĞŶƚĚƵŵƉďĂŝůĞĚƵŶůĞƐƐĂ>DǀĂƌŝĂŶĐĞŝƐ ŽďƚĂŝŶĞĚŝŶĂĚǀĂŶĐĞ Ϯϳ͘ZDK> ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ƵƌƌĞŶƚƐĐŚĞŵĂƚŝĐ Ϯ͘WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ƵƌƌĞŶƚǁĞůůŚĞĂĚĚƌĂǁŝŶŐ ϰ͘WƌŽƉŽƐĞĚǁĞůůŚĞĂĚĚƌĂǁŝŶŐ ϱ͘ZŝŐϰϬϭKW^ĐŚĞŵĂƚŝĐ;ϭϭ͟ϱŬͿ ϲ͘ĞƌŝĂůϲϲϬ͛ŵĂƉ ϳ͘ZtKƐƵŶĚƌǇĐŚĂŶŐĞĨŽƌŵ ϴ͘&ŽǆdKWĚŝĂŐƌĂŵ ϵ͘^ƚĂŶĚĂƌĚǁĞůůƉƌŽĐĞĚƵƌĞʹEϮŽƉĞƌĂƚŝŽŶƐ цϲ͕ϯϲϭ͛ʹцϲ͕ϯϲϵ͛ds ĞůƵŐĂϱʹĞůƵŐĂϭϭƐĂŶĚƐĨƌŽŵцϲ͕ϱϱϴ͛ʹ цϳ͕ϭϯϲ͛Dʹ ĞĞůƵŐĂWŽŽůͬWŵƵƐƚďĞĨƵůůǇWΘ͛ĚďĞĨŽƌĞŽƉĞŶŝŶŐĂŶǇ^ƚĞƌůŝŶŐƉĞƌĨƐ͘ ůůƐĂŶĚƐǁŝƚŚŝŶƚŚĞĞůƵŐĂWŽŽůͬ hƉĚĂƚĞĚďǇZZϱͲϵͲϮϮ ^,Dd/ hͲϳ WĂĚϳ Wd͗ϮϭϰͲϬϲϬ W/͗ϱϬͲϭϯϯͲϮϬϮϴϰͲϬϭͲϬϬ WdсϮ͕ϵϲϱ͛ͬdsсϮ͕ϵϰϵ͛ dсϵ͕ϴϬϬ͛ͬdsсϴ͕ϵϮϵ͛ Z<ƚŽ'>сϭϴ͘ϱ͛ ^ĂŶĚWŽŽůdKW D dD D dKW ds dD ds&dĂƚĞ ^ƚĂƚƵƐ ϭz^ƚĞƌůŝŶŐϮϵϭϬϮϵϮϰϮϴϵϱϮϵϭϭϭϰϭϭͬϭϭͬϮϭKƉĞŶ ϭy^ƚĞƌůŝŶŐϮϵϰϳϮϵϳϵϮϵϱϳϮϵϲϮϯϮϯͬϯϭͬϮϬ/ƐŽůĂƚĞĚϭϭͬϭϬͬϮϭ ϭ^ƚĞƌůŝŶŐϯϬϭϴϯϬϮϬϮϵϵϵϮϵϵϵϮϯͬϮϳͬϮϬ/ƐŽůĂƚĞĚϯͬϯϭͬϮϬ DĞůƵŐĂϳϮϰϮϳϮϱϮϲϰϱϴϲϰϲϲϭϬϭϬͬϮϵͬϭϵ/ƐŽůĂƚĞĚϯͬϮϲͬϮϬ DŽƌĞWĞƌĨƐŽŶƉĂŐĞϮ KWE,K>ͬDEdd/> ϮϬ͟Ϯϲ͟,ŽůĞ͗ϱϭϴďďůƐŽĨůĂƐƐ'ĐĞŵĞŶƚƉƵŵƉĞĚ;ͲϬϳƉĂƌĞŶƚͲϭϵϳϲͿ ϭϯͲϯͬϴ͟ϭϳͲϭͬϮ͟,ŽůĞ͗ĐĞŵĞŶƚĞĚǁŝƚŚϭϯ͘ϱƉƉŐĐůĂƐƐ';ĨƌŽŵƐŚŽĞŝŶͲϬϳƉĂƌĞŶƚͿϲͬϴͬϳϲ >ƐŚŽǁƐŐŽŽĚĐĞŵĞŶƚƵƉƚŽĂƚůĞĂƐƚϮϭϬϬ͛D ϵͲϱͬϴ͟ϭϮͲϭͬϰ͟ŚŽůĞ͗ĞŵĞŶƚĞĚƚŚƌŽƵŐŚĂsĐŽůůĂƌďĞůŽǁͲϬϳ͛Ɛ<KW͘ĞŵĞŶƚĞĚǁŝƚŚ ϭϲϬϬƐǆƐĐůĂƐƐ'͘'ŽƚϱϬϬƐǆƐďĂĐŬƚŽƐƵƌĨĂĐĞ͘;ͲϬϳƉĂƌĞŶƚͲϭϵϳϲͿ ϱͲϭͬϮ͟ϳͲϳͬϴ͟ŚŽůĞ͗ĞŵĞŶƚĞĚǁŝƚŚϮϰϱďďůƐϭϭ͘ϱƉƉŐĨŽůůŽǁĞĚďǇϭϬϬďďůƐϭϱ͘ϯƉƉŐƚĂŝů͘ ϳͬϯͬϭϰh^/dƐŚŽǁƐ'ŽŽĚĐĞŵĞŶƚƵƉƚŽϮϭϴϬ͛DĂŶĚĨƌĞĞƉŝƉĞĂďŽǀĞϭϴϱϬ͛D ^/E'd/> ^ŝǌĞdǇƉĞtƚ'ƌĂĚĞŽŶŶ͘/dŽƉƚŵ ϯϬ͟ŽŶĚƵĐƚŽƌϯϭϬ>WͲ^ƵƌĨϯϬΖ ϮϬ͟^ƵƌĨĂĐĞĐĂƐŝŶŐϭϯϯ<ͲϱϱsĞƚĐŽϭϴ͘ϳϯ͟^ƵƌĨϮϬϳϮ͛ ϭϯͲϯͬϴΗ/ŶƚĂƐŝŶŐϲϴ<ͲϱϱdϭϮ͘ϰϭϱ͟^ƵƌĨϮϮϭϰ͛ ϭϯͲϯͬϴΗ/ŶƚĂƐŝŶŐϳϮEͲϴϬdϭϮ͘ϯϰϳ͟ϮϮϭϰ͛Ϯϯϯϲ͛ ϵͲϱͬϴ͟/ŶƚĂƐŝŶŐϰϳEͲϴϬdϴ͘ϲϴϭ͟^ƵƌĨϮϯϯϲ͛ ϱͲϭͬϮ͟WƌŽĚĂƐŝŶŐϭϳWͲϭϭϬtͬͲ,dϰ͘ϴϵϮ͟^ƵƌĨϵϳϲϳ͛ ϱͲϭͬϮ͟ EŽ͘ĞƉƚŚ ;DͿ//ƚĞŵ ϭϭϴϲϵϰ͘ϴϵϮ͟^ǁĞůůWĂĐŬĞƌ ϮϮϯϰϰƵĂůƐƚƌŝŶŐĞǆŝƚƚŚƌŽƵŐŚϵͲϱͬϴ͟ĂŶĚϭϯͲϯͬϴ͟ĐĂƐŝŶŐƐ ϯϮϵϲϱ/WǁŝƚŚϭϬ͛ĐĞŵĞŶƚ͗dŽсϮϵϱϱ͛D;ϭϭͬϭϬͬϮϭͿ ϰϯϬϭϮ/W;ϯͬϯϭͬϮϬͿǁŝƚŚϭϬ͛ĐĞŵĞŶƚ͗dŽсϯϬϬϮ͛D;ϭϭͬϭϬͬϮϭͿ ϱϳϮϬϬ/WǁŝƚŚϯϲ͛ĐĞŵĞŶƚ͗dŽсϳϭϲϰ͛D;ϯͬϮϲͬϮϬͿ ϲ ϴϯϵϯYƵĂĚĐŽ^ƚƌĂĚĚůĞWĂƚĐŚ;ϭϱ͛ůŽŶŐͿĨƌŽŵϴϯϵϰ͛ʹϴ͕ϰϬϵ͛D ;ϭͬϮϱͬϮϬͿ ϳϴϱϰϰ/W;ϭϭͬϱͬϭϵͿ ϴϴϳϱϬ/WǁŝƚŚϱ͛ĐĞŵĞŶƚ͗dŽсϴϳϰϱ͛D;ϯͬϭϲͬϭϲͿ ϵ ϵϭϭϬ/W;ϳͬϮϯͬϭϰͿ͘ƵŵƉĞĚϯϱ͛ĐĞŵĞŶƚŽŶƚŽƉŽĨĨŝůůŽŶ ϯͬϭϲͬϭϲ͗dŽсϵϬϱϮ͛D ϭϯͲϯͬϴ͟ ĂŶĚ ϵͲϱͬϴ͟ ϱ ϲ ϳ ϴ ϵ ϮϬ͟ ϭ Ϯ ϯ ϰ ZdĂŐƐ͗Ϯϵϵϴ͕ϱϳϮϳ͕ϴϱϯϲ͕ϴϲϳϴ͕ ϴϵϵϵ͕ϵϭϴϴ DĂǆŝŶĐ͗ϰϬĚĞŐĂƚϯϰϳϮ͛D DĂǆ>^͗ϴĚĞŐͬϭϬϬ͛ĂƚϮϳϮϵ͛D WĞƌĨŽƌĂƚŝŽŶƐ͗ ŽŶĞDds^ŝǌĞ^W&ĂƚĞ^ƚĂƚƵƐ ^ƚĞƌůŝŶŐϭzϮ͕ϵϭϬΖͲϮ͕ϵϮϰΖϮ͕ϴϵϴΖͲϮ͕ϵϭϭΖϮͲϳͬϴΗϭϭͬϭϭͬϮϭKƉĞŶ ^ƚĞƌůŝŶŐϭyϮ͕ϵϳϰΖͲϮ͕ϵϳϵΖϮ͕ϵϱϳΖͲϮ͕ϵϲϮΖϯͲϯͬϴΗϲϬϯͬϯϭͬϮϬ/ƐŽůĂƚĞĚ ^ƚĞƌůŝŶŐϭϯ͕ϬϭϴΖͲϯ͕ϬϮϬΖϮ͕ϵϵϳΖͲϮ͕ϵϵϵΖϯͲϯͬϴΗϲϬϯͬϮϳͬϮϬ/ƐŽůĂƚĞĚ DͺĞůϳ͕ϮϰϮΖͲϳ͕ϮϱϮΖϲ͕ϰϱϴΖͲϲ͕ϰϲϲΖϮͲϳͬϴΗϭϬϭϬͬϮϵͬϭϵ/ƐŽůĂƚĞĚ Ͳϭϲϴ͕ϬϭϱΖͲϴ͕ϬϮϲΖϳ͕ϭϲϲΖͲϳ͕ϭϳϳΖϮͲϳͬϴΗϭϭϬϮͬϬϮͬϮϬ/ƐŽůĂƚĞĚ Ͳϭϲϴ͕ϬϭϲΖͲϴ͕ϬϮϲΖϳ͕ϭϲϳΖͲϳ͕ϭϳϳΖϮͲϳͬϴΗϭϬϭϬͬϮϵͬϭϵ/ƐŽůĂƚĞĚ ^Zͺ>'dϴ͕ϬϳϰΖͲϴ͕ϬϴϭΖϳ͕ϮϮϰΖͲϳ͕ϮϯϬΖϮͲϳͬϴΗϲϬϮͬϬϮͬϮϬ/ƐŽůĂƚĞĚ ^Zͺ>'dϴ͕ϬϳϱΖͲϴ͕ϬϴϭΖϳ͕ϮϮϱΖͲϳ͕ϮϯϬΖϮͲϳͬϴΗϲϭϬͬϮϵͬϭϵ/ƐŽůĂƚĞĚ Ͳϭϳϴ͕ϭϮϳΖͲϴ͕ϭϰϮΖϳ͕ϮϳϱΖͲϳ͕ϮϵϬΖϮͲϳͬϴΗϭϱϬϯͬϭϰͬϭϵ/ƐŽůĂƚĞĚ Ͳϭϵϴ͕ϮϰϱΖͲϴ͕ϮϱϱΖϳ͕ϯϵϬΖͲϳ͕ϰϬϬΖϮͲϳͬϴΗϭϬϬϯͬϭϰͬϭϵ/ƐŽůĂƚĞĚ ͲϮϬϴ͕ϮϴϵΖͲϴ͕ϮϵϵΖϳ͕ϰϯϯΖͲϳ͕ϰϰϯΖϮͲϳͬϴΗϭϬϬϯͬϭϰͬϭϵ/ƐŽůĂƚĞĚ ͲϮϬϴ͕ϯϵϲΖͲϴ͕ϰϬϲΖϳ͕ϱϯϴΖͲϳ͕ϱϰϳΖϮͲϳͬϴΗϭϬϬϯͬϭϰͬϭϵWĂƚĐŚĞĚ;ϭͬϮϱͬϮϬͿ ͲϮϭϴ͕ϰϱϭͲϴ͕ϰϱϲΖϳ͕ϱϵϮΖͲϳ͕ϱϵϳΖϮͲϳͬϴΗϱϬϮͬϭϭͬϭϵ/ƐŽůĂƚĞĚ ͲϮϭ>tZϴ͕ϰϵϲΖͲϴ͕ϱϬϲΖϳ͕ϲϯϲΖͲϳ͕ϲϰϲΖϮͲϳͬϴΗϭϬϬϮͬϮϮͬϭϵ/ƐŽůĂƚĞĚ ͲϮϮϴ͕ϱϲϬΖͲϴ͕ϱϳϱΖϳ͕ϲϵϵΖͲϳ͕ϳϭϰΖϮͲϳͬϴΗϭϱϬϮͬϮϮͬϭϵ/ƐŽůĂƚĞĚ;ϭϭͬϱͬϭϵͿ >ͲϮϯϴ͕ϲϭϬΖͲϴ͕ϲϮϬΖϳ͕ϳϰϴΖͲϳ͕ϳϱϴΖϯͲϯͬϴΗϲϬϴͬϬϴͬϭϰ/ƐŽůĂƚĞĚ;ϭϭͬϱͬϭϵͿ >ͲϮϱϴ͕ϳϬϴΖͲϴ͕ϳϮϴΖϳ͕ϴϰϱΖͲϳ͕ϴϲϰΖϯͲϯͬϴΗϲϬϴͬϬϴͬϭϰ/ƐŽůĂƚĞĚ;ϭϭͬϱͬϭϵͿ >ͲϮϲϴ͕ϳϳϬΖͲϴ͕ϳϴϬΖϳ͕ϵϬϲΖͲϳ͕ϵϭϲΖϯͲϯͬϴΗϲϬϴͬϬϴͬϭϰ/ƐŽůĂƚĞĚ;ϯͬϭϲͬϭϲͿ >ͲϮϳϴ͕ϴϮϬΖͲϴ͕ϴϯϬΖϳ͕ϵϱϱΖͲϳ͕ϵϲϱΖϯͲϯͬϴΗϲϬϴͬϬϴͬϭϰ/ƐŽůĂƚĞĚ;ϯͬϭϲͬϭϲͿ >ͲϮϵϵ͕ϬϰϱΖͲϵ͕ϬϲϬΖϴ͕ϭϳϴΖͲϴ͕ϭϵϯΖϯͲϯͬϴΗϲϬϳͬϮϱͬϭϰ/ƐŽůĂƚĞĚ;ϯͬϭϲͬϭϲͿ >ͲϯϬϵ͕ϭϮϯΖͲϵ͕ϭϯϱΖϴ͕ϮϱϱΖͲϴ͕ϮϲϳΖϯͲϯͬϴΗϲϬϳͬϮϬͬϭϰ/ƐŽůĂƚĞĚ;ϳͬϮϯͬϭϰͿ >ͲϯϬϵ͕ϭϱϱΖͲϵ͕ϭϲϱΖϴ͕ϮϴϳΖͲϴ͕ϮϵϳΖϯͲϯͬϴΗϲϬϳͬϮϬͬϭϰ/ƐŽůĂƚĞĚ;ϳͬϮϯͬϭϰͿ >Ͳϯϭϵ͕ϮϭϬΖͲϵ͕ϮϮϭΖϴ͕ϯϰϭΖͲϴ͕ϯϱϮΖϯͲϯͬϴΗϭϮϬϳͬϭϲͬϭϰ/ƐŽůĂƚĞĚ;ϳͬϮϯͬϭϰͿ hƉĚĂƚĞĚďǇDϬϱͲϭϯͲϮϮ WZKWK^ hͲϳ WĂĚϳ Wd͗ϮϭϰͲϬϲϬ W/͗ϱϬͲϭϯϯͲϮϬϮϴϰͲϬϭͲϬϬ WdсϮ͕ϵϲϱ͛ͬdsсϮ͕ϵϰϵ͛ dсϵ͕ϴϬϬ͛ͬdsсϴ͕ϵϮϵ͛ Z<ƚŽ'>сϭϴ͘ϱ͛ WZ&KZd/KEd/> ŽŶĞdŽƉ;DͿƚŵ ;DͿ dŽƉ ;dsͿƚŵ;dsͿ&dĂƚĞ ^ƚĂƚƵƐ ^ƚĞƌůŝŶŐϭzϮ͕ϵϭϬΖϮ͕ϵϮϰΖϮ͕ϴϵϴΖϮ͕ϵϭϭΖϭϰΖϭϭͬϭϭͬϮϬϮϭ/ƐŽůĂƚĞĚ ^ƚĞƌůŝŶŐϭyϮ͕ϵϳϰΖϮ͕ϵϳϵΖϮ͕ϵϱϳΖϮ͕ϵϲϮΖϱΖϯͬϯϭͬϮϬϮϬ/ƐŽůĂƚĞĚ ^ƚĞƌůŝŶŐϭϯ͕ϬϭϴΖϯ͕ϬϮϬΖϮ͕ϵϵϳΖϮ͕ϵϵϵΖϮΖϯͬϮϳͬϮϬϮϬ/ƐŽůĂƚĞĚ ^ƚĞƌůŝŶŐцϱ͕ϯϭϵΖцϱ͕ϴϬϭΖцϰ͕ϴϳϴΖцϱ͕ϮϳϯΖцϰϴϮΖ&ƵƚƵƌĞWƌŽƉŽƐĞĚ ĞůƵŐĂцϲ͕ϱϱϴΖцϳ͕ϭϯϲΖцϱ͕ϴϵϯΖцϲ͕ϯϲϵΖцϱϳϰΖ&ƵƚƵƌĞWƌŽƉŽƐĞĚ /ƐŽůĂƚĞĚWĞƌĨƐŽŶWĂŐĞϮ KWE,K>ͬDEdd/> ϮϬ͟Ϯϲ͟,ŽůĞ͗ϱϭϴďďůƐŽĨůĂƐƐ'ĐĞŵĞŶƚƉƵŵƉĞĚ;ͲϬϳƉĂƌĞŶƚͲϭϵϳϲͿ ϭϯͲϯͬϴ͟ϭϳͲϭͬϮ͟,ŽůĞ͗ĐĞŵĞŶƚĞĚǁŝƚŚϭϯ͘ϱƉƉŐĐůĂƐƐ';ĨƌŽŵƐŚŽĞŝŶͲϬϳƉĂƌĞŶƚͿϲͬϴͬϳϲ >ƐŚŽǁƐŐŽŽĚĐĞŵĞŶƚƵƉƚŽĂƚůĞĂƐƚϮϭϬϬ͛D ϵͲϱͬϴ͟ϭϮͲϭͬϰ͟ŚŽůĞ͗ĞŵĞŶƚĞĚƚŚƌŽƵŐŚĂsĐŽůůĂƌďĞůŽǁͲϬϳ͛Ɛ<KW͘ĞŵĞŶƚĞĚǁŝƚŚ ϭϲϬϬƐǆƐĐůĂƐƐ'͘'ŽƚϱϬϬƐǆƐďĂĐŬƚŽƐƵƌĨĂĐĞ͘;ͲϬϳƉĂƌĞŶƚͲϭϵϳϲͿ ϱͲϭͬϮ͟ϳͲϳͬϴ͟ŚŽůĞ͗ĞŵĞŶƚĞĚǁŝƚŚϮϰϱďďůƐϭϭ͘ϱƉƉŐĨŽůůŽǁĞĚďǇϭϬϬďďůƐϭϱ͘ϯƉƉŐƚĂŝů͘ ϳͬϯͬϭϰh^/dƐŚŽǁƐ'ŽŽĚĐĞŵĞŶƚƵƉƚŽϮϭϴϬ͛DĂŶĚĨƌĞĞƉŝƉĞĂďŽǀĞϭϴϱϬ͛D ^/E'd/> ^ŝǌĞdǇƉĞtƚ'ƌĂĚĞŽŶŶ͘/dŽƉƚŵ ϯϬ͟ŽŶĚƵĐƚŽƌϯϭϬ>WͲ^ƵƌĨϯϬΖ ϮϬ͟^ƵƌĨĂĐĞĐĂƐŝŶŐϭϯϯ<ͲϱϱsĞƚĐŽϭϴ͘ϳϯ͟^ƵƌĨϮϬϳϮ͛ ϭϯͲϯͬϴΗ/ŶƚĂƐŝŶŐϲϴ<ͲϱϱdϭϮ͘ϰϭϱ͟^ƵƌĨϮϮϭϰ͛ ϭϯͲϯͬϴΗ/ŶƚĂƐŝŶŐϳϮEͲϴϬdϭϮ͘ϯϰϳ͟ϮϮϭϰ͛Ϯϯϯϲ͛ ϵͲϱͬϴ͟/ŶƚĂƐŝŶŐϰϳEͲϴϬdϴ͘ϲϴϭ͟^ƵƌĨϮϯϯϲ͛ ϱͲϭͬϮ͟WƌŽĚĂƐŝŶŐϭϳWͲϭϭϬtͬͲ,dϰ͘ϴϵϮ͟^ƵƌĨϵϳϲϳ͛ dh/E'd/> ϯͲϭͬϮ͟^ƵƌĨцϳϭϲϬ͛ ϱͲϭͬϮ͟ EŽ͘ĞƉƚŚ ;DͿ//ƚĞŵ ϭϭ͕ϴϲϵ͛ϰ͘ϴϵϮ͟^ǁĞůůWĂĐŬĞƌ ϮϮ͕ϯϰϰ͛ƵĂůƐƚƌŝŶŐĞǆŝƚƚŚƌŽƵŐŚϵͲϱͬϴ͟ĂŶĚϭϯͲϯͬϴ͟ĐĂƐŝŶŐƐ ϯцϲ͕ϱϬϴ͛/WǁŝƚŚϯϱ͛ĐĞŵĞŶƚ͗dŽΛΕϲ͕ϰϳϯ͛ ϰϳ͕ϮϬϬ͛/WǁŝƚŚϯϲ͛ĐĞŵĞŶƚ͗dŽсϳϭϲϰ͛D;ϯͬϮϲͬϮϬͿ ϱ ϴ͕ϯϵϯ͛YƵĂĚĐŽ^ƚƌĂĚĚůĞWĂƚĐŚ;ϭϱ͛ůŽŶŐͿĨƌŽŵϴϯϵϰ͛ʹϴ͕ϰϬϵ͛D ;ϭͬϮϱͬϮϬͿ ϲϴ͕ϱϰϰ͛/W;ϭϭͬϱͬϭϵͿ ϳϴ͕ϳϱϬ͛/WǁŝƚŚϱ͛ĐĞŵĞŶƚ͗dŽсϴϳϰϱ͛D;ϯͬϭϲͬϭϲͿ ϴ ϵ͕ϭϭϬ͛/W;ϳͬϮϯͬϭϰͿ͘ƵŵƉĞĚϯϱ͛ĐĞŵĞŶƚŽŶƚŽƉŽĨĨŝůůŽŶ ϯͬϭϲͬϭϲ͗dŽсϵϬϱϮ͛D ϭϯͲϯͬϴ͟ ĂŶĚ ϵͲϱͬϴ͟ ϰ ϱ ϲ ϳ ϴ ϮϬ͟ ZdĂŐƐ͗Ϯϵϵϴ͕ϱϳϮϳ͕ϴϱϯϲ͕ϴϲϳϴ͕ ϴϵϵϵ͕ϵϭϴϴ DĂǆŝŶĐ͗ϰϬĚĞŐĂƚϯϰϳϮ͛D DĂǆ>^͗ϴĚĞŐͬϭϬϬ͛ĂƚϮϳϮϵ͛D ϭ Ϯ ^ƚĞƌůŝŶŐ ĞůƵŐĂ ϯ hƉĚĂƚĞĚďǇDϬϱͬϭϯͬϮϮ WZKWK^ hͲϳ WĂĚϳ Wd͗ϮϭϰͲϬϲϬ W/͗ϱϬͲϭϯϯͲϮϬϮϴϰͲϬϭͲϬϬ /^K>dWZ&KZd/KE^ WZ&KZd/KEd/> ŽŶĞdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ&d ĂƚĞ ^ƚĂƚƵƐ DͺĞůϳ͕ϮϰϮΖϳ͕ϮϱϮΖϲ͕ϰϱϴΖϲ͕ϰϲϲΖϭϬΖ/ƐŽůĂƚĞĚ Ͳϭϲϴ͕ϬϭϱΖϴ͕ϬϮϲΖϳ͕ϭϲϲΖϳ͕ϭϳϳΖϭϭΖ/ƐŽůĂƚĞĚ Ͳϭϲϴ͕ϬϭϲΖϴ͕ϬϮϲΖϳ͕ϭϲϳΖϳ͕ϭϳϳΖϭϬΖ/ƐŽůĂƚĞĚ ^Zͺ>'dϴ͕ϬϳϰΖϴ͕ϬϴϭΖϳ͕ϮϮϰΖϳ͕ϮϯϬΖϳΖ/ƐŽůĂƚĞĚ ^Zͺ>'dϴ͕ϬϳϱΖϴ͕ϬϴϭΖϳ͕ϮϮϱΖϳ͕ϮϯϬΖϲΖ/ƐŽůĂƚĞĚ Ͳϭϳϴ͕ϭϮϳΖϴ͕ϭϰϮΖϳ͕ϮϳϱΖϳ͕ϮϵϬΖϭϱΖ/ƐŽůĂƚĞĚ Ͳϭϵϴ͕ϮϰϱΖϴ͕ϮϱϱΖϳ͕ϯϵϬΖϳ͕ϰϬϬΖϭϬΖ/ƐŽůĂƚĞĚ ͲϮϬϴ͕ϮϴϵΖϴ͕ϮϵϵΖϳ͕ϰϯϯΖϳ͕ϰϰϯΖϭϬΖ/ƐŽůĂƚĞĚ ͲϮϬϴ͕ϯϵϲΖϴ͕ϰϬϲΖϳ͕ϱϯϴΖϳ͕ϱϰϳΖϭϬΖWĂƚĐŚĞĚ;ϭͬϮϱͬϮϬͿ ͲϮϭϴ͕ϰϱϭΖϴ͕ϰϱϲΖϳ͕ϱϵϮΖϳ͕ϱϵϳΖϱΖ/ƐŽůĂƚĞĚ ͲϮϭ>tZϴ͕ϰϵϲΖϴ͕ϱϬϲΖϳ͕ϲϯϲΖϳ͕ϲϰϲΖϭϬΖ/ƐŽůĂƚĞĚ ͲϮϮϴ͕ϱϲϬΖϴ͕ϱϳϱΖϳ͕ϲϵϵΖϳ͕ϳϭϰΖϭϱΖ/ƐŽůĂƚĞĚ;ϭϭͬϱͬϭϵͿ >ͲϮϯϴ͕ϲϭϬΖϴ͕ϲϮϬΖϳ͕ϳϰϴΖϳ͕ϳϱϴΖϭϬΖ/ƐŽůĂƚĞĚ;ϭϭͬϱͬϭϵͿ >ͲϮϱϴ͕ϳϬϴΖϴ͕ϳϮϴΖϳ͕ϴϰϱΖϳ͕ϴϲϰΖϮϬΖ/ƐŽůĂƚĞĚ;ϭϭͬϱͬϭϵͿ >ͲϮϲϴ͕ϳϳϬΖϴ͕ϳϴϬΖϳ͕ϵϬϲΖϳ͕ϵϭϲΖϭϬΖ/ƐŽůĂƚĞĚ;ϯͬϭϲͬϭϲͿ >ͲϮϳϴ͕ϴϮϬΖϴ͕ϴϯϬΖϳ͕ϵϱϱΖϳ͕ϵϲϱΖϭϬΖ/ƐŽůĂƚĞĚ;ϯͬϭϲͬϭϲͿ >ͲϮϵϵ͕ϬϰϱΖϵ͕ϬϲϬΖϴ͕ϭϳϴΖϴ͕ϭϵϯΖϭϱΖ/ƐŽůĂƚĞĚ;ϯͬϭϲͬϭϲͿ >ͲϯϬϵ͕ϭϮϯΖϵ͕ϭϯϱΖϴ͕ϮϱϱΖϴ͕ϮϲϳΖϭϮΖ/ƐŽůĂƚĞĚ;ϳͬϮϯͬϭϰͿ >ͲϯϬϵ͕ϭϱϱΖϵ͕ϭϲϱΖϴ͕ϮϴϳΖϴ͕ϮϵϳΖϭϬΖ/ƐŽůĂƚĞĚ;ϳͬϮϯͬϭϰͿ >Ͳϯϭϵ͕ϮϭϬΖϵ͕ϮϮϭΖϴ͕ϯϰϭΖϴ͕ϯϱϮΖϭϭΖ/ƐŽůĂƚĞĚ;ϳͬϮϯͬϭϰͿ %HDYHU&UHHN8QLW %&$&XUUHQW sĂůǀĞ͕DĂƐƚĞƌ͕/tͲ&͕ ϱϭͬϴϭϬD&͕,tK͕ ƚƌŝŵ sĂůǀĞ͕hƉƉĞƌDĂƐƚĞƌ͕ t<DͲD͕ϱϭͬϴϱD&͕,tK͕ ƚƌŝŵ sĂůǀĞ͕^ǁĂď͕t<DͲD͕ ϱϭͬϴϱD&͕,tK͕ ƚƌŝŵ sĂůǀĞ͕tŝŶŐ͕t<DͲD͕ ϯϭͬϴϱD&͕,tK͕ ƚƌŝŵ dƌĞĞĐĂƉ͕KƚŝƐ͕ϱϭͬϴϱD&y ϵЪKƚŝƐYƵŝĐŬhŶŝŽŶ ƌŽƐƐŽǀĞƌƐƉŽŽů͕ ϱϭͬϴϱD&yϱϭͬϴϭϬD& ĂƐŝŶŐƐƉŽŽů͕KdͲϮϮͲW͕ ϮϭЬϮDyϭϯϱͬϴϱD͕ ǁͬϮͲϯϭͬϴϱD&K͕ KKďŽƚƚŽŵƉƌĞƉ 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777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 1/11/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 7A (PTD 214-060) Gamma Ray Correlation & Perf 11/10/2021 Please include current contact information if different from above. 37' (6HW Received By: 01/12/2022 By Abby Bell at 12:35 pm, Jan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y Samantha Carlisle at 12:34 pm, Dec 07, 2021 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH SFD 12/7/2021 RBDMS HEW 12/9/2021 BJM 01/12/22 DSR-12/7/21 1 Winston, Hugh E (OGC) From:Jacob Flora <Jake.Flora@hilcorp.com> Sent:Wednesday, September 1, 2021 3:27 PM To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] BCU-07A (PTD 214-060) Velocity String Sundry Bryan, We will RU a whip (short coil section), RIH w a GS, engage and pull hanger above the BOPs into the lubricator, close pipe and slips, pick lubricator up to expose GS XN, cut off, redress coil and install a double dimple connector, stab lubricator, spool OOH. Then main thing here would be the fact the coil hanger will pick up into the lubricator. Let me know if you need more detail. Thanks, Jake From: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Sent: Wednesday, September 1, 2021 3:14 PM To: Jacob Flora <Jake.Flora@hilcorp.com> Subject: [EXTERNAL] BCU‐07A (PTD 214‐060) Velocity String Sundry Jake, Could you explain how you intend to maintain pressure control while pulling the velocity string on this well, including when you pull the hanger? Thanks 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 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. 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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: Pull velocity string, 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):Junk (MD): 9,800'N/A Casing Collapse Structural Conductor Surface 1,500 psi Intermediate 1,950 psi Production 4,750 psi Liner 7,460 psi 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 Plugs (MD): 3,012; 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 8, 2021 9,767'9,767' N/A 8,896' 2,336' Perforation Depth MD (ft): 2,336' See Attached Schematic 2,336' 5-1/2" 2,336'9-5/8" 30" 20" 35' 13-3/8"2,336' 2,072'3,060 psi 35' 2,077' 2,336' 35' 2,072' N/A TVD Burst N/A 6,870 psi MD 3,450 psi Length Size CO 236A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028118 214-060 50-133-20284-01-000 Beaver Creek Unit (BCU) 07A Beaver Creek / Beaver Creek Oil - Beluga Gas Pool COMMISSION USE ONLY Authorized Name: 10,640 psi Tubing Grade: Tubing MD (ft): See Attached Schematic jake.flora@hiclorp.com 8,929'3,012'2,992'~998 psi 7164; 8543, 8750, 9110 Swell Pkr: N/A 1,869' MD/TVD; N/A, N/A Perforation Depth TVD (ft): Tubing Size: Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Wellbore schematic Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:19 pm, Aug 23, 2021 321-415 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.08.23 12:58:35 -08'00' Taylor Wellman (2143) BOP test to 4000 psi. 10-404 BJM 9/2/21 X DSR-8/23/21 SFD 8/23/2021 SFD 8/23/2021 Sterling Undefined Gas Pool - 20 AAC 25.050; Beluga Gas Pool - CO 237B SFD 8/23/2021 - Sterling Undefined Gas Pool dts 9/2/2021 9/3/2021Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.09.03 07:39:32 -08'00' RBDMS HEW 9/3/2021 Well Prognosis Well: BCU-07A Date: 8/23/2020 Well Name: BCU-07A API Number: 50-133-20284-01 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: September 8, 2021 Rig: N/A Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-060 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Second Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) AFE Number: Current BHP: ~ 1,294 psi @ 2,962’ TVD (Based on .437 Pressure Gradient) Max. Expected BHP: ~ 1,294 psi @ 2,962’ TVD (Based on .437 Pressure Gradient.) Max. Potential Surface Pressure: ~ 998 psi (Based on actual reservoir pressure less gas gradient to surface (0.10psi/ft) Well Status: BCU-07A is currently a Sterling D sand gas producer currently offline. Summary: The BCU-07A was drilled and completed as a 5-1/2” monobore in 2014 targeting the Lower Beluga at Beaver Creek. Several lower Beluga sands were tested and would not sustain flow. The LB 23 & 25 came online making right about 2 MMCFD with little to no water. Most of the beluga sands were eventually added in a plug and perf style approach until the well finally died off in October 2019 after making 1.05 BCF of gas. On April 1, 2020 the Sterling D sands were added coming online at 3.0 MMCFD and 75 BWPD. The well dropped off to 1.8 MMCFD which was well below the unloading rate and a 2-3/8” coil V-string was installed on May 14, 2020. The well cum’d just over 0.2 BCF before completely watering out and wouldn’t sustain flow in August of 2021. A capillary string was installed in May 2020 and later pulled January 2021. The purpose of this work/sundry is to pull the 2-3/8” velocity string, plug back and perforate up-hole Sterling. Notes Regarding Wellbore Condition: x CIBP set @ 3,012’ x Coil Tubing Hanger installed above master Valve Variance Request: x A variance to 20 AAC 25.112(g) requiring pressure testing of plugs is requested due to the need to keep water off of sensitive formations, and the mechanical unfeasibility of pressure testing each CIBP with water and not having a way to then remove that water from the wellbore. Each plug will be tagged once after setting and again during cement bailing. x A variance to 20 AAC 25.112(c)(1)(E) requiring 25’ cement over a CIBP is requested due to the close proximity of the perforations being plugged and added. Procedure: 1. MIRU Coiled Tubing, PT BOPE to 4,000 psi Hi 250 Low. 2. MU GS pulling tool, engage coil hanger, drop pump down dart plug , pump and seat plug in nipple at bottom of velocity string. This will isolate coil from reservoir. 3. PU and pull 2-3/8” Coil velocity string. Since these perfs and plugs are in the same Sterling undefined gas pool, testing of plugs is not required. - bjm Since these perfs and plugs are in the same Sterling undefined gas pool, cement is not required on top of the plugs. - bjm o pull the 2-3/8” velocity string, plug back and perforate up-hole Sterling. See attached email for more detail on maintaining well control while pulling CT velocity string hanger - bjm BCU-07A is currently a Sterling D sand gas producer currently offline. Well Prognosis Well: BCU-07A Date: 8/23/2020 4. RDMO coil tubing. 5. RU nitrogen, following Hilcorp’s nitrogen SOP pressure as needed to depress fluid level to the existing perforations. 6. RU E-line. PT Lubricator to 3500 psi. 7. Dump 10’ of cement on existing CIBP at 3012’. 8. Set CIBP over existing perforations at 2965’ and dump 10’ cement on plug. 9. Tag plug and cement. 10. Perforate Sterling sands per the below table: FORMATION INTERVAL (Status) MD TOP MD Base Total Ftg TVd TOP TVD Bot Sterling D1Z ±2,895’ ±2,905’ ±10 ±2,883’ ±2,894’ Sterling D1Y ±2,910’ ±2,924’ ±14 ±2,898’ ±2,911’ 11. Turn well over to production. Contingency: (If zone at 2910-2924’ is wet) 1. RU E-line, PT lubricator to 3500 psi. 2. Set CIBP over open perfs at ~2905’ with no cement on plug due to proximity of perforation sets. 3. Perforate next zone up at 2895’ – 2905’. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Coil BOPE Schematic 4. Standard Well Procedure- Nitrogen State/Prov:Alaska Country:USA 122.7' Downhole Revision Date: Schematic Revision Date: 0.0º @ 2,336'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: 7/30/2020 Well Name & Number:Beaver Creek Unit #7A A - 028118 County or Parish:Kenai Peninsula Borough Lease: 39.9º @ 3,350' Date Completed:6/23/2014 Ground Level (above MSL): RKB (above GL): 3.5º to 10.0º 18.5' Revised By:Donna Ambuz BCU - 7A Pad 7 1,800 FNL, 2,050' FEL, Sec. 4, T6N, R10W, S.M. TD: 9,800' MD 8,929' TVD Conductor 30" LP-B 310# weight Top Bottom MD 0' 35' TVD 0' 35' Surface Casing 20" K-55 133.33# weight Top Bottom MD 0' 2,072' TVD 0' 2,072' 26" hole cmt w/ 3,200 sks of Class-G Intermediate Casing 13-3/8" BTC Top Bottom MD 0' 2,214' K-55, 68# MD 2,214' 2,336' N-80, 72# 17-1/2" hole cmt w/ 2,750 sks of Class-G, Intermediate Casing 9-5/8" BTC Top Bottom MD 0' 2,336' N-80, 47.0# 12-1/4" hole cmt w/ 3,185 sks of Class-G Jewelry 1. Swell Packer (21' Long) 1A. V-String Bottom Nipple 1B. CIBP 4.24" 3/31/20 2. CIBP 4.25" (w/36' of cement) 3/27/20 3. Straddle Assembly 15' Long (1/25/20) 4. CIBP (11/5/19) 5. CIBP 5-1/2" Depth 1,869' 2,950' 3,012' 7,200' 8,394'- 8,409' 8,543' 8,750' Permit #:214-060 API #:50-133-20284-01 Prop. Des:FED A-028118 KB elevation:141.2' (18.5' AGL) Lat:N60° 38' 32.402" Long:W151° 2' 16.440" Spud:6/02/2014 01:00 hrs TD:6/19/2014 12:30 hrs Rig Released:6/24/2014 6:00 hrs PBTD: 3,012' MD 2,992' TVD SCHEMATIC 13-3/8" casing cmt top @ 2,130' (CBL 6/08/76) 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom MD 0' 9,767' TVD 0' 8,896' 7-7/8" hole Cmt w/ 791 sks ( 245 bbls) of 11.5 ppg, Lite Crete, 413 sks ( 100 bbls) of 15.3 ppg, Class G 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 (35 bbl) - 11.5 ppg Cement (245 bbl) - 15.3 ppg Cement (100 bbl) - 8.4 ppg Lease Water (226 bbl) Max Dogleg: 11.84°/100' @ 2,353' Max Inclination: 39.9° @ 3,350' RA Mkr Jt 5,727' RA Mkr Jt 2,998' RA Mkr Jt 8,536' RA Mkr Jt 8,678' RA Mkr Jt 8,999' RA Mkr Jt 9,188' TOC (USIT 7/3/14) - 1,850' Openhole Casing 33' off bottom Casing Shoe @ 9,767' LB-31 Perforations: Zone MD TVD Size SPF Date Sterling D1X 2,974'-2,979' 2,957'-2,962' 3-3/8" 6 03/31/20 Sterling D1 3,018'-3,020' 2,997'-2,999' 3-3/8" 6 03/27/20 M_Bel 7,242'-7,252' 6,458'-6,466' 2-7/8" 10 10/29/19 B-16 8,015'-8,026' 7,166'-7,177' 2-7/8" 11 02/02/20 B-16 8,016'-8,026' 7,167'-7,177' 2-7/8" 10 10/29/19 SR_LBGT 8,074'-8,081' 7,224'-7,230' 2-7/8" 6 02/02/20 SR_LBGT 8,075'-8,081' 7,225'-7,230' 2-7/8" 6 10/29/19 B-17 8,127'-8,142' 7,275'-7,290' 2-7/8" 15 03/14/19 B-19 8,245'-8,255' 7,390'-7,400' 2-7/8" 10 03/14/19 B-20 8,289'-8,299' 7,433'-7,443' 2-7/8" 10 03/14/19 B-20 8,396'-8,406' 7,538'-7,547' 2-7/8" 10 03/14/19 B-21 8,451-8,456' 7,592'-7,597' 2-7/8" 5 02/11/19 B-21 LWR 8,496'-8,506' 7,636'-7,646' 2-7/8" 10 02/22/19 B-22 8,560'-8,575' 7,699'-7,714' 2-7/8" 15 02/22/19 LB-23 8,610'-8,620' 7,748'-7,758' 3-3/8" 6 08/08/14 LB-25 8,708'-8,728' 7,845'-7,864' 3-3/8" 6 08/08/14 LB-26 8,770'-8,780' 7,906'-7,916' 3-3/8" 6 08/08/14 LB-27 8,820'-8,830' 7,955'-7,965' 3-3/8" 6 08/08/14 LB-29 9,045'-9,060' 8,178'-8,193' 3-3/8" 6 07/25/14 LB-30 9,123'-9,135' 8,255'-8,267' 3-3/8" 6 07/20/14 LB-30 9,155'-9,165' 8,287'-8,297' 3-3/8" 6 07/20/14 LB-30 LB-30 5 LB-29 LB-27 LB-26 LB-25 LB-23 TOC 9,052' TOC 8,745' B-17 B-19 B-20 B-21 B-21 LWR B-22 M_Bel B-16 SR_LBGT B-20 4 3 Sterling D1X 2 Sterling D1 TOC 7,164' 1B 1A Coil Velocity String 2.375" CT x .188 wall. 1.999 I.D. (coil has seam) Quality tubing QT-900 V string volume 11.45 bbls Set EOT @ 2950' RKB Run/pulling tool 3" GS spear. State/Prov:Alaska Country:USA 122.7' Downhole Revision Date: Schematic Revision Date: 0.0º @ 2,336'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: 7/30/2020 Well Name & Number:Beaver Creek Unit #7A A - 028118 County or Parish:Kenai Peninsula Borough Lease: 39.9º @ 3,350' Date Completed:6/23/2014 Ground Level (above MSL): RKB (above GL): 3.5º to 10.0º 18.5' Revised By:Donna Ambuz BCU - 7A Pad 7 1,800 FNL, 2,050' FEL, Sec. 4, T6N, R10W, S.M. TD: 9,800' MD 8,929' TVD Conductor 30" LP-B 310# weight Top Bottom MD 0' 35' TVD 0' 35' Surface Casing 20" K-55 133.33# weight Top Bottom MD 0' 2,072' TVD 0' 2,072' 26" hole cmt w/ 3,200 sks of Class-G Intermediate Casing 13-3/8" BTC Top Bottom MD 0' 2,214' K-55, 68# MD 2,214' 2,336' N-80, 72# 17-1/2" hole cmt w/ 2,750 sks of Class-G, Intermediate Casing 9-5/8" BTC Top Bottom MD 0' 2,336' N-80, 47.0# 12-1/4" hole cmt w/ 3,185 sks of Class-G Jewelry 1. Swell Packer (21' Long) 1A. V-String Bottom Nipple 1B. CIBP 4.24" 3/31/20 2. CIBP 4.25" (w/36' of cement) 3/27/20 3. Straddle Assembly 15' Long (1/25/20) 4. CIBP (11/5/19) 5. CIBP 5-1/2" Depth 1,869' 2,950' 3,012' 7,200' 8,394'- 8,409' 8,543' 8,750' Permit #:214-060 API #:50-133-20284-01 Prop. Des:FED A-028118 KB elevation:141.2' (18.5' AGL) Lat:N60° 38' 32.402" Long:W151° 2' 16.440" Spud:6/02/2014 01:00 hrs TD:6/19/2014 12:30 hrs Rig Released:6/24/2014 6:00 hrs PBTD: 3,012' MD 2,992' TVD PROPOSED 13-3/8" casing cmt top @ 2,130' (CBL 6/08/76) 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom MD 0' 9,767' TVD 0' 8,896' 7-7/8" hole Cmt w/ 791 sks ( 245 bbls) of 11.5 ppg, Lite Crete, 413 sks ( 100 bbls) of 15.3 ppg, Class G 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 (35 bbl) - 11.5 ppg Cement (245 bbl) - 15.3 ppg Cement (100 bbl) - 8.4 ppg Lease Water (226 bbl) Max Dogleg: 11.84°/100' @ 2,353' Max Inclination: 39.9° @ 3,350' RA Mkr Jt 5,727'RA Mkr Jt 2,998' RA Mkr Jt 8,536'RA Mkr Jt 8,678' RA Mkr Jt 8,999' RA Mkr Jt 9,188' TOC (USIT 7/3/14) - 1,850' Openhole Casing 33' off bottom Casing Shoe @ 9,767' Perforations: Zone MD TVD Size SPF Date Sterling D1X 2,974'-2,979' 2,957'-2,962' 3-3/8" 6 03/31/20 Sterling D1 3,018'-3,020' 2,997'-2,999' 3-3/8" 6 03/27/20 M_Bel 7,242'-7,252' 6,458'-6,466' 2-7/8" 10 10/29/19 B-16 8,015'-8,026' 7,166'-7,177' 2-7/8" 11 02/02/20 B-16 8,016'-8,026' 7,167'-7,177' 2-7/8" 10 10/29/19 SR_LBGT 8,074'-8,081' 7,224'-7,230' 2-7/8" 6 02/02/20 SR_LBGT 8,075'-8,081' 7,225'-7,230' 2-7/8" 6 10/29/19 B-17 8,127'-8,142' 7,275'-7,290' 2-7/8" 15 03/14/19 B-19 8,245'-8,255' 7,390'-7,400' 2-7/8" 10 03/14/19 B-20 8,289'-8,299' 7,433'-7,443' 2-7/8" 10 03/14/19 B-20 8,396'-8,406' 7,538'-7,547' 2-7/8" 10 03/14/19 B-21 8,451-8,456' 7,592'-7,597' 2-7/8" 5 02/11/19 B-21 LWR 8,496'-8,506' 7,636'-7,646' 2-7/8" 10 02/22/19 B-22 8,560'-8,575' 7,699'-7,714' 2-7/8" 15 02/22/19 LB-23 8,610'-8,620' 7,748'-7,758' 3-3/8" 6 08/08/14 LB-25 8,708'-8,728' 7,845'-7,864' 3-3/8" 6 08/08/14 LB-26 8,770'-8,780' 7,906'-7,916' 3-3/8" 6 08/08/14 LB-27 8,820'-8,830' 7,955'-7,965' 3-3/8" 6 08/08/14 LB-29 9,045'-9,060' 8,178'-8,193' 3-3/8" 6 07/25/14 LB-30 9,123'-9,135' 8,255'-8,267' 3-3/8" 6 07/20/14 LB-30 9,155'-9,165' 8,287'-8,297' 3-3/8" 6 07/20/14 5 TOC 9,052' TOC 8,745' 4 3 2974-2979' 2 TOC 7,164' 1B 1A 2895'-2924' proposed perfs 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 Coil Tubing BOP STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Install Cap String, N2 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: 3,012; 7,164; 8,543; Total Depth measured 9,800 feet 8,750; 9,110 feet true vertical 8,929 feet N/A feet Effective Depth measured 3,012 feet 1,869 feet true vertical 2,992 feet 1,869 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Cap String 3/8' 2,925' MD 2,912' TVD Tubing (size, grade, measured and true vertical depth)CT Vel String 2-3/8' QT 900 2,950' MD 2,935' TVD Packers and SSSV (type, measured and true vertical depth)Swell Pkr; N/A 1,869' MD/TVD N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 WINJ WAG 847 Water-Bbl MD 35' 2,072' 9,767' 90 Oil-Bbl measured true vertical Packer 9-5/8" 5-1/2" 2,336' 2,336' 2,336' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beaver Creek / Beaver Creek Oil - Beluga Gas PoolN/A measured TVD Tubing Pressure 35779 Beaver Creek Unit (BCU) 07A N/A FEDA028118 2,336' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-060 50-133-20284-01-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-222 363 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 9,767' 407 8,896' 0 Representative Daily Average Production or Injection Data 3' 2,072' 2,336' 2,336' Conductor Surface Intermediate Production 7,460psi 4,750psi Casing Structural 20" 20" 13-3/8" Length 3,450psi 3,060psi Collapse 1,500psi 1,950psi tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: 10,640psi Burst 6,870psi 35' 2,077' t Fra O 6. A G L PG , R 2 Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:25 am, Aug 17, 2020 gg Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.08.14 13:26:16 -08'00' Taylor Wellman RBDMS HEW 8/17/2020 gls 9/17/20 Install Cap String, N22 Sterling Undefined Gas SFD 8/17/2020DSR-8/17/2020 SFD 8/17/2020 Rig Start Date End Date Cap String 6/5/20 7/30/20 07/29/2020 -Wednesday Discussed with Reservoir Engineer if we should change set depth of Cap string. Decided to not make the change. Run 3/8" Cap string to 2,925'. Hang off string and set spool on ground. Depart with cap string truck and deliver to Falls Creek. 06/05/2020 - Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU 07A 50-133-20284-01-00 214-060 State/Prov:Alaska Country:USA 122.7' Downhole Revision Date:Schematic Revision Date: 0.0º @ 2,336'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: 7/30/2020 Well Name & Number:Beaver Creek Unit #7A A - 028118 County or Parish:Kenai Peninsula Borough Lease: 39.9º @ 3,350' Date Completed:6/23/2014 Ground Level (above MSL):RKB (above GL): 3.5º to 10.0º 18.5' Revised By:Donna Ambuz BCU - 7A Pad 7 1,800 FNL, 2,050' FEL, Sec. 4, T6N, R10W, S.M. TD: 9,800' MD 8,929' TVD Conductor 30" LP-B 310# weight Top Bottom MD 0' 35' TVD 0' 35' 36" hole cmt w/ 500 sks of Class-G Surface Casing 20" K-55 133.33# weight Top Bottom MD 0' 2,072' TVD 0' 2,072' 26" hole cmt w/ 3,200 sks of Class-G Intermediate Casing 13-3/8" BTC Top Bottom MD 0' 2,214' K-55, 68# MD 2,214' 2,336' N-80, 72# 17-1/2" hole cmt w/ 2,750 sks of Class-G, bumped plug Intermediate Casing 9-5/8" BTC Top Bottom MD 0' 2,336' N-80, 47.0# 12-1/4" hole cmt w/ 3,185 sks of Class-G Jewelry 1. Swell Packer (21' Long) 1A. V-String Bottom Nipple 1B. CIBP 4.24" 3/31/20 2. CIBP 4.25" (w/36' of cement) 3/27/20 3. Straddle Assembly 15' Long (1/25/20) 4. CIBP (11/5/19) 5. CIBP 5-1/2" 6. CIBP 5-1/2" CIBP (Tested to 2,260 psi N2) Depth 1,869' 2,950' 3,012' 7,200' 8,394'- 8,409' 8,543' 8,750' 9,110' Permit #:214-060 API #:50-133-20284-01 Prop. Des:FED A-028118 KB elevation:141.2' (18.5' AGL) Lat:N60°38' 32.402" Long:W151°2' 16.440" Spud:6/02/2014 01:00 hrs TD:6/19/2014 12:30 hrs Rig Released:6/24/2014 6:00 hrs PBTD: 3,012' MD 2,992' TVD SCHEMATIC 13-3/8" casing cmt top @ 2,130' (CBL 6/08/76) 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom MD 0' 9,767' TVD 0' 8,896' 7-7/8" hole Cmt w/ 791 sks ( 245 bbls) of 11.5 ppg, Lite Crete, 413 sks ( 100 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK 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 (35 bbl) - 11.5 ppg Cement (245 bbl) - 15.3 ppg Cement (100 bbl) - 8.4 ppg Lease Water (226 bbl) Max Dogleg: 11.84°/100' @ 2,353' Max Inclination: 39.9°@ 3,350' RA Mkr Jt 5,727' RA Mkr Jt 2,998' RA Mkr Jt 8,536' RA Mkr Jt 8,678' RA Mkr Jt 8,999' RA Mkr Jt 9,188' TOC (USIT 7/3/14) - 1,850' Openhole Casing 33' off bottom Casing Shoe @ 9,767' LB-31 Perforations: Zone MD TVD Size SPF Date Sterling D1X 2,974'-2,979' 2,957'-2,962' 3-3/8" 6 03/31/20 Sterling D1 3,018'-3,020' 2,997'-2,999' 3-3/8" 6 03/27/20 M_Bel 7,242'-7,252' 6,458'-6,466' 2-7/8" 10 10/29/19 B-16 8,015'-8,026' 7,166'-7,177' 2-7/8" 11 02/02/20 B-16 8,016'-8,026' 7,167'-7,177' 2-7/8" 10 10/29/19 SR_LBGT 8,074'-8,081' 7,224'-7,230' 2-7/8" 6 02/02/20 SR_LBGT 8,075'-8,081' 7,225'-7,230' 2-7/8" 6 10/29/19 B-17 8,127'-8,142' 7,275'-7,290' 2-7/8" 15 03/14/19 B-19 8,245'-8,255' 7,390'-7,400' 2-7/8" 10 03/14/19 B-20 8,289'-8,299' 7,433'-7,443' 2-7/8" 10 03/14/19 B-20 8,396'-8,406' 7,538'-7,547' 2-7/8" 10 03/14/19 B-21 8,451-8,456' 7,592'-7,597' 2-7/8" 5 02/11/19 B-21 LWR 8,496'-8,506' 7,636'-7,646' 2-7/8" 10 02/22/19 B-22 8,560'-8,575' 7,699'-7,714' 2-7/8" 15 02/22/19 LB-23 8,610'-8,620' 7,748'-7,758' 3-3/8" 6 08/08/14 LB-25 8,708'-8,728' 7,845'-7,864' 3-3/8" 6 08/08/14 LB-26 8,770'-8,780' 7,906'-7,916' 3-3/8" 6 08/08/14 LB-27 8,820'-8,830' 7,955'-7,965' 3-3/8" 6 08/08/14 LB-29 9,045'-9,060' 8,178'-8,193' 3-3/8" 6 07/25/14 LB-30 9,123'-9,135' 8,255'-8,267' 3-3/8" 6 07/20/14 LB-30 9,155'-9,165' 8,287'-8,297' 3-3/8" 6 07/20/14 LB-31 9,210'-9,221' 8,341'-8,352' 3-3/8" 12 07/16/14 LB-30 LB-30 5 LB-29 LB-27 LB-26 LB-25 LB-23 TOC 9,052' TOC 8,745' B-17 B-19 B-20 B-21 B-21 LWR B-22 M_Bel B-16 SR_LBGT B-20 4 3 Sterling D1X 2 Sterling D1 TOC 7,164' 1B 1A Coil Velocity String 2.375" CT x .188 wall. 1.999 I.D. (coil has seam) Quality tubing QT-900 V string volume 11.45 bbls Set EOT @ 2950' RKB Run/pulling tool 3" GS spear. Capillary String 6/5/20 3/8” 2205 Stainless Steel (11,500’ spool) Top Bottom MD 0’ 2,925’ TVD 0’ 2,912’ 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Install Velocity String, N2 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: 3,012; 7,164; 8,543; Total Depth measured 9,800 feet 8,750; 9,110 feet true vertical 8,929 feet N/A feet Effective Depth measured 3,012 feet 1,869 feet true vertical 2,992 feet 1,869 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)CT Vel String 2-3/8' QT 900 2,950' MD 2,791' TVD Packers and SSSV (type, measured and true vertical depth)Swell Pkr; N/A 1,869' MD/TVD N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: 10,640psi Burst 6,870psi 35' 2,077' 3,450psi 3,060psi Collapse 1,500psi 1,950psi 7,460psi 4,750psi Casing Structural 20" 20" 13-3/8" Length 3' 2,072' 2,336' 2,336' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 9,767' 847 8,896' 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-192 357 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-060 50-133-20284-01-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 9530 Beaver Creek Unit (BCU) 07A N/A FEDA028118 2,336' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beaver Creek / Beaver Creek Oil - Beluga Gas PoolN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 9-5/8" 5-1/2" 2,336' 2,336' 2,336' WINJ WAG 1,572 Water-Bbl MD 35' 2,072' 9,767' 79 t Fra O 6. A G L PG , R 2 Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:23 am, Jun 01, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.05.29 17:15:52 -08'00' Taylor Wellmangls 6/4/20 RBDMS HEW 6/1/2020 Install Velocity String, N2 DSR-6/1/2020 Rig Start Date End Date CTU 5/13/20 5/14/20 05/13/2020 - Wednesday PTW, JSA with SLB, Cruz and Hilcorp Rep. MIRU SLB CTU 13 with 2.375" CT. NOS assist to rig down wellhead and install new production tree with CT hanger assembly. Continue to rig up SLB. Start BOPE test. 24 Hr BOPE test witness notification sent 5/11/2020 @ 12:05 PM. Witness waived by Jim Regg 5/11/2020 @ 12:25 PM. Test all rams and valves to 250/4,000 psi. Prep CT BHA. Confirm connections and GS spear with Yellow Jacket. 05/14/2020 - Thursday PTW, JSA with SLB coil, Cruz Crane op, Yellow Jacket, NOS wellhead tech, and Hilcorp Rep. After 24 hrs SITP 1,025 psi. Drop 10 soap sticks down well before running V string. Pick injector head. Make up 2x 10' sticks of lubricator. Stab on well. Pump 3 bbls of water in CT 2.375" CT with 3100' on reel. Blow down with N2 to remove scale and rust from CT walls. Make up pump out plug/coil connector. BHA blow out plug and coil connector dimensions. 3.12" OD x 1.8' long. ID of 1.9". Pull test connector to 25 K. Bump connections and install anti rotation screws. Stab on well. PT stack 250/4,000 psi. Bleed down to 1,000 psi. RIH tag fill at 2,984' CTMD. Slick line previously tagged at 2989' KB. Pick up coil to 2930' and park. Close pipe and slip rams. Perform push pull -15k up to 25K. Positive engagement of pipe slips. Bleed off pressure above pipe rams and perform a no flow test. Sniff with gas monitor. Break chain friction strip injector head off BOP stack to expose pipe. Cut coil 3' above BOP stack. Dress V string end of coil and whip end of coil. Install 3" GS spear on injector end. Having troubles with installing the 1.8' long coil connector on V string end due to pipe memory of 2.375" CT. Hanger assembly installed. Surface inverted coil connector 3.25" OD x 1.65' long and 1.995" ID. 4.08' 2 7/8 4.7 lb/ft pup joint installed. 1.995" ID. 4" Hanger body. Pick injector head and latch 3" GS spear. Drop chain traction and break chain friction and scope down over V string. Screw on lubricator. Pull test coil connector to 25K. Space out measurements from coil hanger bottom shoulder to bottom shoulder hanger lock down bolts 20.5'. Open BOP EQ ports to equalize pressure. 950 psi. Open pipe and slip rams. RIH 19' and park. NOS wellhead tech engage lower hanger bolts 3-11/16". Land V string 20.6'. Engage upper hanger bolts. Attempt to pressure test hanger seals to 2500 psi. Pressure would drop to 2,000 psi over 1 minute. PU coil 2k over in tension. Turn in lower hanger bolts. Slack off coil to neutral weight. PT hanger seals to 2,500 psi for 5 minutes with zero loss. Rig down NOS tools. N2 cooled down. Online with N2 down CT whip end. 3" spear has plug in bottom to change from flow activated piston release to pressure activated release. -2K down on hanger and 750 psi on CT to release 3" GS spear. Pick up and tag CT pack off assembly. Swap vales and continue pumping N2 down V string to shear pump out plug. 3500 psi pump out plug released. Close master and swab valves with 1,025 psi SITP. Bleed down surface coil. Pop off well and break down tools. Rig down CTU 13. 28,400 scf pumped ( 305 gallons) Coil V string completion info: 2.375" CT x .188 wall. 1.999 I.D. (coil has seam), Quality tubing QT-900, V string volume 11.45 bbls, Set EOT @ 2,950' RKB, Run/pulling tool 3" GS spear. Daily Operations: Hilcorp Alaska, LLC Weekly Operations Summary API Number Well Permit NumberWell Name BCU 07A 50-133-20284-01-00 214-060 Swap vales and continue pumping N2 down V string to shear pump out plug. 3500 psi pump out plug released. BHA blow out plug and coil connector dimensions. Cut coil 3' above BOP stack. k. NOS wellhead tech engage lower hanger bolts 3-11/16" RIH tag fill at 2,984' CTMD. Pick injector head and latch 3" GS spear. Sniff with gas NOS assist to rig down wellhead and install new production tree with CT hanger assembly. Pump 3 bbls of water in CT 2.375" CT with 3100' on reel. State/Prov:Alaska Country:USA 122.7' Downhole Revision Date:Schematic Revision Date: 0.0º @ 2,336'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: 5/15/2020 Well Name & Number:Beaver Creek Unit #7A A - 028118 County or Parish:Kenai Peninsula Borough Lease: 39.9º @ 3,350' Date Completed:6/23/2014 Ground Level (above MSL):RKB (above GL): 3.5º to 10.0º 18.5' Revised By:Donna Ambuz BCU - 7A Pad 7 1,800 FNL, 2,050' FEL, Sec. 4, T6N, R10W, S.M. TD: 9,800' MD 8,929' TVD Conductor 30" LP-B 310# weight Top Bottom MD 0' 35' TVD 0' 35' 36" hole cmt w/ 500 sks of Class-G Surface Casing 20" K-55 133.33# weight Top Bottom MD 0' 2,072' TVD 0' 2,072' 26" hole cmt w/ 3,200 sks of Class-G Intermediate Casing 13-3/8" BTC Top Bottom MD 0' 2,214' K-55, 68# MD 2,214' 2,336' N-80, 72# 17-1/2" hole cmt w/ 2,750 sks of Class-G, bumped plug Intermediate Casing 9-5/8" BTC Top Bottom MD 0' 2,336' N-80, 47.0# 12-1/4" hole cmt w/ 3,185 sks of Class-G Jewelry 1. Swell Packer (21' Long) 1A. V-String Bottom Nipple 1B. CIBP 4.24" 3/31/20 2. CIBP 4.25" (w/36' of cement) 3/27/20 3. Straddle Assembly 15' Long (1/25/20) 4. CIBP (11/5/19) 5. CIBP 5-1/2" 6. CIBP 5-1/2" CIBP (Tested to 2,260 psi N2) Depth 1,869' 2,950' 3,012' 7,200' 8,394'- 8,409' 8,543' 8,750' 9,110' Permit #:214-060 API #:50-133-20284-01 Prop. Des:FED A-028118 KB elevation:141.2' (18.5' AGL) Lat:N60°38' 32.402" Long:W151°2' 16.440" Spud:6/02/2014 01:00 hrs TD:6/19/2014 12:30 hrs Rig Released:6/24/2014 6:00 hrs PBTD: 3,012' MD 2,992' TVD SCHEMATIC 13-3/8" casing cmt top @ 2,130' (CBL 6/08/76) 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom MD 0' 9,767' TVD 0' 8,896' 7-7/8" hole Cmt w/ 791 sks ( 245 bbls) of 11.5 ppg, Lite Crete, 413 sks ( 100 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK 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 (35 bbl) - 11.5 ppg Cement (245 bbl) - 15.3 ppg Cement (100 bbl) - 8.4 ppg Lease Water (226 bbl) Max Dogleg: 11.84°/100' @ 2,353' Max Inclination: 39.9°@ 3,350' RA Mkr Jt 5,727' RA Mkr Jt 2,998' RA Mkr Jt 8,536' RA Mkr Jt 8,678' RA Mkr Jt 8,999' RA Mkr Jt 9,188' TOC (USIT 7/3/14) - 1,850' Openhole Casing 33' off bottom Casing Shoe @ 9,767' LB-31 Perforations: Zone MD TVD Size SPF Date Sterling D1X 2,974'-2,979' 2,957'-2,962' 3-3/8" 6 03/31/20 Sterling D1 3,018'-3,020' 2,997'-2,999' 3-3/8" 6 03/27/20 M_Bel 7,242'-7,252' 6,458'-6,466' 2-7/8" 10 10/29/19 B-16 8,015'-8,026' 7,166'-7,177' 2-7/8" 11 02/02/20 B-16 8,016'-8,026' 7,167'-7,177' 2-7/8" 10 10/29/19 SR_LBGT 8,074'-8,081' 7,224'-7,230' 2-7/8" 6 02/02/20 SR_LBGT 8,075'-8,081' 7,225'-7,230' 2-7/8" 6 10/29/19 B-17 8,127'-8,142' 7,275'-7,290' 2-7/8" 15 03/14/19 B-19 8,245'-8,255' 7,390'-7,400' 2-7/8" 10 03/14/19 B-20 8,289'-8,299' 7,433'-7,443' 2-7/8" 10 03/14/19 B-20 8,396'-8,406' 7,538'-7,547' 2-7/8" 10 03/14/19 B-21 8,451-8,456' 7,592'-7,597' 2-7/8" 5 02/11/19 B-21 LWR 8,496'-8,506' 7,636'-7,646' 2-7/8" 10 02/22/19 B-22 8,560'-8,575' 7,699'-7,714' 2-7/8" 15 02/22/19 LB-23 8,610'-8,620' 7,748'-7,758' 3-3/8" 6 08/08/14 LB-25 8,708'-8,728' 7,845'-7,864' 3-3/8" 6 08/08/14 LB-26 8,770'-8,780' 7,906'-7,916' 3-3/8" 6 08/08/14 LB-27 8,820'-8,830' 7,955'-7,965' 3-3/8" 6 08/08/14 LB-29 9,045'-9,060' 8,178'-8,193' 3-3/8" 6 07/25/14 LB-30 9,123'-9,135' 8,255'-8,267' 3-3/8" 6 07/20/14 LB-30 9,155'-9,165' 8,287'-8,297' 3-3/8" 6 07/20/14 LB-31 9,210'-9,221' 8,341'-8,352' 3-3/8" 12 07/16/14 LB-30 LB-30 5 LB-29 LB-27 LB-26 LB-25 LB-23 TOC 9,052' TOC 8,745' B-17 B-19 B-20 B-21 B-21 LWR B-22 M_Bel B-16 SR_LBGT B-20 4 3 Sterling D1X 2 Sterling D1 TOC 7,164' 1B 1A Coil Velocity String 2.375" CT x .188 wall. 1.999 I.D. (coil has seam) Quality tubing QT-900 V string volume 11.45 bbls Set EOT @ 2950' RKB Run/pulling tool 3" GS spear. 23/8"CT velocity string. Coil Velocity Stringyg 2.375" CT x .188 wall. 1.999 I.D. (coil has seam) Quality tubingQT-900yg V string volume 11.45 bblsg Set EOT @ 2950' RKB@ Run/pulling tool 3" GS spear. 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: Install Cap String, 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):Junk (MD): 9,800'N/A Casing Collapse Structural Conductor Surface 1,500 psi Intermediate 1,950 psi Production 4,750 psi Liner 7,460 psi 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: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 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 tkramer@hilcorp.com 8,929'3,012'2,992'~1,166 psi 7164; 8543, 8750, 9110 Swell Pkr: N/A 1,869' MD/TVD; N/A, N/A Perforation Depth TVD (ft):Tubing Size: COMMISSION USE ONLY Authorized Name: 10,640 psi 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 FEDA028118 214-060 50-133-20284-01-000 Beaver Creek Unit (BCU) 07A Beaver Creek / Beaver Creek Oil - Beluga Gas Pool Length Size CO 236A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY N/A TVD Burst N/A 6,870 psi MD 3,450 psi 3,060 psi 35' 2,077' 2,336' 35' 2,072' 30" 20" 35' 13-3/8"2,336' 2,072' Perforation Depth MD (ft): 2,336' See Attached Schematic 2,336' 5-1/2" 2,336'9-5/8" Plugs (MD): 3,012; 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: June 14, 2020 9,767'9,767' N/A 8,896' 2,336' m n P 66 t 2 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:23 am, Jun 01, 2020 320-222 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.05.29 16:53:25 -08'00' Taylor Wellman DLB 06/01/2020 X DSR-6/1/2020 10-404 Install Cap String, N22 GAS gls 6/1/20Comm 6/2/2020 dts 06012020 JLC 6/1/2020 RBDMS HEW 6/4/2020 Well Prognosis Well: BCU-07A Date: 5/29/2020 Well Name: BCU-07A API Number: 50-133-20284-01 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: June 14, 2020 Rig: N/A Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-060 First Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) Second Call Engineer: Christina Twogood (907) 777-8443 (O) (907) 378-7323 (M) AFE Number: Current BHP: ~ 1,294 psi @ 2,962’ TVD (Based on .437 Pressure Gradient) Max. Expected BHP: ~ 1,294 psi @ 2,962’ TVD (Based on .437 Pressure Gradient.) Max. Potential Surface Pressure: ~ 1,166 psi (Based on actual reservoir pressure less gas gradient to surface (0.10psi/ft) Brief Well Summary BCU-07A drilled and completed in 2014 targeting the lower Beluga formation. However, the first several sands proved to be non-productive and was plug backed to the LB-23. The well came online in the LB-23 making just over 2 MMCFD with little to no water. In February and March 2019 the Lower Beluga and a few Middle Beluga sands were perforated. In March of 2020 a plug was set at 3,012’ and the D1X sand was perforated. The well is making 1.9 MM scfd and is making 75 bwpd with it, but is struggling to keep water unloaded via the 5-1/2” casing to surface. In May 2020, A 2-3/8” coil velocity string was placed in the well to help unload water. The purpose of this work/sundry is to install a Capillary line in the well to allow for soap to be injected to help unload water. Notes Regarding Wellbore Condition x CIBP set @ 3,012’ x Coil Tubing Hanger installed above master Valve Capillary Truck Procedure: Procedure: 1. RU Cap String Truck. 2. Stab 3/8” capillary line into wellhead pack-off assembly. Make up BHA components. Install pack-off and pressure test against swab valve 250 psi low/3,000 psi high. 3. RIH with 3/8” capillary string to ±2,925’ MD. 4. Install slips and connect tubing to chemical injection pump. 5. RD Dyna Coil Unit. 6. Turn well over to production. The purpose of this work/sundry is to install a Capillary line in the well to allow for soap to be injected to help unload water. Well Prognosis Well: BCU-07A Date: 5/29/2020 Attachments: 1. Current Schematic 2. Proposed Schematic State/Prov:Alaska Country:USA 122.7' Downhole Revision Date:Schematic Revision Date: 0.0º @ 2,336'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: 5/15/2020 Well Name & Number:Beaver Creek Unit #7A A - 028118 County or Parish:Kenai Peninsula Borough Lease: 39.9º @ 3,350' Date Completed:6/23/2014 Ground Level (above MSL):RKB (above GL): 3.5º to 10.0º 18.5' Revised By:Donna Ambuz BCU - 7A Pad 7 1,800 FNL, 2,050' FEL, Sec. 4, T6N, R10W, S.M. TD: 9,800' MD 8,929' TVD Conductor 30" LP-B 310# weight Top Bottom MD 0' 35' TVD 0' 35' 36" hole cmt w/ 500 sks of Class-G Surface Casing 20" K-55 133.33# weight Top Bottom MD 0' 2,072' TVD 0' 2,072' 26" hole cmt w/ 3,200 sks of Class-G Intermediate Casing 13-3/8" BTC Top Bottom MD 0' 2,214' K-55, 68# MD 2,214' 2,336' N-80, 72# 17-1/2" hole cmt w/ 2,750 sks of Class-G, bumped plug Intermediate Casing 9-5/8" BTC Top Bottom MD 0' 2,336' N-80, 47.0# 12-1/4" hole cmt w/ 3,185 sks of Class-G Jewelry 1. Swell Packer (21' Long) 1A. V-String Bottom Nipple 1B. CIBP 4.24" 3/31/20 2. CIBP 4.25" (w/36' of cement) 3/27/20 3. Straddle Assembly 15' Long (1/25/20) 4. CIBP (11/5/19) 5. CIBP 5-1/2" 6. CIBP 5-1/2" CIBP (Tested to 2,260 psi N2) Depth 1,869' 2,950' 3,012' 7,200' 8,394'- 8,409' 8,543' 8,750' 9,110' Permit #:214-060 API #:50-133-20284-01 Prop. Des:FED A-028118 KB elevation:141.2' (18.5' AGL) Lat:N60°38' 32.402" Long:W151°2' 16.440" Spud:6/02/2014 01:00 hrs TD:6/19/2014 12:30 hrs Rig Released:6/24/2014 6:00 hrs PBTD: 3,012' MD 2,992' TVD SCHEMATIC 13-3/8" casing cmt top @ 2,130' (CBL 6/08/76) 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom MD 0' 9,767' TVD 0' 8,896' 7-7/8" hole Cmt w/ 791 sks ( 245 bbls) of 11.5 ppg, Lite Crete, 413 sks ( 100 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK 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 (35 bbl) - 11.5 ppg Cement (245 bbl) - 15.3 ppg Cement (100 bbl) - 8.4 ppg Lease Water (226 bbl) Max Dogleg: 11.84°/100' @ 2,353' Max Inclination: 39.9°@ 3,350' RA Mkr Jt 5,727' RA Mkr Jt 2,998' RA Mkr Jt 8,536' RA Mkr Jt 8,678' RA Mkr Jt 8,999' RA Mkr Jt 9,188' TOC (USIT 7/3/14) - 1,850' Openhole Casing 33' off bottom Casing Shoe @ 9,767' LB-31 Perforations: Zone MD TVD Size SPF Date Sterling D1X 2,974'-2,979' 2,957'-2,962' 3-3/8" 6 03/31/20 Sterling D1 3,018'-3,020' 2,997'-2,999' 3-3/8" 6 03/27/20 M_Bel 7,242'-7,252' 6,458'-6,466' 2-7/8" 10 10/29/19 B-16 8,015'-8,026' 7,166'-7,177' 2-7/8" 11 02/02/20 B-16 8,016'-8,026' 7,167'-7,177' 2-7/8" 10 10/29/19 SR_LBGT 8,074'-8,081' 7,224'-7,230' 2-7/8" 6 02/02/20 SR_LBGT 8,075'-8,081' 7,225'-7,230' 2-7/8" 6 10/29/19 B-17 8,127'-8,142' 7,275'-7,290' 2-7/8" 15 03/14/19 B-19 8,245'-8,255' 7,390'-7,400' 2-7/8" 10 03/14/19 B-20 8,289'-8,299' 7,433'-7,443' 2-7/8" 10 03/14/19 B-20 8,396'-8,406' 7,538'-7,547' 2-7/8" 10 03/14/19 B-21 8,451-8,456' 7,592'-7,597' 2-7/8" 5 02/11/19 B-21 LWR 8,496'-8,506' 7,636'-7,646' 2-7/8" 10 02/22/19 B-22 8,560'-8,575' 7,699'-7,714' 2-7/8" 15 02/22/19 LB-23 8,610'-8,620' 7,748'-7,758' 3-3/8" 6 08/08/14 LB-25 8,708'-8,728' 7,845'-7,864' 3-3/8" 6 08/08/14 LB-26 8,770'-8,780' 7,906'-7,916' 3-3/8" 6 08/08/14 LB-27 8,820'-8,830' 7,955'-7,965' 3-3/8" 6 08/08/14 LB-29 9,045'-9,060' 8,178'-8,193' 3-3/8" 6 07/25/14 LB-30 9,123'-9,135' 8,255'-8,267' 3-3/8" 6 07/20/14 LB-30 9,155'-9,165' 8,287'-8,297' 3-3/8" 6 07/20/14 LB-31 9,210'-9,221' 8,341'-8,352' 3-3/8" 12 07/16/14 LB-30 LB-30 5 LB-29 LB-27 LB-26 LB-25 LB-23 TOC 9,052' TOC 8,745' B-17 B-19 B-20 B-21 B-21 LWR B-22 M_Bel B-16 SR_LBGT B-20 4 3 Sterling D1X 2 Sterling D1 TOC 7,164' 1B 1A Coil Velocity String 2.375" CT x .188 wall. 1.999 I.D. (coil has seam) Quality tubing QT-900 V string volume 11.45 bbls Set EOT @ 2950' RKB Run/pulling tool 3" GS spear. (CIBP 3012') Coil Velocity Stringyg 2.375" CT x .188 wall. 1.999 I.D. (coil has seam) Quality tubingQT-900yg V string volume 11.45 bblsg Set EOT @ 2950' RKB@ Run/pulling tool 3" GS spear. CT velocity string (capstring will be run inside CT string) Gas production up the 2 3/8" Coil tubing. Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.05.05 16:10:13 -08'00' Taylor Wellman By Samantha Carlisle at 4:57 pm, May 05, 2020 320-192 gls 5/6/20 CT 10-404 X DSR_5/6/2020 X DLB 05/06/2020 + 4000 psi BOPE test (CT) 5/7/2020dts 4/7/2020 JLC 5/7/2020 SVS performance test within 5 days . Notify inspector to witness BOPE test. ssv blinded New CT hanger NOTE: MV not operable Gas production though CT string. ssv 1 Carlisle, Samantha J (CED) From:Ted Kramer <tkramer@hilcorp.com> Sent:Wednesday, May 6, 2020 10:53 AM To:Schwartz, Guy L (CED) Subject:FW: [EXTERNAL] BCU -07A Velocity string. (PTD 214-060) Attachments:scan.pdf Guy, Hereiswhatthefieldsentmeforasketch. TedKramer(985)Ͳ867Ͳ0665 From:AndyGraves Sent:Wednesday,May6,202010:41AM To:TedKramer<tkramer@hilcorp.com>;ChrisWalgenbach<cwalgenbach@hilcorp.com> Cc:MikeChivers<mchivers@hilcorp.com>;TaylorNasse<tnasse@hilcorp.com> Subject:RE:[EXTERNAL]BCUͲ07AVelocitystring.(PTD214Ͳ060) Ted, Here’saquickonelinedrawing,hopefullythiswilldo.IfnotletmeknowandI’llgointomoredetail. AndyGraves|LeadOperator Alt:MikeChivers BeaverCreekField|KenaiAssetTeam Hilcorp Alaska, LLC agraves@hilcorp.com O:907Ͳ283Ͳ1317 C:907Ͳ394Ͳ3076 From:TedKramer Sent:Wednesday,May6,20209:35AM To:ChrisWalgenbach<cwalgenbach@hilcorp.com> Cc:MikeChivers<mchivers@hilcorp.com>;AndyGraves<agraves@hilcorp.com>;TaylorNasse<tnasse@hilcorp.com> Subject:FW:[EXTERNAL]BCUͲ07AVelocitystring.(PTD214Ͳ060) Chris, SeeGuysnotebelow. Canyoumakemeasticksketchofhowwewouldhookupthesurfaceforthe2Ͳ3/8”coilvelocitystring.Ibelievewhat hewantstoseeishowtheSSVwillbeused.HeisholdinguptheSundryforthissketch. Ihaveattachedthewellheaddrawingforthecoilinstallation. 2 TedKramer SeniorOperationsEngineer HilcorpAlaskaLLC 907Ͳ777Ͳ8420(Office) 985Ͳ867Ͳ0665(cell) From:Schwartz,GuyL(CED)[mailto:guy.schwartz@alaska.gov] Sent:Wednesday,May6,20209:06AM To:TedKramer<tkramer@hilcorp.com> Subject:RE:[EXTERNAL]BCUͲ07AVelocitystring.(PTD214Ͳ060) Yes..justaroughdrawing…willbothSSVbefunctionalandtiedintotheLPpilot? GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From:TedKramer<tkramer@hilcorp.com> Sent:Wednesday,May6,20208:49AM To:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Subject:RE:[EXTERNAL]BCUͲ07AVelocitystring.(PTD214Ͳ060) Guy, Weplantotakeproductionupthe2Ͳ3/8”Coilstringonly. Doyoustillneedthediagram? TedKramer Sr.OperationsEngineer HilcorpͲAlaskaLLC Office–907Ͳ777Ͳ8420 Cell–985Ͳ867Ͳ0665 From:Schwartz,GuyL(CED)[mailto:guy.schwartz@alaska.gov] Sent:Wednesday,May6,20208:34AM To:TedKramer<tkramer@hilcorp.com> Subject:[EXTERNAL]BCUͲ07AVelocitystring.(PTD214Ͳ060) 3 Ted, Needafewdetailsonhowwellwillbeproductionisrouted…areyoutakinggasouttheCTx512/”annulusorboth? .WillbothSSV’sbetiedintotheLPpilot? ProvideasimplepipingdiagramshowinghowthiswillsetupforSVScompliance. GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). Carlisle, Samantha J (CED) From: Davies, Stephen F (CED) Sent: Tuesday, April 28, 2020 10:38 AM To: Carlisle, Samantha J (CED) Subject: FW: [EXTERNAL] Beaver Creek Unit 7A (PTD 21 O ; Sundry Report 320-118) - Question Sa m, Could you please put a copy of the email thread below in the Laserfiche and well history files for Beaver Creek Unit 7A (PTD 214-006)? Thanks and stay safe, Steve D. 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.davieslaalaska.gov. From: Ted Kramer <tkramer@hilcorp.com> Sent: Tuesday, April 28, 2020 9:21 AM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov> Subject: RE: [EXTERNAL] Beaver Creek Unit 7A (PTD 214-006; Sundry Report 320-118) - Question Steve, Family is well. I hope yours is as well. These sands lie above the assigned Sterling pools of 237B. Therefore, I believe that they would be undefined Sterling gas pool. I checked with Ben Siks and he agrees, Undefined Sterling Gas Pool. Sincerely, Ted Kramer Senior Operations Engineer Hilcorp Alaska LLC 907-777-8420(Office) 985-867-0665 (cell) From: Davies, Stephen F (CED) [mailto:steve.davies@alaska.aovl Sent: Tuesday, April 28, 2020 8:58 AM To: Ted Kramer <tkramer@hilcorp.com> Cc: Boyer, David L (CED) <david.bover2@alaska.eov> Subject: [EXTERNAL] Beaver Creek Unit 7A (PTD 214-006; Sundry Report 320-118) - Question Ted, Hope all is well with you and your family. I am entering perforation data into AOGCC's database, and I have a question. Beaver Creek Unit 7A (BCU 7A) was recently perforated between 2977' and 3020' MD. I'm trying to ensure that those perforations are assigned to the proper pool. The well is governed by CO 2378. Do the new perforations in BCU 7A lie within the Sterling Gas Pool as defined by CO 237B, or do they lie above the top of that pool within an undefined Sterling Gas Pool? Thanks and be well, 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.daviesPalaska.2ov. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: 3,012; 7,164; 8,543; Total Depth measured 9,800 feet 8,750; 9,110 feet true vertical 8,929 feet N/A feet Effective Depth measured 3,012 feet 1,869 feet true vertical 2,992 feet 1,869 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)Swell Pkr; N/A 1,869' MD/TVD N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: 10,640psi Burst 6,870psi 35' 2,077' 3,450psi 3,060psi Collapse 1,500psi 1,950psi 7,460psi 4,750psi Casing Structural 20" 20" 13-3/8" Length 3' 2,072' 2,336' 2,336' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 9,767' 1,572 8,896' 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-118 953 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-060 50-133-20284-01-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 390 Beaver Creek Unit (BCU) 07A N/A FEDA028118 2,336' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beaver Creek / Beaver Creek Oil - Beluga Gas PoolN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 9-5/8" 5-1/2" 2,336' 2,336' 2,336' WINJ WAG 0 Water-Bbl MD 35' 2,072' 9,767' 0 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.04.24 15:00:30 -08'00' Taylor Wellman By Samantha Carlisle at 10:11 pm, Apr 24, 2020 gls 4/29/20 X Nitrogen X RBDMS HEW 4/27/2020 DSR-4/27/2020 CO 237B Sterling Undefined Gas Pool SFD 4/28/2020 SFD 4/28/2020 Rig Start Date End Date 3/26/20 3/31/20 03/31/2020 - Tuesday Sign in. Mobe to location. PTW and JSA. Rig up lubricator and PT to 250 psi low and 3,000 psi high. Field bled tubing to 1,017 psi. RIH w/ 3-3/8" x 2' HC, 6 spf, 60 deg phase perf gun and tied into GPT log. Tagged TOC at 7,164' (36' of cement on top of plug). Ran correlation log and send to town. Told to add 4' to correlation log. Added 4' and spotted gun from 3018' to 3020'. Fired gun at 1730 hrs with 1,017 psi on tubing. After 5 min - 1,022 psi, 10 min - 1,032 psi and after 15 min - 1,052 psi. POOH. All shots fired and gun was dry. Rig down lubricator and turn well over to production. TP - 1,139 psi. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU 07A 50-133-20284-01-00 214-060 03/26/2020 - Thursday Sign in. Mobe to location. PTW, JSA and SIMOPS with AKE-Line and SLB N2 crew. Rig up hard lines and lubricator. PT both to 250 psi low and 4,000 psi high. RIH with a new GPT tool found Fluid level at 400'. I started pumping N2 at 1,500'. We started having some small issue with the new GPT tool and wasn't sure about fluid level so I shut down N2. We went down and tagged at 8,200' BHP was 3,373 psi with 325 psi on surface. . Operator called his boss and figured out the problem. Started N2 pumping again while pulling up to 2780'. Shut down N2 and logged down and found fluid level at 3050' with 3,500 psi on tubing but going down. Put N2 back on line for approx. 30 min until they went from 3,200 psi back to 3,500 psi at 1,000 scf rate and shut them down. Waited until well pressure went down to 3,200 psi and then logged back down and found fluid at 3950'. POOH and send GPT correlation log to Anchorage. Rigged down SLB N2 while coming out of hole. RIH with 4.25" CIBP and tie into Perf Log dated 10-29-19. Ran plug correlation log will send to town after I set plug. Spotted and set plug at 7,200' with 2,650 psi on tubing. Lost 150 lbs of line tension when plug set. Picked up 30' and went back down and tagged plug. Looks like good set. POOH. setting tool looks ok. RIH w/ 4" x 20' cement bailer loaded with 16 ppg cement and tagged plug at 7,200'. Pick up 12' and attempted to dump cement. Got out of hole and detonator went off but did not break glass disc at bottom of bailer. Look like low order fire. The glass was cracked but was still holding the cement. Dumped cement in buckets. Made 3 successful bailer runs of cement that put 36' of 16 ppg cement on top of plug. Cement in place at 0300 hrs. Est Top of Cement 7,164'. Rig down lubricator and wait on cement. Will be back to perforate around 1400 hrs. Should have perf correlation log sent in by 1600 hrs. TP - 2,050 psi. 03/27/2020 - Friday logged back down and found fluid at 3950'. started pumping N2 at 1,500' Spotted and set plug at 7,200' with 2,650 psi on tubing. RIH with a new GPT tool found Fluid level at 400'. Displaced with N2 3018' to 3020'. Fired gun at 1730 hrs with 1,017 psi on tubing. *set plug and cement cap (TOC 7164 ft) Est Top of Cement 7,164' Rig Start Date End Date 3/26/20 3/31/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU 07A 50-133-20284-01-00 214-060 Sign in. PTW,JSA and SIMOPS with AKE-Line/SLB N2. Rig up lubricator while SLB goes and pressure up BCU 19 from 3,800 psi to 4,250 psi. PT to 250 psi low and 3,000 psi high. RIH w/ GPT and tie into GPT log. Find FL at 300'. SLB N2 is back and pull GPT tool back in lubricator. Rig up N2, PT lines and lubricator to 250 psi low and 4,000 psi high. Started pushing fluid away at 800 scf at 1,800 psi. Pressure broke over after 750 gals pumped and pressure dropped to 1,300 psi after 900 gal pump and fluid level was at top perf at 3,018'. POOH. Rig down SLB N2. Used 900 gal of N2. RIH w/ 4.24" CIBP and tie into GPT log. Run correlation log. Spotted and set plug at 3,012' (6' above top perf of the D1 sand) with 1,158 psi on tubing. Lost 200 lbs line tension when plug set. Pick up 20' and go back down and tag plug. POOH. Setting tool looked good. Good set. RIH w/ 3-3/8" x 5' HC, 6 spf, 60 deg phase perf gun and tied into GPT log. Run correlation log and send to town. Town said to add 1' to correlation. Added 1' to log. Blew well down to 1,025 psi. Spotted and fired gun from 2,974' to 2,979' with 1,025 psi on tubing. Pressure went to 1063 in first 30 seconds. After 5 min - 1,132 psi, 10 min - 1,134 psi and 15 min - 1,135 psi. POOH. All shots fired and gun was dry. Rig down lubricator and turn well over to field. 3/31/20 Spotted and set plug at 3,012' (6' above top perf of the D1 sand) Spotted and fired gun from 2,974' to 2,979' with 1,025 psi on tubing. P Find FL at 300'. S State/Prov:Alaska Country:USA 122.7' Downhole Revision Date:Schematic Revision Date: 0.0º @ 2,336'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: 4/16/2020 Well Name & Number:Beaver Creek Unit #7A A - 028118 County or Parish:Kenai Peninsula Borough Lease: 39.9º @ 3,350' Date Completed:6/23/2014 Ground Level (above MSL):RKB (above GL): 3.5º to 10.0º 18.5' Revised By:Donna Ambuz BCU - 7A Pad 7 1,800 FNL, 2,050' FEL, Sec. 4, T6N, R10W, S.M. TD: 9,800' MD 8,929' TVD Conductor 30" LP-B 310# weight Top Bottom MD 0' 35' TVD 0' 35' 36" hole cmt w/ 500 sks of Class-G Surface Casing 20" K-55 133.33# weight Top Bottom MD 0' 2,072' TVD 0' 2,072' 26" hole cmt w/ 3,200 sks of Class-G Intermediate Casing 13-3/8" BTC Top Bottom MD 0' 2,214' K-55, 68# MD 2,214' 2,336' N-80, 72# 17-1/2" hole cmt w/ 2,750 sks of Class-G, bumped plug Intermediate Casing 9-5/8" BTC Top Bottom MD 0' 2,336' N-80, 47.0# 12-1/4" hole cmt w/ 3,185 sks of Class-G Jewelry 1. Swell Packer (21' Long) 1A. CIBP 4.24" 3/31/20 2. CIBP 4.25" (w/36' of cement) 3/27/20 3. Straddle Assembly 15' Long (1/25/20) 4. CIBP (11/5/19) 5. CIBP 5-1/2" 6. CIBP 5-1/2" CIBP (Tested to 2,260 psi N2) Depth 1,869' 3,012' 7,200' 8,394'- 8,409' 8,543' 8,750' 9,110' Permit #:214-060 API #:50-133-20284-01 Prop. Des:FED A-028118 KB elevation:141.2' (18.5' AGL) Lat:N60°38' 32.402" Long:W151°2' 16.440" Spud:6/02/2014 01:00 hrs TD:6/19/2014 12:30 hrs Rig Released:6/24/2014 6:00 hrs PBTD: 3,012' MD 2,992' TVD SCHEMATIC 13-3/8" casing cmt top @ 2,130' (CBL 6/08/76) 1 Production Casing 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom MD 0' 9,767' TVD 0' 8,896' 7-7/8" hole Cmt w/ 791 sks ( 245 bbls) of 11.5 ppg, Lite Crete, 413 sks ( 100 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK 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 (35 bbl) - 11.5 ppg Cement (245 bbl) - 15.3 ppg Cement (100 bbl) - 8.4 ppg Lease Water (226 bbl) Max Dogleg: 11.84°/100' @ 2,353' Max Inclination: 39.9°@ 3,350' RA Mkr Jt 5,727' RA Mkr Jt 2,998' RA Mkr Jt 8,536' RA Mkr Jt 8,678' RA Mkr Jt 8,999' RA Mkr Jt 9,188' TOC (USIT 7/3/14) - 1,850' Openhole Casing 33' off bottom Casing Shoe @ 9,767' LB-31 Perforations: Zone MD TVD Size SPF Date Sterling D1X 2,974'-2,979' 2,957'-2,962' 3-3/8" 6 03/31/20 Sterling D1 3,018'-3,020' 2,997'-2,999' 3-3/8" 6 03/27/20 M_Bel 7,242'-7,252' 6,458'-6,466' 2-7/8" 10 10/29/19 B-16 8,015'-8,026' 7,166'-7,177' 2-7/8" 11 02/02/20 B-16 8,016'-8,026' 7,167'-7,177' 2-7/8" 10 10/29/19 SR_LBGT 8,074'-8,081' 7,224'-7,230' 2-7/8" 6 02/02/20 SR_LBGT 8,075'-8,081' 7,225'-7,230' 2-7/8" 6 10/29/19 B-17 8,127'-8,142' 7,275'-7,290' 2-7/8" 15 03/14/19 B-19 8,245'-8,255' 7,390'-7,400' 2-7/8" 10 03/14/19 B-20 8,289'-8,299' 7,433'-7,443' 2-7/8" 10 03/14/19 B-20 8,396'-8,406' 7,538'-7,547' 2-7/8" 10 03/14/19 B-21 8,451-8,456' 7,592'-7,597' 2-7/8" 5 02/11/19 B-21 LWR 8,496'-8,506' 7,636'-7,646' 2-7/8" 10 02/22/19 B-22 8,560'-8,575' 7,699'-7,714' 2-7/8" 15 02/22/19 LB-23 8,610'-8,620' 7,748'-7,758' 3-3/8" 6 08/08/14 LB-25 8,708'-8,728' 7,845'-7,864' 3-3/8" 6 08/08/14 LB-26 8,770'-8,780' 7,906'-7,916' 3-3/8" 6 08/08/14 LB-27 8,820'-8,830' 7,955'-7,965' 3-3/8" 6 08/08/14 LB-29 9,045'-9,060' 8,178'-8,193' 3-3/8" 6 07/25/14 LB-30 9,123'-9,135' 8,255'-8,267' 3-3/8" 6 07/20/14 LB-30 9,155'-9,165' 8,287'-8,297' 3-3/8" 6 07/20/14 LB-31 9,210'-9,221' 8,341'-8,352' 3-3/8" 12 07/16/14 LB-30 LB-30 5 LB-29 LB-27 LB-26 LB-25 LB-23 TOC 9,052' TOC 8,745' B-17 B-19 B-20 B-21 B-21 LWR B-22 M_Bel B-16 SR_LBGT B-20 4 3 Sterling D1X 2 Sterling D1 TOC 7,164' 1A CIBP at 3012 ft Sterling D1 Sterling D1XXSterling D1X CIBP and cement cap Sterling D1X 2,974'-2,979' 2,957'-2,962' 3--2g ,Sterling D1X 2 974' 2 979' 2 957' 2 962' 3 3/8" 6603/31/206 03/31/20 63/8" 6 Sterling D1 3,018'-3,020' 2,997'-2,999' 3-3g ,Sterling D1 3,018 3,020 2,997 2,999 3 3/8" 66 03/27/206 03/27/20 63/8 6 St li D1X 2 974' 2 979' 2 957' 2 962' 32 3/8" 6603/31/20 6 g,, ,,g , THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Taylor Wellman Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 wv✓rv. cog cc. cl as ka.gov Re: Beaver Creek Field, Beaver Creek Oil and Sterling Gas Pools, BCU 07A Permit to Drill Number: 214-060 Sundry Number: 320-118 Dear Mr. Wellman: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, OC �— J sie�owski Commissioner DATED this I + day of March, 2020. IBDMS«' MAR 312020 RECEIVE® STATE OF ALASKA MAR 13 2 ALASKA OIL AND GAS CONSERVATION COMMISSION 3/ Q2Q 20 APPLICATION FOR SUNDRY APPROVALS /� /��. /� 20 CCC 95 280 AM .l . 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Q r Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Nitrogen ❑� 2. Operator Name: 4. Current Well Class 1 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Stratigraphic ❑ Service ❑ 214-060 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20284-01-00 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 Q Beaver Creek Unit (BCU) 07A 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028118 Beaver Creek /Beaver Creek Oil -Sterling Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,800' 8,929' 8,543' 7,682' —1,012 psi 8,543' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 35' 30" 35' 35' Surface 2,072' 20" 2,072' 2,077' 3,060 psi 1,500 psi Intermediate 2,336' 13-3/8" 2,336' 2,336' 3,450 psi 1,950 psi Production 2,336' 9-5/8" 2,336' 2,336' 6,870 psi 4,750 psi Liner 9,767' 5-1/2" 9,767' 18,896' 10,640 psi 7,460 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic N/A N/A I N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Swell Packer; N/A 1,869' MD/TVD 12. Attachments: Proposal Summary Wellbore schematic r 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory P ry ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: March 25th, 2020 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Taylor Wellman 777-8449 Contact Name: Christina Twogood Authorized Title: Operations Ma Contact Email: CtwO ood hilCof .Com Contact Phone: 777-8443 Authorized Signature: Date: °3 13 zo+r.o COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �3ap - Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: -ABDMS tom/ MAR 312929 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: / b _ � 0 4. APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 'tl R A A I/}c/ j Submit Form and Form -403 Revised 4/2017 Approved applicati SGB o3/OO a s the tldte of approval. Attachments in Duplicate H uae"�u Aeaxe, M Well Prognosis Well: BCU -07A Date:03/09/2020 Well Name: BCU -07A API Number: 50-133-20284-01-00 Current Status: Shut -In Gas Well Leg: N/A Estimated Start Date: 03/25/2020 Rig: E -Line Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-060 First Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) AFE Number: Current BHP: - 1,293 psi @ 7,553' TVD (Based on 2007 BCU 16 RFT data) Max. Expected BHP (Beluga): - 1,311 psi @ 7,646' TVD (Based on actual reservoir pressure) Max. Expected BHP (Sterling): - 1,313 psi @ 3,004' TVD (Based on norm. gradient (0.437 psi/ft)) Max. Potential Surface Pressure: - 1,012 psi (Based on expected BHP (Sterling) and gas gradient to surface (0.10 psi/ft)) Brief Well Summary BCU -07A was drilled and completed in 2014 targeting the lower Beluga formation. The first several sands proved to be non-productive and were plugged back to the LB -23. The well came online in the LB -23 making just over 2 MMCFD with little to no water. In February and March 2019 the Lower Beluga and a few Middle Beluga sands were perforated. The Middle Beluga sands caused the rate to drop off. One of the sands appears to be wet, causing the 5-1/2" wellbore to load up. In October 2019 the SR_LBGT, B-16 and M_Bel sands were perforated. In February 2020 the SR_LBGT and B-16 sands were perforated. The purpose of this work/sundry is to perforate the D1 and D1X sands in the Sterling zone,. Notes Regarding Wellbore Condition • Last tag on 2/14/2020 at 8,263' KB SLM with GR on Slickline • Failed attempt to retrieve straddle assembly. 4.5" LIB showed embedded sand at 8,162' KB SLM. Safety Concerns Discuss Nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. Considertank placement based on wind direction and current weatherforecast (venting Nitrogen during this job). 0 Ensure all crews are aware of stop job authority. B tlilcoru Alaska. LU E -line Procedure Well Prognosis Well: BCU -07A Date:03/09/2020 1. MIRU E -Line Unit and pressure control equipment. PT lubricator to 250 psi Low/ 3,000 psi High. 2. RIH with GPT tool and find fluid level. If fluid is over the depth of the new perfs, discuss using Nitrogen with the Operations Engineer. 3. If needed, RU Nitrogen Truck, pressure upon well and push water back into formation. Use GPT tool to confirm water level is below interval to perf. 4. RIH with 5-1/2" CIBP and set at +7,200 Dump bail 35' cement on top. POOH. 5. RU perf guns. 6. RIH and perforate the below intervals: Zone Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Sterling D1X ±2,974' ±2,979' ±2,957' ±2,962' S Sterling D1 +3,018' +3,025' +2,997' +3,004' 7 a. Pressure up well to 1,000 psi before perforating. b. Proposed perfs also shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact pert intervals. d. All perforations in table above are located in the Sterling Gas Pool based on Conservation Order 237A. e. Use Gamma/CCL to correlate. f. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. g. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. h. Record 5, 10 and 15 minute pressures after firing guns. 7. POOH. 8. RDMO E -Line. 9. Turn well over to production. E -Line Procedure (Contingency) 1. If any zone produces sand and/or water and needs to be isolated. 2. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 3,000 psi High. 3. RIH and set 5-1/2" Casing Patch or set 5-1/2" CIBP above the zone and dump 35' of cement on top of the plug. Attachments 1. Current Well Schematic 2. Proposed Well Schematic 3. Standard Well Procedure—Nitrogen Operations Hilcorp Alaska, LLC #: 214-060 50-133-20284-01 les: FEDA-028118 ration: 141 2' (18.5'AGL) N60° 38' 32.402" W151° 2' 16.440" 6/02/2014 01:00 hrs 6/19/2014 12:30 hrs eased: 6/24/2014 6:00 hrs Tree can - 9-112" OIN 8.0" Seal Diameter 5.118" Modified ID Bon TOC(USIT7/3114)-1,850' 13-318" casing cmt top @ 2,130' (CBL 6108/76) 1 CasinglCementmg Detail - 9.4 ppg Mud - 10.6 ppg Mud Push (35 bbl) - 11.5 ppg Cement (245 bbp - 15.3 ppg Cement (100 bbl) 8.4 ppg Lease Water (226 bbl) BCU - 7A Pad 7 1,800 FNL, 2,050' FEL, Sec. 4, T6N, R10W, S.M. 14 1l M_Bel B-16 SR_LBGT B-17 B-19 B-20 8.20 B-21 B-21 LWR Jewelry Death 1. Swell Packer (21' Long) 1,869 2. Straddle Assembly 75' Long (1125/20) 8,394'-8,409' 3. CIBP (1115119) 8 543' 4. CIBP 5-1/2" 8,750' 5. CIBP 5.12" CIBP (Tested to 2,260 psi N2) 9,110' RA Mkr it 2,998' RA Mkr it 5,727' LB -30 LB -30 RA Mkr it 9,188' LB -31 SCHEMATIC Conductor 30" LP -B 310#weight 192 Bottom MD 0' 35' TVD 0' 35' 36" hole cmt w/ 500 sks of Class -G Surface Casing 20" K-55 133.33# weight T02 Bottom MD 0' 2,072' TVD 0' 2,072' 26" hole cmt w/ 3,200 sks of Class -G Intermetliate Casino 13-3/8" BTC Top Bottom MD 0' 2,214' KSS, 68# MD 2,214' 2,336' N-80, 72# 17-1/2" hole amt w/ 2,750 sks of Class -G, bumped plug Intermediate Casing 9-5/8" BTC TOP Bottom MD 0' 2,336' N-80, 47.0# 12.1/4" hole cmt w/ 3,185 sks of Class -G Production Casino 5-112" P-110 17 ppf DWC/FHT Top Bottom MD 0' 9,787' T1D 0' 8,896- 7-71B" hole Cmt w/ 791 sks (M able) of 11.5 ppg, Lite Crete, 413 sks (100 bbls) of 15.3 ppg. Class G cmt wl FJISVBLOK Perforations, Beaver Creek Unit#7A RA Mkr it 8,536' Zone MD 3 B-22 M_Bel 7,242'-7,252' LB -23 10/29/19 SAS 8,015'-8,026' 7,166-7,177' 2-7/8" 11 'RA Mkr it 8,678' B-16 OC 7.167'-7,177' 2-71W 10 LB -254.5' SR L8GT 8,074'-8,081' 7,224'-7,230' 2-7/8" 6 19TY0 SR LBGT 8,079-8,081' 7,226-7,230' 2-7/8" 6 4 LB -26 8,127-8,142' 7,276-7,290' 2-7/e" 15 LB -27 B-19 8,245'-8,255' 7,390'-7,400' 2-716" 10 03/14/19 RA Mkr it 8,999' 8,289'-8,299 C 03/14/19 LB -2952' 8,396'-8,406' 7,538'T54T 2-718" 10 LB -30 LB -30 RA Mkr it 9,188' LB -31 SCHEMATIC Conductor 30" LP -B 310#weight 192 Bottom MD 0' 35' TVD 0' 35' 36" hole cmt w/ 500 sks of Class -G Surface Casing 20" K-55 133.33# weight T02 Bottom MD 0' 2,072' TVD 0' 2,072' 26" hole cmt w/ 3,200 sks of Class -G Intermetliate Casino 13-3/8" BTC Top Bottom MD 0' 2,214' KSS, 68# MD 2,214' 2,336' N-80, 72# 17-1/2" hole amt w/ 2,750 sks of Class -G, bumped plug Intermediate Casing 9-5/8" BTC TOP Bottom MD 0' 2,336' N-80, 47.0# 12.1/4" hole cmt w/ 3,185 sks of Class -G Production Casino 5-112" P-110 17 ppf DWC/FHT Top Bottom MD 0' 9,787' T1D 0' 8,896- 7-71B" hole Cmt w/ 791 sks (M able) of 11.5 ppg, Lite Crete, 413 sks (100 bbls) of 15.3 ppg. Class G cmt wl FJISVBLOK Perforations, Beaver Creek Unit#7A Zone MD TVD Size SPF Dat M_Bel 7,242'-7,252' 6,458-6,466 2-7/8" 10 10/29/19 SAS 8,015'-8,026' 7,166-7,177' 2-7/8" 11 02/02/20 B-16 8,016'-8,026' 7.167'-7,177' 2-71W 10 10/29/19 SR L8GT 8,074'-8,081' 7,224'-7,230' 2-7/8" 6 0210220 SR LBGT 8,079-8,081' 7,226-7,230' 2-7/8" 6 1029/19 B-17 8,127-8,142' 7,276-7,290' 2-7/e" 15 03/14/19 B-19 8,245'-8,255' 7,390'-7,400' 2-716" 10 03/14/19 B-20 8,289'-8,299 7,433'-7,443' 2-718" 10 03/14/19 B-20 8,396'-8,406' 7,538'T54T 2-718" 10 03/14/191 solaced B-21 8,451-8,456' 7,592'-7,597' 2-7/8" 5 02/11/19 B-21 LWR 8496'-8,506' 7,636'-7,646' 2-7/8" 10 02/22/19 B-22 8,560''-8,575' 7,699-7,714' 2-71W 15 02/22119 LB -23 8,610'-8,620 7,748'-7,758' 331W 6 8/08114 LB -25 8,708'-8,728' 7,845'-7,864' 33/8° 6 8/08/14 LB -26 8,770'-8,780' 7,906'-7,916' 3-318" 6 8/08/14 LB 27 8,820'-8,830' 7,955-7,965' 3-3/8" 6 8N8/14 LB -29 9,046-9,060' 8,179-8,193' 33/8" 6 725/14 L630 9,123'-9,135 8,255'-8,267' 3-3/8" 6 720114 LB -30 9,155-9,165' 8,287'-8,297' 33/8" 6 720114 LB -31 9,210'-9,221' 8,341'-8,352' 3-3/8" 12 7/18114 CasingS� Openhole Casing 33' off bottom Max Dogleg: 71,84°/700' @ 2,353' Max Inclination: 39.9° @ 3,360' Well Name &Number: Beaver Creek Unit#7A Lease: TD: PBTD: Kenai Peninsula Borough 9,800'MD 8,543' MD Counhy: USA 8,929' TVD 7,682' TVD Maximum Deviation: Max Dogleg: 71,84°/700' @ 2,353' Max Inclination: 39.9° @ 3,360' Well Name &Number: Beaver Creek Unit#7A Lease: A-028118 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Counhy: USA Angle @KOP and Depth: 0.0° @21 Angle/Perfs: 3.5° to 7011° Maximum Deviation: 39.9° @ 3,350' Date Completed: 6/23/2074 Ground Level (above MSL): 722.7' IRKS (above GL): 78.5' Revised By:. Christina Twogood Downhole Revision Date: I I Schematic Revision Dale: 3/1712020 Hil"n) Alaska. LLC #: 214-060 50-133-20264-01 has; FEDA-028116 +etlon: 141.2' (16.5'AGL) N60° 38' 32.402" W151° 2' 16,440" 6/02/2014 01 00 hrs 6/19/2014 12'.30 hrs eased: 6/24/2014 6:00 hrs Tree exn - 9-112" Oils 5.0" Seat Diameter 5-111" Modified iD Bore TOC (USIT 7/3/14) -1,860' 13-318" casing chat top @ 2,130' (CBL 6108/76) Cashm/Cementing Detail - 9.4 ppg Mud - 10.5 ppg Mud Push (35 bbl) 11.5 ppg Cement (245 bbl) - 15.3 ppg Cement (100 bbl) - 8.4 ppg Lease Water (226 bbl) BCU - 7A Pad 7 1,800 FNL, 2,050' FEL, Sec. 4, T6N, R101N, S.M. Sterling DIX Sterling 01 , M_Bel B-16 SR_LBGT B-17 B-19 B-20 8-20 B-21 B-21 LWR B-22 LB -23 LB -25 LB -26 LB -27 LB -29 Jewelry Deoth LB -30 1. Swell Packer(21'Long) 1,869' LB -30 2. CIBP 5-112" +7,200' .2,997'--3,004' 3. Straddle Assembly 15' Long (1/25/20) 8,394'- 8,409' 7.718" hole Cart w/ 791 sks ( 245 bels) of 11.5 ppg, 4. CIBP (1115/19) 8,543' 2-718" 10 5. CIBP 5-1/2" 8,750' LB -31 6. CIBP 5-1/2" CIBP(Tested to 2,260 psi N2) 9,110' 2-7/8" 11 RA Mkr Jt 2,998' RA Mkr Jt 5,727' 2 PROPOSED SCHEMATIC Conductor 30" LP -B 310#weight Two Bottom MD 0' 35' TVD 0' 35' 36" hole cmt w/ 500 its of Class -G Surface Casing 20" K-55 133.3Ut right TT02 Bottom MD 0' 2,072' TVD 0' 2,072' 26" hole cmt w/ 3,200 sks of Class -G Intermediate Casing 13-3/8" BTC TOR Bottom MD 0' 2,214' K-55, 68# MD 2,214' 2,336' N-80, 72# 17-112" hole cmt .12,760 sks of Class -G, bumped plug Intermediate Casing 9-5/8" BTC Top Bottom MD 0' 2,336' N-80, 47.0# 12-1/4" hole cmt w/ 3,185 sks of Class -G Max Dogleg: 11.84°I100' @ 2,953' Max Inclination: 39.9° @ 3,350' Well Name &Number: production Cosine Date 5-112" P-110 19 pin DWCIC-HT TBD Top Bottom , 3 MD 0' 9,767' .2,997'--3,004' WD 0' 8,896' - - 7.718" hole Cart w/ 791 sks ( 245 bels) of 11.5 ppg, 7,242'-7,252' Lite Crate, 413 sks (100 bole) of 15.3 ppg, Class G 2-718" 10 cmtw/EASYBLOK RA Mkr Jt 8,536' B-16 6,015'-8,026' 7,166-7,177' Max Dogleg: 11.84°I100' @ 2,953' Max Inclination: 39.9° @ 3,350' Well Name &Number: Zone MO TVD Size SPF Date Sterling DIX «2,974'-42,979' •2.957'-±2.962' TBD RA Mkr Jt 8,678' Sterling Df .3018'-•3,025' .2,997'--3,004' TBD TOC M_Bel 7,242'-7,252' 6,458'-6,466' 2-718" 10 10/29/19 8,745' B-16 6,015'-8,026' 7,166-7,177' 2-7/8" 11 02/02/20 I Schematic Revision Date:1 B-16 6,016'-8,026' 7,167-7,177' 2-7/8" 10 10/29/19 - 5 SR_LBGT 8,074'-8,081' 7,224'-7,230' 2-7/8" 6 02/02/20 SR LBGT 8,075'-8,081' 7,225'-7,230' 2-7/8" 6 10/29/19 B-17 8,127-8,142' 7,275-7,290 2-7/8" 15 03/14/19 B-19 8,245'-8,255' 7,390'-7,400' 2-7/8" 10 03/14F19 B-20 8,289'-8,299 7,433'-7,443' 2-718" 10 03/14/19 B-20 8,396'-8,406'7,539-7,547- 2-71W 10 03/14/19 RA Mkr Jt8,999' TOC B-21 8,451-8,458' 7,592-7,59T 2-7/8" 5 02/11/19 9,052' 0 21 LWR 8,496'-8,506'7,636'-7p646- 2-78" 10 02/22/19 B-22 8,560'$,575' 7,699'-7,714' 2-7/8" 15 02/22/19 ' 113-23 8,610'-8,620' 7,748'-7,758' 3-318" 6 08/08/14 ..LB -25 8,708'-8,728' 7,845'-7,864' 3-3/8" 6 08/08/14 LB -26 8,770'-8,780' 7,906'-7,916'3-349' 6 08/08/14 LB -27 8,820'-8,830' 7,955'-7,965' 33/8" 6 08/08/14 RA Mkr Jt 9,188' LB -29 9,045'-9,080' 8,178-6,193' 3-3/8" 6 07/25/14 LB -30 9,123'-9,135' 8,255$,267' 8-3/8" 6 07/20/14 LB -30 9,155'-9,185' 8,287'-8,297' 3-3/8" 6 07/20/14 11331 9 210'-9 221' R'3411R 35T :LA10." 19 n711RHe Max Dogleg: 11.84°I100' @ 2,953' Max Inclination: 39.9° @ 3,350' Well Name &Number: Casing Shoe@9,]67' Lease: Openhole A-028118 Casing 33' off bottom TD: PBTD: Alaska 9,800' MD 8,543' MD 0.0° 2,336' Angle/PWs: 3.5° to 10.0° 8,929 -TVD 7,682'IWO Date Completed: Max Dogleg: 11.84°I100' @ 2,953' Max Inclination: 39.9° @ 3,350' Well Name &Number: Beaver Creek Unit#7A Lease: A-028118 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 0.0° 2,336' Angle/PWs: 3.5° to 10.0° Maximum Deviation: 39.9° A 3,350' Date Completed: 6/23/2014 Ground Level (above MSL):1 122.7' RKB (above GQ:j 18.5' Revised By: Christina Twogood Downhole Revision Dale: I Schematic Revision Date:1 3/11/2020 STANDARD WELL PROCEDURE IweorpAlaeea.LIX NITROGEN OPERATIONS 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/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 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. 12/08/2015 FINAL v1 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAR r Z r= i-Ytl- 1. Operations Abandon Plug Perforations Fracture Stimulate Pull TubingQ�py) shutdown Ll Performed: Suspend El Perforate ❑✓ Other Stimulate ❑ E]• ^QAlter Casing n ro ed Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Nitrogen Displace ❑✓ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 15. Permit to Drill Number: Name: Development P ❑ Stratigraphic❑ Ex Exploratory ry ❑ Service ❑ 214-060 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20284-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028118 Beaver Creek Unit (BCU) 07A 9. Logs (List logs and submit electronic and printed data per 20AAG25.071): 10. Field/Pool(s): N/A Beaver Creek / Beaver Creek Oil - Beluga Gas Pool 11. Present Well Condition Summary: 8,543; Total Depth measured 9,800 feet Plugs measured 8,750; 9,110 feet true vertical 8,929 feel Junk measured N/A feet Effective Depth measured 8,543 feet Packer measured 1,869 feet true vertical 7,682 feet true vertical 1,869 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 35' 30" 35' 35' Surface 2,072' 20" 2,072' 2,077' 3,060 psi 1,500 psi Intermediate 2,336' 13-3/8" 2,336' 2,336' 3,450 psi 1,950 psi Production 2,336' 9-5/8" 2,336' 2,336' 6,870 psi 4,750 psi Liner 9,767' 5-1/2" 9,767' 8,896' 10,640 psi 7,460 psi 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) Swell Pkr; N/A 1,869' MD/TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 78 0 0 101 Subsequent to operation: 0 0 0 0 37 14. Attachments (required per 20 AAC 25.070, 25.071, 8 25.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ✓ WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-475 me: Taylor Wellman 777-8449 Contact Name: Ted Kramer e:ns ager/Contact L Email: lkmmer(rDhilcoro.com nature: Date: 0i/ /r /v2i4 Contact Phone: 777-8420 Form 10-404 Revised 4/2o;;p-7, / -70 '-0 BDMS ( "' MAR 13 2020 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU 07A 50-133-20284-01-00 1 214-060 10/29/19 1 2/14/20 Daily Operations: 10/29/2019 -Tuesday Sign in. Mobe to location. PTW and JSA. Spot and rig up equipment. Arm gun. PT lubricator to 250 psi low and 3,000 psi high. Well flowing 60K at 85 psi. RIH w/ 2-7/8" x 6' (knocked off 1' by per TK) Razor HC, 6 spf, 60 deg phase. Tie into SLB RST Log and run correlation log. Send to town and was told to shift log up 4' and perf from 8,075' to 8,081'. Spotted and fired gun w/well flowing 60k at 85 psi. After 15 min there was no significant pressure or rate increase. POOH. All shots fired and gun was wet. Gun #1. RIH w/ 2-7/8" x 10' (knocked off V by per TK) Razor HC, 6 spf, 60 deg phase. Tie into perf log, run correlation log and send to town. Got ok to perf from 8,016'to 8,026'..Spotted and fired gun with well flowing 96K at 88.8 psi. After 5 min - 102K at 89 psi, 10 min - 103K at 88.7 psi and 15 min at 86.4K at 88.6 psi. POOH. All shots fired and gun was wet. Gun #2. RIH w/ 2-7/8" x 10' Razor HC, 6 spf, 60 deg phase and tie into RST Log. Run correlation log and send to town. Told to shift log up 6'. Shifted log up 6' and spotted shot from 7,242' to 7,252'. Fired gun w/102K at 87 psi. After 5 min - 97K at 87 psi and 15 min - 102.5K at 88.9 psi. POOH. All shots fired and gun was wet. Gun #3. RIH w/ 2-7/8" x 17' Razor HC, 6 spf, 60 deg phase and tie into RST Log. Run correlation log and the well came on and decision was made to POOH and soap well tonight and see what it does. Its making 200K at 88 psi at 1800 hrs. POOH with pert gun. GUN #4 WAS NOT SHOT. Rig down lubricator and bop off well. Put soap launcher on. Leave equipment on location. 10/30/2019- Wednesday Sign in. PTW and JSA. Rig up lubricator. PT to 250 psi low and 3,000 psi high. Flowing 100K at 56 psi to a blow down tank. RIH with GPT tool with well flow approx 1,000K at 56 psi making about 4 to 5 bbls an hour and looked like soapy gas to about 4,400'. Pretty much fluid on down. Tie into perf log and well quit flowing when we got to about 6,600'. RIH logging and tagged at 8,609'. Ran a log to 6,630' and correlated to perf log. Send to town. Called to town and discussed. Told to shut well in and run log from 8,600' to 2,170'. Pretty much fluid to 3,410' and then turned to gas. POOH and send log to town. Also sent to town in 3 sections the down log. Rig down AKE-Line equipment and release them. Turn well over to field. 11/02/2019 -Saturday ON LOCATION - TGSM - JSA - PERMIT. RIG UP W/L - PT LUB 3000 PSI - GOOD. RIH W/ 4.75" GAUGE RING TO 2,332'KB WT FALL TO 2,448'KB WT FALL TO 4,118'KB WT FALL TO 8,650'KB TAG - POOH - MAKE PASSES THROUGH TIGHT SPOTS -. RIH W/ DRIFT FOR PATCH (4.75" GR, 4.475" X 7' DUMMY, 3.375" X 6' DUMMY, 4.475" X 6.5' DUMMY. 4.6" CENTRALIZING SWEDGE) TO 2345'KB BOBBLE HARD - MAKE PASSES AT DIFFERENT SPEEDS - 120 FPM - LOSE 200 LBS DOWN - PULL AN EXTRA 400LBS COMING BACK UP - CONT IN HOLE TO 2,918'KB - SET DOWN - PICK UP - RIH AT 200 FPM - PASS THROUGH WITH. LIGHT BOBBLE - CONTINUE IN HOLE TO 8,550'KB DO NOT TAG - POOH - MAKE SEVERAL PASSES THROUGH TIGHT SPOTS - DO NOT SET DOWN - POOH. OOH W/ DUMMY GUNS - RIG DOWN W/L CLOSE OUT PERMIT - DEPART FIELD. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU 07A 50-133-20284-01-00 214-060 10/29/19 2/14/20 Daily Operations: 11/05/2019 -Tuesday Sign in. PTW, JSA and SIMOPS with AKE-Line and SLB N2. Mobe to location. Rig up hard lines and lubricator. PT hard lines to 4,500 psi and lubricator to 4,000 psi. TP - 870 psi. We had 2,500 gals of N2. RIH w/GPT tool and tie into RST log. Find fluid level at 4,200'. Start pushing fluid into perfs at 1,000 scf at 964 psi. Kept pushing fluid away and pressure climbing also. SLB N2 got up to 3,650 psi at 800 scf when we ran out of N2. AKE-Line was tracking fluid level with GPT tool and fluid level was at 7,516' at 3,650 psi.. Pulled out of hole. Rigged down SLB N2 and sent correlation log to town. RIH w/4,24" OD CIBP and tie into GPT log. Town ok plug and patch log. Ran in hole and run correlation plug log. After looking over log decision was made to set plug at 8,544' instead of 8,550' to give a little more room. Spotted and set plug at 8,544' with 2,600 psi on tubing. Pick up 30' and go back down and tag plug. POOH. Good set. RIH w/ 4.70" x 20' casing patch and tie into GPT log. Had to work thru tight spot at 2,300' and then had tight spot at 2,900'. Tried to get thru tight spot numerous times at different speeds but could not get thru it. It was pulling about 400 to 900 Ib over tool weight. Called town and discussed. Decided to POOH and come back in the morning with a 15' patch and see if we can get down. Rig down lubricator and secure the well. Will be back in the morning about 10 am with a 15' patch. They have to take a 10' section off and put a 5' section on at their shop in the morning. TP - 2,200 psi. 11/06/2019- Wednesday Sign in. Mobe to location. PTW and JSA. PT lubricator to 250 psi low and 3,000 psi high. TP - 2,100 psi RIH w/ 2-3/8" GPT tool and tie into Plug log. Found Fluid Level at 8,121' and tag plug at 8,544'. Run correlation log and send to town. Did not see any tight spots going in or out of hole. POOH. Put casing patch on line and change out lubricator. PT to 250 psi low and 3,000 psi high. RIH with 2-3/4" CCL/Gama and 4.70"x15' Tubing Patch to 2,790'. Tools sat down at 2,790' (New sit down spot) and we finally worked it thru using different speeds. Did not see anything at 2,300'. Sat down again at 2,938' (about like yesterday). Tried numerous speeds but couldn't get thru. Had approx. 600 lb overpull and was still picking up at same spot. Pumped 2 bbl of diesel while working tools but did not help. Pulled back up past the 2,790' spot and tried to get thru it again. Could not get thru after about 10 tries. Called town and discussed. Decided to check on straddle packer and special clearance patch. POOH Rig down lubricator and secure the well. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU 07A 50-133-20284-01-00 1 214-060 10/29/19 1 2/14/20 Daily Operations: 11/08/2019 - Friday Sign in. Mobe to location. PTW and JSA. Rig up lubricator. PT to 250 psi low and 3,000 psi high. TP - 2,090 psi. RIH w/3- 1/8" CCL, 4.50"x20' Dummy Gun and sit down at 2,300'. Tried numerous times at different speeds and couldn't get thru. Hard to understand because we got thru this depth with bigger stuff. POOH. Had some hard sandy black stuff in scallops of the dummy gun. RIH w/3-1/8" CCL, 4.50"x17' Dummy Gun and sit down at 2,300'. Tried a lot of things like the run above but could not get thru. It would sit down same place as above and would pull about 300 Ib over tool weight every time. POOH and had same stuff on dummy gun as above. Call town and discussed. MU 4.78" GR and 2.75 junk basket and tried to go in hole. Kept sitting down on tubing hanger. POOH and had scratch marks on sides of GR that looked like we tried to go into a smaller ID. Sent pics to town. RIH w/3-1/8" CCL, 4.50"x7' dummy gun down and tag at 8,543'. We barely saw any bobbles at 2,300', 2,790' and 2,950'. The places we have been having trouble the last few days. POOH. Town will check with BLM and see if we have to put cement on top of plug at 8,543'. Then we will set CIBP at 8,380'. It will probably be Monday or Tuesday when we do this. Rig down lubricator and secure the well. TP - 2,050 psi. 11/27/2019- Wednesday PTW and JSA. Spot and rig up equipment. PT lubricator to 250 psi low and 3,000 psi high. Had to change o -ring out. TP - 2,000 psi RIH w/the 2 run straddle packer set dummy and set down at 2,300'. Run down hole at 200 fpm and went thru tight spot at 2,300'. RIH to 2,880' and set down again. Tried numerous speeds but could not get thru tight spot. POOH. Take the first 8' 3-1/2" pump out of string and made it a 3 set straddle packer. Really didn't see any bad marks or scratches on the straddle packer dummy. RIH w/3 set straddle packer dummy and set down at 2,880'. Tried different speeds and dummy went thru ok at 250 fpm all the way down to 8,544' and tagged plug. POOH we saw just a bobble at 2,880', 2,443' and 2,300'. POOH. Rig down off well. Turn well back over to field. TP - 2,000 psi. NOTE: I called Todd with Quado and he said it would be about 2 weeks before straddle packer was here. 01/24/2020 - Friday Sign in. Mobe to location. We had an extra long PTW/JSA with a new hand with AKE-Line. Spotted and rigged up lubricator. PT to 250 psi low and 3000 psi high. TP - 2200 psi RIH w/two 1-11/16 wt, 2,125" shooting gama and 4.56" GR/JB. Tools set down at 116'. We worked it and dumped methanol down well. We have just a little bit of spang movement on the junk basket. It would stick some on us. POOH and checked line all the way out just in case it was stopping at a grease tube. Couldn't find a bad spot. RIH with same except we replaced GR and junk basket with 3-1/8"0' wt bar on bottom. Set down at same spot 116'. Work tools and still couldn't go down. Dumped 20 gal diesel to cut a -line grease. POOH Rig down a -line lubricator except for pump in sub and wireline valve. Slickline is going to use crane. Wait on Slickline PTW and JSA. Spot and rig up slickline. PT to 250 psi low and 3000 psi high. RIH w/3.94" Gauge Ring to 250'. Didn't see anything at 116'e -line was stopping at. We didn't sit down but I had them POOH and put bigger gauge ring on. RIH w/4.65" gauge ring down to 8549' wlm and tag plug. POOH. Did not have any problems going in or out of hole. It seems like it was line problem going thru the grease tubes that AKE-Line was having trouble with instead of ice plug. Ed with AKE-Line check the line as they came out of hole but didn't see or feel a bad spot. They will be out here at 7 am with a different wireline truck. Rig down slickline and secure well. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU 07A 50-133-20284-01-00 1 214-060 10/29/19 2/14/20 Daily Operations: 01/25/2020 - Saturday Sign in. PTW and JSA with AKE-Line and Quadco. Change out Eline truck. Rig up lubricator and attempt to PT. O-ring leaked. Change oring. PT to 250 psi low and 3000 psi high. TP - 2100 psi. RIH w/4.5"x5.94' lower packer and 4.5"x4' WLAK and tie into RST log. Tools slowed down at 2300' and 2900' but didn't stop at 80 fpm. Tools air wt 520 Ib. RIH at 80 fpm down to 8535'. Did not tag. Run correlation log and send to town. Town said to substract Ton log. Substract 3' and set bottom packer at 8409'. Lost 200 lbs when packer set. POOH. All looks good. RIH with 4.50" OD Tie back Assy, a -line spangs and stab into bottom packer assy. Beat down 10 times to bury seals and latch. Over pull 500 Ib to make sure tie back is latch. Slack off to neutral wt and shear off tie back assy. Lost 100 Ib when sheared. POOH. Good set. No Problems going in or out of well. Tools air wt. 550 Ib. RIH w/4,5" OD upper packer assy, a -line spangs and stab into tie back assy. Beat down 10 times to bury seals and latch. Over pull 500 Ib Ib to make sure it latched. Slack off to neutral wt and set upper packer. Lost 230 Ib when packer set. POOH. Tools looks good. Tool air wt was 680 lb. The Quadco Straddle packer is from 8393.5' to 8409'. It covers perfs from 8396' to 8406' (B20 sand) Rig down equipment and turn well over to field. S'RAbo 01/30/2020 - Thursday Sign in. Mobe to location. PTW, JSA and SIMOPS with SLB N2 and AKE-Line. Spot equip and rig up hard lines and lubricator. PT to 250 psi low and 4,000 psi high. TP - 85 psi RIH w/GPT and tied into SLB RST log. Went down to 5,200' and checked for fluid level. Was in fluid. Slickline found FL at 6,500'. We went back up and found FL at 3,200'. Figured FL was at 1,800' to 2,000' when we started. Raised SLB rate to 1,500 scf at 2,000 psi. Kept rate at 1,500 scf and pressure kept rising up to 3,900 psi. We would stop and find fluid level while pressure came down. We pumped a total of 2,797 gals of N2 when we ran out with TP - 3,900 psi. Found FL at 6,350'. 1 have N2 tanker (6,000 gals), SLB N2 crew and AKE- Line set to be here in the morning at 0700 hrs. Will find out where FL is in the morning and what pressure we have on tubing. Rig down lubricator and secure well. TP - 3,600 psi. 01/31/2020 - Friday Sign in. Mobe to location PTW, JSA and SIMOPS with AKE-Line and SLB N2. SLB transferred N2 from tanker while AKE- Line rigged up. PT hard lines and Lub to 4,000 psi. TP - 2,833.9 psi. RIH w/GPT tool to about 100'. Going real slow due to N2 and a -line grease. Pull up in lub and dump 10 gal of diesel to cut a -line grease. Run back in hole and was going ok. Tie into RST log and found fluid level at,7350' (1,000' deeper than we left it) and TP - 2,750 psi. Pumped N2 at 1,500 SCF and raised pressure to 3,900 psi. Shut them down after an hour and checked FL. Found it at 7,450'. We gained 100'. Pressured up again pump at same rate and pressure for 1 hour and check. Found FL at 7,550', another 100' but have used 1,400 gal of N2 Called town and decision was made to pressure up to 3,900 psi and wait 1 hour and see how much it pushed away instead of burning up N2. Pressured up to 3,900 psi and waited an hour. FL went down to 7,580' (30' deeper). Called town and decision made to POOH, pressure tubing up to 4,000 psi, shut in and check in am. Pressure tubing up to 4,000 psi and rid down lubricator and secure well. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU 07A 50-133-20284-01-00 214-060 10/29/19 2/14/20 Daily Operations: 02/01/2020 -Saturday Sign in. Mobe to location. PTW, ISA and SIMOPS with AKE-Line and SLB N2. Crane wouldn't start. Rig up heater and put on engine. Rig up hard lines and lubricator. PT 250 psi low and 4,000 psi high. RIH w/GPT and tie into Plug log. Find FL at 7,920'. Pump N2 for 1 hour and find FL at 7966'. Talk to town and decision made to perforate. Used 1,000 gal of N2 pump 1500 scf going up to 4,000 psi. Rid down SLB N2 and POOH with AKE-Line. RIH w/ 2-7/8" x 7" HC, 6 spf, 60 deg phase and tie into GPT log. Run correlation log and send to town. Could not get a good reading off gama ray or CCL. Decision made to POOH and get another shooting gama ray from AKE-Line shop. Wait on gama tool. RIH w/ 2-7/8" x 7' HC, 6 spf, 60 deg phase and tie into GPT log. Run correlation log and send to town. Was told to shift up 1'. Shift up V and spotted gun from 8,074'to 8,081'. Fired gun with 3,101 psi on tubing. After 5 min - 3,098 psi, 10 min - 3,093 psi and 15 min - 3,088 psi. POOH. All shots fired. Gun was wet. RIH w/ 2-7/8" x 11' HC, 6 spf, 60 deg phase and tie into Perf log. Run correlation log and send to town. Get ok to perf from 8,015' to 8,026' with 2,971 psi . Spotted and fired gun with 2,971 psi on tubing. After 5 min - 2,949 psi, 10 min - 2,931 psi and 15 min - 2,913 psi. POOH. All shots fired. Gun was wet. Rig down lubricator and turn well over to field. 02/14/2020 - Friday ARRIVE @ BEAVER CREEK OFFICE, SIGN-IN/PERMIT/JSA, TALK W/CO MAN AND QUADCO REP ABOUT DAYS OPERATIONS AND PLAN FORWARD. MOBILIZE TO WELLSITE, SPOT EQUIPMENT, RU SLICKLINE AND 7" LUBRICATOR PT TO 250 PSI LOW AND 2000 PSI HIGH, TP - 0 PSI. RIH W/QUADCO PULLING TOOL BAITED WITH POLLARD ROPE SOCKET. RIH DOWN TO 8,500' WHICH IS PAST PACKER. FOUND WIRE HAD COME OUT OF COUNTER HEAD. PUT BACK IN AND GO ALL THE WAY TO 8,887' AND TOOLS SET DOWN. PULLED UP TO 3,500 LBS AND TOOL SLIPPED OFF. TRIED TO GET TOOLS TO LATCH PACKER BUT FINALLY SHEARED BAIT SUB THAT WAS ON QUADCO PULLING TOOL. TOP OF PACKER SHOULD BE AT 8,390'. SLICKLINE COUNTER WAS OFF. POOH AND LEFT QUODCO AND BAIT SUB IN HOLE. POOH. REPIN FLUID LEVEL - 550' RIH WITH GR AND TAG TOOLS AT 8,233'. LATCHED BAIT SUB WITH QUADCO PULLING TOOL. TRIED TO LATCH PACKER IF IT WAS THERE AND SHEARED OFF BAIT SUB AND QUADCO TOOL AGAIN. POOH AND REPIN. RIH W/ SAME 8,236'KB W/T 2,500 JAR LICK COMES FREE. POOH W/ QUADCO AND BAIT SUB. RIH W/3" PUMP BAILER TO SAME POOH - NO SAND JUST DIESEL- CHANGE OUT COUNTER HEAD. RIH W/4.5" LIB TO 8,162'KB. SPANG DOWN TWICE AND POOH. LIB SHOW IMBEDDED SAND. DID NOT SHOW PACKER TOP. CALLED TOWN AND WAS TOLD TO RIG SL DOWN. RIG DOWN SLICK LINE AND SECURE WELL. .IICO[p Ati18KA. LLL #: 214-060 50-133-20284-01 )es: FED A-028118 va fon: 141.2' (18.5'AGL) N60° 38' 32,402" W151° 2' 16.440" 6/02/2014 01.00 hrs 6/19/2014 12:30 hrs leased: 6/24/2014 6:00 lus Tree can - 9-1/2" Ods 8.0" Seal Diameter 5.12" Modiibd ID Bore TOC(USIT7/3/14)-1,850' 13-3/8" casing cmt top @ 2,130' (CBL 6/08/76) Casino/Cemenbna Detail - 9.4 ppg Mud - 10.5 ppg Mud Push (35 bbl) - 11.5 ppg Cement (245 bbl) - 153 ppg Cement (100 bbl) 8.4 ppg Lease Water (226 bb) Jewelry - - - - Depth 1. Swell Packer (21' Long) 1,869' 2. SUaddle Assembly 15' Long (112520) 8394'- 6,468'-6,466' 2-7/8" 10 8,409' 3. COP (1115/19) 8,543' 4. COP 5-12" 8,750' 5, CIBP 5-12" CIBP (Tested to 2,260 psi N2) 9,110' BCU - 7A Pad 7 1,500 FNL, 2,050' FEL, Sec. 4, T6N, R10W, S.M. j MBel e_-16 SR LBGT B-17 B-19 B-20 B-20 B-21 B-21 LWR B-22 LB -23 TOC LB -25 - 6,745' LB -26 LB -27 TOC LB -29 .9,052- L ,052'L LB-30 LB -31 RA Mkr Jt 2,998' RA Mkr Jt5,727' i PA 2 RA MktA 8,536' �ct RA Mkr Jlr- 8,678' 4 RA Mkr Jt 8,999' 5 RA Mkr Jt 9,188' SCHEMATIC Conductor 30" LP -B 310# weight Tog Bottom MD 0' 35' TVD 0' 35' 36" hole cant w/ 500 sks of Class -G Surface Casing 20" K-55 133.33#weight Tog Bottom MD 0' 2,072' TVD 0' 2,072- 26" hole chat w/ 3,200 sks of Class -G Intermediate Casing 13-3/8" BTC TOR Bottom MD 0' 2,214' K-55, 68# MD 2,214' 2,336' N-80, 72# 17-112" hole chat w/ 2,750 sks of Class -G, bumped plug Intermediate Casing 8-5/8" BTC TOR Bottom MD 0' 2,336' N-80, 47.0# 12-1/4" hole curt w/ 3,185 sks of Class -G ProductJon Casino 5-112" P-110 17opf DVVC/G-HT Top Bottom MD 0' 9,767' TVD 0' 0,896 7-7/9" hole Cant w/ 791 sks (N5 bbls) of 11.5 ppg, Lite Grate, 413 sks (100 bible) of 15.3 ppg, Class G omtw/EASYBLOK Zone MD TVD Size SPF Date M_Bel 7.242'-7,252' 6,468'-6,466' 2-7/8" 10 10/29/19 B-16 8015'-8,026' 7,166'-7,177' 2-7/8" 11 02/02/20 B-16 8,016-8,026' 7,167'-7,177' 2-72" 10 10/29/19 SR_LBGT 8,074'-8,081' 7,224'-7,230' 2-72" 6 02/02/20 SR_LBGT 6,075'-8,081' 7,225'-7,230' 2-72" 6 10/29/19 B-17 8,127'-8,142' 7,275'-7,290' 2-7/8" 15 03/14/19 B-19 8,245'-8,255' 7,390'-7,400' 2-72" 10 03/14/19 B-20 8,289'$,299' 7,433'-7,443' 2-7/8" 10 03/14/19 B-20 8,396'-8,406' 7,538'-7,547' 2-718" 10 03/14/19 Isolated B-21 8,451-8,456' 7,592'-7,597' 2-718" 5 02/11/19 B-21 LWR 8,496'-8,506' 7,636'-7,646 2-7/8' 10 0222/19 B-22 8,560'-8,575' 7,699'-7,714' 2-72" 15 0222/19 LB -23 8,610'-8,620' 7,748'-7,758' 33/8" 6 8108/14 LB -25 8709-8,728' 7,845'-7,864' 3316" 6 8/08/14 LB -26 B,770'-8,780' 7,906'-7.916' 3318" 6 8/08/14 LB -27 8,820'-8,830' 7,955'-7,965' 33/8" 6 8/08/14 18-29 9,045-9,060' 8,178'-8,103' 3318" 6 7/25/14 LB -30 9,123'9,135' 8,255'-8,26T 3318" 6 7/20/14 LB -30 9,155'-9,185' 8,287'-8,297' 33/8" 6 720/14 L631 9,210'-9,221' 8.341'-8,352' 3318" 12 7/16/14 ' Casing Shoe@8,767' Openhole Casing 33' off bottom Max Dogleg: 11.84°/100' @ 2,353' MaxInclination: 39.9° @ 3,350' Well Name &Number Beaver Creek Unit #7A Lease: TD: PBTD: Kenai Peninsula Borough 9,800' MD11 8,543' MD T Country: T USA 8,929' TVD 7,682' TVD Maximum Deviation: Max Dogleg: 11.84°/100' @ 2,353' MaxInclination: 39.9° @ 3,350' Well Name &Number Beaver Creek Unit #7A Lease: A-028118 County or Parish: Kenai Peninsula Borough State/Prov: Alaska T Country: T USA Angle@KOP and Depth: 0.0°@2,336' Angle/Perfs: 3.5°to 10.0° Maximum Deviation: 39.9°@3,350' Date Completed: 6/23/2014 Ground Level (above MSL): 122.7' RKB (above GL): 18.5' Revised By: Donna Ambruz Downhole Revision Data Schematic Revision Date: 2/26/2020 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Beaver Creek Field, Beaver Creek Oil — Beluga Gas Pool, BCU 07A Permit to Drill Number: 214-060 Sundry Number: 319-475 Dear Mr. York: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Jerem Price Chair DATED this day of October, 2019. RBDMSI"' OCT 2 2 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2n nnr 25 280 RECEIVED OCT 11 2019 Urs I 12.1 l9 AOGCC 1. Type of Request: Abandon El Plug Perforations ❑ `Fracture Stimulate ❑ Repair Well 11 Operations shutdown ❑ Suspend ❑ Perforate 0 i Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Nitrogen ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Tj I S Hilcorp Alaska, LLC Exploratory 11 Development Q Stratigraphic ❑ Service ❑ 214-060 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20284-01-00 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.v Yes © No � Beaver Creek Unit (BCU) 07A 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028118 ' Beaver Creek / Beaver Creek Oil - Beluga Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 9,800' 8,929' 9,682' 8,811' 505 psi 8,750 & 9,110 N/A Casing Length Size MD ND Burst Collapse Structural Conductor 35' 30" 35' 35' Surface 2,072' 20" 2,072' 2,077' 3,060 psi 1,500 psi Intermediate 2,336' 13-3/8" 2,336' 2,336' 3,450 psi 1,950 psi Production 2,336' 9-5/8" 2,336' 2,336' 6,870 psi 4,750 psi Liner 9,767' 5-1/2" 9,767' 8,896' 10,640 psi 7,460 psi 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 (ft) and TVD (ft): Swell Packer; N/A 1,869' MDfTVD 12. Attachments: Proposal Summary Wellbore schematic r 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Exploratory ❑ Stratigraphic ❑ Development Q Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: October 29, 2019 ❑ OIL WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑✓ ' WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Be York 777-8345 Contact Name: Christina Twogood Authorized Title: Operations Manager Contact Email: CtwO OOd hIICOr .Com Contact Phone: 777-8443 Authorized Signature: Date: 1 � u t� � Z UI COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: /(/tY 1 3 t Plug Integrity ❑ BOP Test Q Mechanical Integrity Test ElLocation Clearance ❑ Other: RBDMS �' OCT 212019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No F3/' Subsequent Form Required: % o —140`4 APPROVED BY �) Approved by: COMMISSIONER THE COMMISSION Date: t --�,��a1NP�� (, [0 Z Submit Form and For Revis d 4/20 7 Approved application i I 7 f S r m he dot¢ ofapproval. Attachments in Duplicate LC n 1$Icow Alaska, LL Well Prognosis Well: BCU -07A Date:10/14/2019 Well Name: BCU -07A API Number: 50-133-20284-01 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: October 291h, 2019 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-060 First Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) AFE Number: Current BHP: — 1,293 psi @ 7,553' TVD (Based on 2007 BCU 16 RFT data) Max. Expected BHP: — 1,213 psi @ 7,086' TVD (Based on actual reservoir pressure) Max. Potential Surface Pressure: — 505 psi (Based on actual reservoir pressure and gas gradient to surface (0.10psi/ft)) Brief Well Summary BCU -07A drilled and completed in 2014 targeting the lower Beluga formation. However, the first several sands proved to be non-productive and was plug backed to the LB -23. The well came online in the LB -23 making just over 2 MMCFD with little to no water. In February and March 2019 the Lower Beluga and a few Middle Beluga sands were perforated. The Middle Beluga sands caused the rate to drop off. One of the sands appears to be wet, causing the 5-1/2" wellbore to load up. The purpose of this work/sundry is to perforate the 137, 139, M_Beluga, B16 and SR LBGT sands in the Middle Beluga zone. Notes Regarding Wellbore Condition • CIBP and cement set @ 8,745' (TOC) Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job). • Ensure all crews are aware of stop job authority. E -line Procedure: 1. MIRU E -line and pressure control equipment. PT Lubricator to 250 psi Low / 3,000 psi High. 2. RIH with GPT tool and find fluid level. If fluid level is over the depth of the new perfs, discuss using Nitrogen with the Operations Engineer. 3. If needed, RU Nitrogen truck, pressure up on well and push water back into formation. Use GPT tool to confirm fluid level is below interval to perf. 4. RU perf guns. U Hilearp Alaska, LG 5. RIH and perforate the following intervals: Well Prognosis Well: BCU -07A Date: 10/14/2019 Zone Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Middle Beluga B7 +6,681' +6,698' +5,993' +6,010' 17' Middle Beluga B9 +6,951' +6,961' +6,215' +6,225' 10' Middle Beluga M_Beluga +7,242' +7,252' +6,458' +6,468' 10' Middle Beluga B16 +8,015' +8,026' +7,021' +7,032' 11' Middle Beluga SR_LBGT +8,074' +8,081' +7,079' +7,086' 7' a. Well may be shot flowing. If not, pressure up well to 1,000 psi before perforating. a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Use Gamma/CCL to correlate. d. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool. e. Record tubing pressures before and after each perforating run. f. Record 5, 10 and 15 minute pressures after firing guns. 6. POOH. 7. RDMO E -line. 8. Turn well over to production. E -Line Procedure (Contingency) 1. If these zones produce sand and/or water and need to he isolated: 2. MIRU E -Line and pressure control equipment. PT Lubricator to 250 psi Low/ 3,000 psi High. 3. RIH and set 3-1/2" Casing Patch or set CIBP above the zone and dump 35' of cement on top of the plug. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Standard Well Procedure — Nitrogen Operations Ifl r118CarD Ala9ka. LLII Permit* 214-060 API P. 50-133-20284-01 Prop. Des: FED A-028118 KS elevation' 141.2' (18.5'AGL) ,Lt. N60° 38' 32.402" Lona: W151° 2' 16.440 - Sault 6/02/2014 01:00 hrs M, 6/19/2014 12:30 bra Ria Released- 6/24/2014 6:00 his Tree cm -9-12" Is B.o" Seal Diameter St/8" Motlifletl ID Bore TOC (USIT 713114)-1,880' 13-3/8" casing cmt top @ 2,130'(CBL 6/08116) Casino/Cementing Dotall - 9.4 ppg Mud - 10.5 ppg Mud Push (35 bbl) 11.5 ppg Cement (245 bbl) - 163 ppg Cement (100 bbl) 8,4 ppg Lease Water (226 bbl) 1. Swell Padcer(2l'Long) 7,869 2. 5-12" CIBP 8,750' 3.5-1/2" CIBP(Tested to 2.260 psi N2) 9,110' U - 7A Pad 7 [:Sec�.4:,T6N, NL, 2,050' FEL, 7Mry R10W, S.M. M I I I I I I �• RA Mkr it 2,998' RA Mkr Jt 5,727' B-17 B-19 B-20 B-21 B-21 LWR LB-30 3 LB -30 Md RA Mkr it 9,188' LB -31 1 SCHEMATIC Conductor 30" LP -B 310#weight TOR Bottom MD 0' 35' WD 0' 35' 36" hole cast w/ 600 sks of Class -0 Surface Caslna t 8,536' B-22 B-20 Too Bottom LB -23 MD 0' 2,072' 03/14/19 WD 0' 2,072' 8,3968,406' 8,678' Intermediate Casing TOt Top Bottom LB -25 8,]4LB-262 f bumped plug Indermedi t Casing 9418" BTC LB-27TOt Mn 0' 2,336' N-80, 47.0# 12-1/4" hole cmtw/3,185 sks of Class -G 8.560'-8,575' Production Casing 8,999' 6412" P-110 17 Plot DWC/C-KT LB -23 Top Batlom LB -29 9,05 8108114 LB-30 3 LB -30 Md RA Mkr it 9,188' LB -31 1 SCHEMATIC Conductor 30" LP -B 310#weight TOR Bottom MD 0' 35' WD 0' 35' 36" hole cast w/ 600 sks of Class -0 B-19 Surface Caslna 7,390-7,400' 2-78" 10 20" K-65 133.33# weight B-20 Too Bottom 7,433'-7,443' 2-7/8" MD 0' 2,072' 03/14/19 WD 0' 2,072' 8,3968,406' 26" hole Con w/ 3,200 sks of Class -G Intermediate Casing 13418" BTC Top Bottom MD 0' 2,214' K-55, 68# MD 2,214' 2,336' N-80, 72# 17-1/2" hole cmt w/2,750 sks of Class -G, bumped plug Indermedi t Casing 9418" BTC Top Bottom Mn 0' 2,336' N-80, 47.0# 12-1/4" hole cmtw/3,185 sks of Class -G 8.560'-8,575' Production Casing 15 6412" P-110 17 Plot DWC/C-KT LB -23 Top Batlom 7,748'-7,758' 34/8" MD 0' 9,767' 8108114 TVD "8,896- 8,70&8,728' 7-718" bole Cmt w1791 sks (M bbls) of 11.6 ppg, 6 Lite Crets, 413 sks (100 1,11.) of 15.3 ppg, Class G LB -26 cmtwl EASYBLOK B-19 8,2454,255 7,390-7,400' 2-78" 10 03/14/19 B-20 8,2139'-8,299' 7,433'-7,443' 2-7/8" 10 03/14/19 B-20 8,3968,406' 7,536'd,54T 2-718" 10 03/14/19 B-21 8451-8,456 7,592'-7,597' 2418" 5 02111/19 8-21 LWR 8,496-8,506' 7,636-7,646' 2-7/8" 10 0222119 B-22 8.560'-8,575' 7.699-7,714 2-7/8" 15 0222119 LB -23 8.610'-8,620 7,748'-7,758' 34/8" 6 8108114 LB -25 8,70&8,728' 7,845'-7,864' 3-3/8" 6 8/08/14 LB -26 8.770'8,780' 7,906-7.916' 3418" 6 8/08/14 LB -27 8,820'-8,830' 7,955'-7,965' 3.3/8" 6 8/08114 LB -29 9,045'4060' 8,178'-8,193' 3.3/8" 6 712W14 LBO 9,123-9,135' 8,256$,267' 3318" 6 720114 LB -30 9155'-9.165' 8,287'-8,297' 3-318" 6 7120/14 LB -31 9.210'-9,221' 8,341'-8,362' 3-316" 12 7116/14 3 c Casing Shoe � 9,]67' Openhole Casing 33' off bottom TQ PBTD 9,800'MD 9,682'MO 8,929' WD 8,811' WD Max Dogleg: 11.84°/100' � 2,355' Maxlncllnagon: 39.9" 83,350' HilcorD Alaska, LLC penalt#: 214-060 APIL 50-133-20284-01 Prop. Des: FED A-028118 KB elevation: 141.2' (105' AGL) Lat. N60" 38' 32.402" Lona: W151- 2' 16.440" Spa§: 6/0272014 01:00 hm TD: 6/19/2014 1230 hm Rip Released: 6/24/2014 6:00 him Tres can -9-1R"OB9 • Lr WI OWnsW 5•tlr modified ID Bws I TOC1UB11'7/3114)-1,850' I 13518" casing clef top® 2,130' (CBL &03/78) CaslnalCementino Cotell - 9.4 =Mud - 10.5 pp9 Mud Push (35 b1a) - 11.5 pn Cement(245 bbl) - 15.3pn Cement(100bb0 8A ppg Lenee Weter(n6 bb0 2.5-1/2'CIBP 3. 51/2" CIBP (Tested W 2,260 psi N2) BCU - 7A Pad 7 1,800 FNL, 2,050' FEL, Sec. I4, T6N, R10W,, S.M. RA Mkr J12,998' 8-7 B-9 SR LBGT B-17 B-19 B-20 B-21 B-21 LWR Proposed SCHEMATIC Conductor 30" LP -13 3108 weight Too Bottom MD 0' 35' ND 0' 36- 36" hole chat w/ 500 sks of Class -G 9UItaCB Co.IM 2r K45 133.momilght im Bono. MD 0' 2,0n' TVD 0' 2,072' 26" hole ems w/ 3,200 Os of Class -e Intermatllst.c.1 13418" BTC LOR Bottom MD a 2,214' K-55, 688 VC) 2,216 2,338' N40, 728 17-1W hob cant w/ 2,750 sks of Class -0, humPad plop hwas elleb Casing 9516" BTC TT Bottow. MD 0' 2,338' N40, 47.08 12-114" hale cant w13,185 aks c1 Cie." Crodpg catlna 5-1rs' P-tf0 17Ppf OWCK:4tt OD Bottom MD e' ND e' flow 8,998' >Caholetsea(191 sb)ofbbb)of 11.5 0 Lite Can, 413 eke 11 W hbiq 01134 PP9, Clens G cant cal FJ19YBLOK Peflomtiona Zone MD TVD She SPF Date i RA Mkr A 8,536' 6,681'4898' 8-22 TBD &9 6.9514,%1' LB -23 TBD M_BN 7.247-7,257 6458'4988 TBD RA Mkr Jt 8,678' 8,015'-9925' 702•+7 Lit' TOC SR LBGT ell LB -25 8,745 - &17 6,127'-e, 142' ]275'-7290'2-7/8' 15 O&tU19 &19 8.245'-8,255' LB -26 O&14118 2 8.289-8,299' LB -27 0&14/19 B-20 8,396'5.406' 7,5lf)-4.547' 2-78" 10 03/14/19 RA Mkr A 8,999' 8,451-8,456' 7,592'-7.59T 2-718' 5 TOC B-21 LWR 8,498.5,506' L8.29 8,052' 5-22 8,560'5.575' 7,699'4,714' 24/8' 15 02/22/19 LB -23 th 7,748'-7,758' 33/8' 6 LB -30 LB -25 3 1,830 09' &08/14 LB -30 8,770'4)80' 7.906'-7816' 3-Wr 0 8.750 -&27 8,820'4,630 7,955'-7,965' 3318' 6 RA Mkr Jt 9,188' 8110• 9,045'-9,060' 8,178'4.188 3-&8' 6 7/2914 -B3o 9,123'-9,135' 8,255'-826T 341W 6 LB -31 .850 9,155'-9.1.65' Proposed SCHEMATIC Conductor 30" LP -13 3108 weight Too Bottom MD 0' 35' ND 0' 36- 36" hole chat w/ 500 sks of Class -G 9UItaCB Co.IM 2r K45 133.momilght im Bono. MD 0' 2,0n' TVD 0' 2,072' 26" hole ems w/ 3,200 Os of Class -e Intermatllst.c.1 13418" BTC LOR Bottom MD a 2,214' K-55, 688 VC) 2,216 2,338' N40, 728 17-1W hob cant w/ 2,750 sks of Class -0, humPad plop hwas elleb Casing 9516" BTC TT Bottow. MD 0' 2,338' N40, 47.08 12-114" hale cant w13,185 aks c1 Cie." Crodpg catlna 5-1rs' P-tf0 17Ppf OWCK:4tt OD Bottom MD e' ND e' flow 8,998' >Caholetsea(191 sb)ofbbb)of 11.5 0 Lite Can, 413 eke 11 W hbiq 01134 PP9, Clens G cant cal FJ19YBLOK Peflomtiona Zone MD TVD She SPF Date B-7 6,681'4898' 51993.6,010' TBD &9 6.9514,%1' 6,215'5225 TBD M_BN 7.247-7,257 6458'4988 TBD 8-18 8,015'-9925' 702•+7 Lit' T8D SR LBGT ell ' - TBD &17 6,127'-e, 142' ]275'-7290'2-7/8' 15 O&tU19 &19 8.245'-8,255' 7.390'-7.400' 2-7/8' 10 O&14118 8-20 8.289-8,299' 7433'4,443' 2416' 10 0&14/19 B-20 8,396'5.406' 7,5lf)-4.547' 2-78" 10 03/14/19 B-21 8,451-8,456' 7,592'-7.59T 2-718' 5 Oi/11/19 B-21 LWR 8,498.5,506' 7,tK1V,7,648' 2-718' 10 0282/19 5-22 8,560'5.575' 7,699'4,714' 24/8' 15 02/22/19 LB -23 8,610'4,820' 7,748'-7,758' 33/8' 6 810&14 LB -25 8,708-8.728' 7,845'4,864' 33/8" 6 &08/14 ,&26 8,770'4)80' 7.906'-7816' 3-Wr 0 8A0&14 -&27 8,820'4,630 7,955'-7,965' 3318' 6 8108114 -B-29 9,045'-9,060' 8,178'4.188 3-&8' 6 7/2914 -B3o 9,123'-9,135' 8,255'-826T 341W 6 720114 .850 9,155'-9.1.65' 8.2873,29T 3.318' 6 712&14 .831 9,210'-9,221' 8,361'4,352 33/8" 12 711&14 Openhole Cnning 33' op bottom TO• PSTO: 9,800'MD 9,682MD 8,829'TVD 8,811'TVD Max Cogle9: 11.801100' 0 2,353' Max hclinatlon: 399• @3,;=1' STANDARD WELL PROCEDURE FlarurpAlaska. LLC NITROGEN OPERATIONS 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 02 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. 12/08/2015 FINAL v1 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVhu APR 0 4 2019 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate LJ Pull TubingLl er i n shu down LJ Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: Hilcorp Alaska, LLC 4. Well Class Before Work: Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 5. Permit to Drill Number: 214-060 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20284-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028118 Beaver Creek Unit (BCU) 07A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Beaver Creek / Beaver Creek Oil - Beluga Gas Pool 11. Present Well Condition Summary: Total Depth measured 9,800 feet Plugs measured 8,750&9,110 feet true vertical 8,929 feet Junk measured N/A feet Effective Depth measured 9,682 feet Packer measured 1,869 feet true vertical 8,811 feet true vertical 1,869 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 35' 30" 35' 35' Surface 2,072' 20" 2,072' 2,077' 3,060 psi 1,500 psi Intermediate 2,336' 13-3/8" 2,336' 2,336' 3,450 psi 1,950 psi Production 2,336' 9-5/8" 2,336' 2,336' 6,870 psi 4,750 psi Liner 9,767' 5-1/2" 9,767' 8,896' 10,640 psi 7,460 psi 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) Swell Pkr; N/A 1,869' MD/TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 154 1 1 0 1 121 Subsequent to operation: 0 122 13 10 189 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory❑ Development P1 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil LJ Gas ✓ WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-034 ' Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: %ramer/d)hilcoro.c0m Authorized Signature: Date: ni Z,! •"\ Contact Phone: 777-8420 Form 10-404 Revised 4/2017 �,��, RBDMS1�APR 0 5 2019 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU 07A 50-133-20284-01-00 214-060 2/21/19 1 3/14/19 Daily Operations: 02/21/2019 - Thursday Sign in. PTW and Mobe to location. Spot equipment. Have tailgate safety meeting and talk over again. Rig up lubricator. PT to 250 psi low and 3,000 psi high. Wait on manlift. Well flowing 175K at 93 psi. RIH w/ 2-7/8" x 16' spent guns (3" OD) and tag obstruction at 8,730' KB. POOH. No problems. Ran this with well flowing. Could not determine fluid level. Will run GPT and perforate tomorrow morning. Rig down off well and turn well back over to field. Clean up work area and leave location. 02/22/2019 - Friday Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT lubricator to 250 psi low and 3,000 psi high. Well flowing 157 mcf at 93.4 psi. RIH w/GPT tool, tie into SLB RST log dated 3 Jul 14. and tag at 8,717'. Found fluid was coming up to 8,400' and falling back. Sent log to town. Get ok to go ahead with perf. POOH. Send log to town. RIH w/ 2-7/8" x1 5' Razor HC, 6 spf, 60 deg phase and tie into RST log. Run correlation log and send to town. Get ok to pert from 8 560' to 8,575'. Spot and fire gun with 93 psi/157 mcf. After 15 min it was 96 psi/207 mcf. POOH. All shots fired. Fired gun at 1310 hrs. POOH. Gun was wet. RIH w/ 2-7/8" x10' Razor HC, 6 spf, 60 deg phase and tie into RST log. Run correlation log and send to town. Get ok to perf from 8,496' to 8,506'. Spot and fire gun with 94 psi/178 mcf. After 15 min it was 94 psi/196 mcf. POOH. All shots fired. Fired gun at 1530 hrs. POOH Gun was moist. More dry than wet. RIH w/ 2-7/8" x 5' Razor HC, 6 spf, 60 deg phase and tie into RST log. Run correlation log and send to town. Get ok to perf from 8,451' to 8,456'. Spot and fire gun with 94 psi/179 mcf. After 15 min it was 100 psi/367mcf. POOH. All shots fired. Fired gun at 1720 hrs. POOH. Gun was moist. More dry than wet. Rig down lubricator and turn well over to field. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU 07A 50-133-20284-01-00 1 214-060 2/21/19 1 3/14/19 Daily Operations: 03/14/2019 - Thursday Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 3,000 psi high. NOTE: ALL RUNS BELOW WAS WITH WELL FLOWING. RIH w/ GPT tool and tie into Perf log dated 2-22-19. Tagged bottom at 8,715'. Ran GPT tool and it showed slugs of water from 6,200' to 8,715' with well flowing 285k at 91 psi. Sent log to town. POOH. RIH w/ 2-7/8" x 10' Razor HC, 6 spf, 60 deg phase and tie into GPT log. Ran correlation log and send to town. Got ok to pert from 8396' to 8406'. Spot and fire gun with well flowing 294k at 91.5 psi. Fired shot at 1345 hrs. After 5 min - 281k/91.6 psi, 10 min - 319.9k/92.3 psi and 15 min - 335.4k at 92.9 psi. POOH. All shots fired and gun was wet. RIH w/ 2-7/8" x 10' Razor HC, 6 spf, 60 deg phase and tie into GPT log. Ran correlation log and send to town. Told to shift log up 2'. Shifted log and sent back to town. Got ok to pert from 8,289' to 8,299'. Spotted gun and had a misfire. POOH and found gama ray tool shorted. RIH w/ 2-7/8" x 10' Razor HC, 6 spf, 60 deg phase and tie into GPT log. Ran correlation log and send to town. Got ok to perf from 8,289' to 8,299'. Spotted and fired gun at 1831 hrs w/ 275k/90 psi. 5 min - 300k/90 psi, 10 min 310k/91 psi and 15 min - 285k/90 psi. POOH. All shots fired and gun was wet. RIH w/ 2-7/8" x 10' Razor HC, 6 spf, 60 deg phase and tie into GPT log. Ran correlation log and send to town. Got ok to perf from 8,245 to 8,255'. Spotted and fired gun at 1957 hrs with well flowing 290k/90 psi. Good indication gun fired. There was basically no change in rate or pressure. POOH. All shots fired and gun was wet. RIH w/ 2-7/8" x 15' Razor HC, 6 spf, 60 deg phase and tie into GPT log. Ran correlation log and send to town. Got ok to pert from 8,127' to 8,142'. Spot and fire gun at 2130 hrs with well flowing 300k/91 psi. After 5 min - 340k/91, 10 min - 325k/91 psi and 15 min - 329k/91 psi. POOH. All shots fired and gun was wet. Rig down lubricator and equipment and turn well back over to field. Hileorp Alaska, LLC Permit #: 214-060 API #: 50-133-20284-01 Prop. Des: FED A-028118 KB elevation: 141.2' (18.5'AGL) Lat. N60° 38' 32.402" Lona: W151° 2' 16.440" Spud: 6/02/2014 01:00 firs TD: 6/19/2014 12:30 him Rip Released: 6/24/2014 6:00 hrs Tree cxn = 9-li2" Otis 8.0" Seal Diameter -6 V13" Modified 10 Bore CTp( ,i'Sl r 7/3114) -1,850 13.3/8" casing cmt top @ 2,130' (CBL 6/08!/6) Casina/Cementina Dead - 9.4ppg Mud - 10.5 ppg Mud Push (35 bbl) 11.5 ppg Cement (245 bbl) - 15.3 ppg Cement (100 bbl) 8.4 ppg Lease Water(226 bbil Jewelry Depth 1. Swell Packer(21' Long) 1,869' 2. 5-112"CIBP 8,750' 3.5-1/2" CIBP(Tested to 2,260 psi N2) 9,110' BCU - 7A Pad 7 1,800 FNL, 2,050' FEL, uu77 Sec. 4, T6N, R10W, S.M. ``rr RA Mkr A 2,998' SCHEMATIC Conductor 30" LP -B 310#weight T02 Sodom MD 0' 35' ND 0' 35' 36" hole cmt w/ 500 sks of Class -G Surface Casino 20" K-55 133.33# weight TT Bottom MD 0' 2,072' ND 0' 2,072' 26" hole cmt w/ 3,200 sks of ClassG Intermediate Casino 13-3/8" BTC TOR Bottom MD 0' 2,214' K56, 68# MD 2,214' 2,336' NAO, 72# 17-112" hole cmt w/ 2,750 sks of Class -G, bumped plug B-22 LB -23 TOC LB -26 8,74! LB -26 LB -27 TOG LB -29 9,052 a LB -30 LB -30 LB -31 ? Perforations: Zane MD Intermediate Casino Size RA Mkr Jt 5,727' B-17 8,127'-B, 142' 7,276-7,290' 2-718" 15 03/14/19 9-5/8" BTC 8,245'-8,255 4' Tog BotWm 10 ,7 i MD 0' 2,336' N50, 47.0# 8-20 8,289'-8,299' 12-114" hole cmt w/ 3,185 sks of ClassG B-17 10 03/14/19 B-19 B-20 8,3%6 ,406 7,538'-7,547' 4- Production Casing 8-20 c 5412" P-110 17 PM DWCICJIT 8,451-8,456' 7,592'-7,597' Top Boaom 5 02/11119 MD 0' 9,767' 8-21 7,636'-7,646' ND 0' 8,896' 10 02/22/19 7-718" hob Cost w1791 sks ( 245 bbl.) of 11.5 ppg, B-21 LWR 8,560'43,575' Lite Crete, 413 sks (100 bbls) of 15.3 ppg, Class G 2-718" 15 end wIEASYSLOK RA Mkr Jt 8,536' 8,610'-8,620' B-22 LB -23 TOC LB -26 8,74! LB -26 LB -27 TOG LB -29 9,052 a LB -30 LB -30 LB -31 ? Perforations: Zane MD ND-___ Size SPF Date B-17 8,127'-B, 142' 7,276-7,290' 2-718" 15 03/14/19 B-19 8,245'-8,255 7,390'-7,400' 2-418" 10 03/14/19 RA Mkr Jt 8,678' 8-20 8,289'-8,299' 7,433'-7,443' 2-718" 10 03/14/19 B-20 8,3%6 ,406 7,538'-7,547' 2-7/6" 10 03114119 c B-21 8,451-8,456' 7,592'-7,597' 2-718" 5 02/11119 B-21 LWR 8,496-8,506' 7,636'-7,646' 2-7/6 10 02/22/19 2 B-22 8,560'43,575' 7,699'-7,714' 2-718" 15 02122/19 LB -23 8,610'-8,620' 7,748'-7,758' 3-3/8" 6 WM14 LB -25 8,708'-8,728' 7,845'-7,864' 3-318" 6 8/08/14 LB -26 8,770'-8,780' 7,906'-7,916' 3-318" 6 8/08114 LB -27 6,820-8,83D' 7,955'-7,965' 3-318" 6 8/08114 RA Mkr Jt 8,999' LB -29 9,045'-9,060' 8,178'-8,193' 3-3/8" 6 7/25/14 LB -30 9,123'-9,135' 8,255'43,26T 3.9/8" 6 7120/14 - 18-30 9,155'-9,165' 8,287'-6,297' 316' 6 7120/14 - LB -31 9,210'-9221' 8,341'-8.352' 33/8" 12 7116/14 - 3 RA Mkr A 9,188' ifi Casing Shoe V� 9,76T Openhole Casing 33' off botrom 9,800 -MD 9,682'MD 8,929' ND 8,811' ND Max Dogleg: 11.84°/100' � 2,353' Max Inclination: 39.9- @ 3,350' THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 W W W.00gcc.alaska.gov Re: Beaver Creek Field, Beaver Creek Oil and Beaver Creek Gas Pool, BCU 07A Permit to Drill Number: 214-060 Sundry Number: 319-034 Dear Mr. York: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, -6� Daniel T. Seamount, Jr. Commissioner DATED this < day of February, 2019. SCANNED FEE U 5 2019 RECEIVED STATE OF ALASKA JAN T S 2Ois ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ��G� 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well p ❑ Operations shutdown 13 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: Hilcorp Alaska, LLC Exploratory ❑ Development Q Strati re hic Service ❑ g p ❑ 214-060 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20284-01-00 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 Li No ❑� Beaver Creek Unit (BCU) 07A , 9. Property Designation (Lease Number): 10. Field/Pool(s): _ FEDA028118 ' Beaver Creek / Beaver Creek Oil - Beluga Gas Pool it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,800' 8,929' 9,682' 8,811' -538psi 8,750 & 9,110 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 35' 30" 35' 35' Surface 2,072' 20" 2,072' 2,077' 3,060 psi 1,500 psi Intermediate 2,336' 13-3/8" 2,336' 2,336' 3,450 psi 1,950 psi Production 2,336' 9-5/8" 2,336' 2,336' 1 6,870 psi 4,750 psi Liner 9,767' 5-1/2" 9,767' 8,896' 1 10,640 psi 7,460 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic N/A N/A I N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Swell Packer; NIA 1,869' MD/TVD 12. Attachments: Proposal Summary —Ze—llboreschematic—El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: February 11, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: lkramerro-hilcoro.com l� Contact Phone: 777-8420 Z �h � � Authorized Signature: Date: 7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Q 1 O Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: K-/ / APPROVED BY 2 Approved by: COMMISSIONER THE COMMISSION Date: f" t 3 t► i(� �� (; I I RBDMS14" FEB 0 5 2019 Submit Forrn and 70-403 Revised 4/2017 Approved applica i I 4011¢ o t s the date of approval. �. /.�� Attachments in Duplicat Y� .moi il�< it. a. oI/QM .K 11 icorp Alaska, LG Well Prognosis Well: BCU -07A Date: 1/28/2019 Well Name: BCU-O7A API Number: 50-133-20284-01-a0 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: February 11`^, 2019 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: 7,079 Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-060 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867 -0665 (M) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-03411 (M) AFE Number: 25 B-20 8,289 Current Bottom Hole Pressure: Maximum Expected BHP: Max. Allowable Surface Pressure: Brief Well Summary - 1,293 psi @ 7,553' TVD - 1,293 psi @ 7,553' TVD - 538 psi (Based on BCU 16 RFT in 2007) (Based on BCU 16 RFT in 2007) (Based on reservoir potential pressure and gas gradient to surface (0.10psi/ft BCU -07A drilled and completed in 2014 targeting the lower Beluga formation. However, the first several sands proved to be non-productive and was plug backed to the Lower Beluga 23. The well came online in the LB -23 making just over 2 MMCFD with little to no water. The zone has cum'd just over 1.1 BCF and 900 bbls of water to date. Currently, BCU-O7A is making about 250 MCFD With intermitant slugs of water. The purpose of this work/sundry is to add the sands listed in the table below. Notes Regarding Wellbore Condition • CIBP and cement set @ 8,745' (TOC). E -line Procedure: 1. MIRU E -line, PT lubricator to 3,000 psi Hi 250 Low. 2. RIH and perforate the following intervals : Sands Top (MD) 8tm (MD) Top (TVD) Btm (TVD) ft B-16 81015 8,026 7,021 7,032 11 SR_LBGT 8,074 81081 7,079 7,086 7 B-17 8,127 8,151 7,131 7,153 24 B-19 8,240 8,265 7,237 7,272 25 B-20 8,289 8,322 7,288 7,320 33 B-20 8,355 8,378 7,353 7,375 23 B-20 8,396 8,406 7,392 7,402 10 B-21 8,451 8,456 7,447 7,452 5 B-21 LWR 8,496 8,506 7,492 7,501 10 B-22 8,560 8,575 7,553 7,570 15 a. aB Ip�ly .H Hiko,p M.A., LU Well Prognosis Well: BCU -07A Date:1/28/2019 a. Perfs may be shot one at a time and shot up to 12 JSPF (6 JSPF X 2). 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. Use Gamma/CCL/ to correlate. e. Record tubing pressures before and after each perforating run. f. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool. 3. RD E -line. 4. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic Hilcorp Alaska, LLC 50-133-20284-01 les: FED A-028118 la'on: 141.2' (18.5'AGL) N60° 38' 32.402" W151° 2' 16.440" 6/02(2014 01:00 him 6/19/2014 12:30 hrs eased: 6/24/2014 6:00 him Tree cxn - 8-0/2" Obs 8.0" Seal Diameter 5-1/8" Modified ID Bore TOC (USIT 713/14) -1,880' I 13-3/8" casing cmt top @ 2,130' (CBL 6/08/76) Jewelry Depth 1. Swell Packer (21' Long) 1,869- ,869'2.5-1/2" 2.5-V2"CIBP 8,750' 3. 5-1/2" COP (Tested to 2,260 psi N2) 9.110 BCU - 7A Pad 7 1,800 FNL, 2,050' FEL, Sec. 4, T6N, R10W, S.M. 1N III II I R rLB-23 LB -25 LB -26 LB -27 LB -29 LB -30 LB -30 i LB31 1 RA Mkt it 2,998' RA Mkr Jt 5,727 ,r RA Mkr Jt8,536' y,, Yt.2. TOC RA Mkr Jt 8,678' 1,745' 2 4 RA Mk' it 8,999' O2 s,osz ?s 3 RA Mkr it 9,188' SCHEMATIC conductor 30" LP -B 310#weight Too Bottom MD 0' 35' ND 0' 35' 36" hole cmt w/ 500 sks of Class -G Surface Casino 20" K-55 133.33# weight T� Bottom MD 0' 2,072' ND 0' 2,072' 26" hole can w/ 3,200 sks of Class -G Intermediate Casing 13-3/8" BTC TOP Bottom MD 0' 2,214' K-55, 68# MD 2,214' 2,336' N-80, 72# 17-1/2" hole con w/ 2,750 sks of Class -G, bumped plug Intermediate Casino 9-5/8" BTC TOP Bottom MD 0' 2,336' N-80, 47.0# 12-114" hole cmt w/ 3,185 sks of Class -G production Casing 5-112' P-110 17 Ppf DWC/C-W Top Bottom MD 0' 9,787' TVD 0' 8,896' 7-718" We Can wl 791 sks (U5 bbis) of 11.5 ppg, Lila Crete, 413 sks (100 Mal of 15.3 ppb, Class G cnn w1114$ eLOK Casina/Cementing Detail - 9.4 ppg Mud - 10.5 ppg Mud Push (35 bbl) - 11.5 ppg Cement (245 bbl) - 15.3 ppg Cement (100 bbl) 8.4 ppg Lease Water (226 bbl) Perforations: Zane MD TVD Size SPF Date LB -23 8,6108,620' 7,748'-7,758' 3318" 6 BM14 LB -25 8,706-8,728' 7,845-7,864' 3318" 6 8/08/14 LB -26 8,770-8,780' 7,906-7,916 3-3/8" 6 8/08114 LB -27 8,820'-8,830' 7,955'-7,965' 3-318" 6 8108114 LB -29 9,045'-9,066 8,176-8.193' 3-3/8" 6 7/25114 LB -30 9,123'-9,136 8,255'3,267 33/8" 6 7/20114 LB -30 9,155-9,165' 8,287-8,29T 33/8" 6 7/20/14 LB -31 9,210'-9,221' 8,341'-8,352' 3-3/6" 12 7116/14 CasingCasing5��9,767' Openhole Casing 33' off bottom Max Dogleg: 11.84°/100' � 2,353' Mex Inclination: 38.9° @ 3,350' Well Name B Number: Beaver Creek Unit #7ALease: TD: A-028118 9,800'MD8,929' IN Kenai Peninsula Borough ND County: USA Max Dogleg: 11.84°/100' � 2,353' Mex Inclination: 38.9° @ 3,350' Well Name B Number: Beaver Creek Unit #7ALease: A-028118 County or Parish: Kenai Peninsula Borough State/Prov: Alaska County: USA Angle QKOP and Depth: 0.0° 2,338' Angle/Perfs: 3.5° W 10.0° Maximum Deviation: 39.9° 3,350' Date Completed: 6/23/2014 Ground Level (above MSL):1 122.7' RKB (above GL): 18.5' Revised By: Donna Ambruz Downhole Revision Date: 8/8/2016 1 Schematic Revision Date: 3/23/2016 Hil"rp Alaska. LLC API #: 50-133-20284-01 Prop. Des: FED A-028118 KBelevatiow 141.2' (18.5'AGL) Lat. N60° 38' 32.402" Lona: W151° 2' 16.440" Spud: 6/02/2014 01:00 him TD: 6/19/2014 12'30 him Rig Released: 6/24/2014 6:00 hrs Tone ca" = 9-V 2" Otis 8.0" Seal Dmmeter 5-1/8" Modified ID Dore TOC(USIT7/3/14)-1,850' j 13-318" casing cmt top @ 2,130' (CBL 6/08/76) BCU - 7A Pad 7 1,800 FNL, 2,050' FEL, Sec. 4, T6N, R10W, S.M. J1 I II II I� 8.16 SR-LBGT B-17 B-19 B-20 B-21 B-21 LWR Jewelry B-22 1. Swell Packer (21' Long) 1,869' LB .23 8.750' Casing/Cementing Dealt 9p 10' TOC - 9.4 ppg Mud LB -25 8,745 ' - 10.5 ppg Mud Push (35 bbl) 2,336' MD 2,214' 2,336' N-80, 72# - 11.5 ppg Cement (245 bbl) 39.9° 3,360' 17-1/2" hole cmt w/ 2,750 sks of Class -G, - 15.3 ppg Cement (100 bbl) LB -26 bumped plug - 8.4 ppg Lease Water (226 bbd }� Intermediate Casing RA Mkr Jt 5,727' I Schematic Revision Date: 7/26/2019 LB -27 9.5/8" BTC TOL LB -29 9,052' Jewelry Depth 1. Swell Packer (21' Long) 1,869' 2. 5-112"CIBP 8.750' 3. 5-12" CIBP (Tested to 2,260 psi N2) 9p 10' LB -30 LB -30 LB -31 PROPOSED SCHEMATIC Conductor 30" LP -B 310#weight 10.2 Bottom MD 0' 35' TVD 0' 35' 36" hole colt w/ 500 sks of Class -G Surface Casing 20" K-55 133.33# weight Ton Bottom MD 0' 2,072' TVD 0' 2,072- 26" hole cmt w/ 3,200 sks of Class -G "UzOpenhole Casing 33' off bottom TD: PBTD: 9,800' MD 9,682' MD 8,929' TVD 8,811' TVD Maz Dogleg: 11.84°/100' a 2,353 - Max Inclination: 39.9° @ 3,350' Well Name & Number : Intermediate Casing Lease: 13.3/8" BTC County or Pansh: Tog Bottom R4 Mkr Jt 2,998 Slale/Prov: Alaska MD 0' 2,214' K-55,68# Angle CKOP and Depth:0.0° 2,336' MD 2,214' 2,336' N-80, 72# Maximum Deviation: 39.9° 3,360' 17-1/2" hole cmt w/ 2,750 sks of Class -G, 6/2 312 01 4 Grountl Level (above MSL): 122.7' bumped plug 18.5' Revised By: Intermediate Casing RA Mkr Jt 5,727' I Schematic Revision Date: 7/26/2019 9.5/8" BTC TOP Bottom MD 0' 2,336' N-80, 47.0# - 12-1/4" hole cmt w/ 3,185 sks of Class -G Production Casino - 5412" P-110 17 psi DWCIC-HT Top Bottom MD 0' 9,767' TVD 0' 8,896' = 7410" We Crm.1791 sks ( 245 bills) of 11.5 ppg, - Lite Crete, 413 site (100 bills) of 15.3 ppg, Class G - cmtwl EASYBLOK RA Mkr Jt 8,536' - Perforations, Zone MD TVD Size SEEa _= B-16 8,016-8,026' 7,021'-7,032' 11 Proposed SR-LBGT 8,074'-8,081' 7,079-7,086' 7 Proposed RA Mkr Jt 8,678' 817 8,127-8,151' 7,131'-7,153' 24 Proposed B-19 8,249-8,265' 7,237-7,277 25 Proposed c B-20 8,289-8,322' 7,288'-7,320 33 Proposed &20 8,355'-8,378' 7,353-7,375 23 Proposed 2 B-20 9395-8,406' 7,392'-7,402' 10 Proposed B-21 8,451$456' 7,447-7,452' 5 Proposed B-21 LWR 8,496'-8,506' 7,492'-7,501' 10 Proposed B-22 8580'-6,575' 7,553'-7,570' 15 Proposed LB -23 8,619-8,620' 7,748-7,758' 33/8° 6 8/01 14 RA Mkr A 8,999' LB -25 8,701 7,845-7,864' 3-31° 6 8100114 LB -26 8,776-8,789 7,908'-7,916 33/8" 6 8108114 - LB -27 8,820'-8,830' 7,955-7,965' 3-31" 6 8/08!14 LB -29 9045-9,080' 8,176-8,193' 331° 6 7/25/14 LB -30 9,123'-9135' 8,255-8.267- 331" 6 7/20114 �- 3 LB -30 9,156$165' 8,287--8,297- 3-Wir 6 7/20/14 L1331 9,216-9.221' 8.341'-8.352' 331W 12 7116/14 RA Mkr Jt 9,188' "UzOpenhole Casing 33' off bottom TD: PBTD: 9,800' MD 9,682' MD 8,929' TVD 8,811' TVD Maz Dogleg: 11.84°/100' a 2,353 - Max Inclination: 39.9° @ 3,350' Well Name & Number : Beaver Creek Unit#7A Lease: A-028118 County or Pansh: Kenai Peninsula Borough Slale/Prov: Alaska I County I USA Angle CKOP and Depth:0.0° 2,336' Angle/Peds: 3.5° W 10.0° Maximum Deviation: 39.9° 3,360' Date Completed: 6/2 312 01 4 Grountl Level (above MSL): 122.7' 1 RKB (above Gy: 18.5' Revised By: Donna Ambruz Downhole Revision Dale:I 8/8/2014 I Schematic Revision Date: 7/26/2019 STATE OF ALASKA ALIIIL OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations U Fracture Stimulate _I Pull Tubingj � Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 8rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska, LLC ment Develo Exploratory❑ p lorato ry ❑ 214-060 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20284-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028118 Beaver Creek Unit(BCU)07A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Beaver Creek/Beaver Creek Oil-Beluga Gas Pool 11.Present Well Condition Summary: Total Depth measured 9,800 feet Plugs measured 8,750&9,110 feet 1 true vertical 8,929 feet Junk measured N/A feet SPR 1 3 2016 Effective Depth measured 9,682 feet Packer measured 1,869 feet AOG V true vertical 8,811 feet true vertical 1,869 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 35' 30" 35' 35' Surface 2,072' 20" 2,072' 2,077' 3,060 psi 1,500 psi Intermediate 2,336' 13-3/8" 2,336' 2,336' 3,450 psi 1,950 psi Production 2,336' 9-5/8" 2,336' 2,336' 6,870 psi 4,750 psi Liner 9,767' 5-1/2" 9,767' 8,896' 10,640 psi 7,460 psi Perforation depth Measured depth See Attached Schematic SCANNED APR 2 2 2016 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) Swell Pkr; N/A 1,869'MD/TVD N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 813 Subsequent to operation: 0 106 4 0 1403 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑✓ Exploratory Development Li Service Li Stratigraphic Li Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas Li WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 316-177 Contact Joe Kaiser-777-8393 Email jkaiser@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature `/�"/ Phone 907-777-8405 Date Cizzzz44 /��f�'" Wi.3/I G Form 10-404 Revised 5/2015it., -` / , � 1,V b,PR 1 4 2016 Submit Original Only /s-(4 • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU 07A N/A 50-133-20284-01-00 214-060 3/16/16 3/16/16 Daily Operations: 03/16/2016-Wednesday Meet at office. Safety meeting. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,500 psi high. TP - 1,550 psi RIH w/4.53" GR/Junk basket and tie into SLB RST log dated 3-Jul-14. and tag fill at 9,087.5'. POOH. RIH w/4" x 30' dump bailer and dump bailed 17.5' of cement on top of fill at 9,087.5'. POOH, good dump. Cement in place at 1400 hrs. RIH w/4" x 30' dump bailer and dump bailed 17.5' of cement on top of cement at 9,070'. POOH -Good dump. (35' cement total)TOC est at 9,052.5'. Cement in place at 1615 hrs. RIH w/4.23" CIBP and tie into SLB RST log dated 3-Jul-14. Run correlation log and send to town. Get ok to set plug at 8,750'.Spotted plug and fired setting tool. After 2 min the plug set. Lost wt on tool line. Picked up 50' and slacked off, went down and lightly tagged plug at 8,750'. POOH. Everything looks like good set. TP 1,550 psi. RIH w/4" x 10' cement bailer and dump bailed 5' of cement on top of plug at 8,750'. Cement in place at 2030 hrs. Est TOC at 8,745'. Rig down lubricator and turn well over to field. • • • • BCU - 7A Pad? SCHEMATIC 1,800 FNL, 2,050'FEL, Sec.4, T6N, R10W, S.M. llileorp Alaska. LIA: Conductor Permit#: 214-060 30" LP-B 310#weight API#: 50-133-20284-01 Top Bottom Prop.Des: FED A-028118 TVD 0' 35' KB elevation: 141.2' (18.5'ADL) 36"hole cmt w/500 sks of Class-G Lat: N60° 38' 32.402" Lona: W151° 2' 16.440" Spud: 6/02/2014 01:00 hrs Surface Casing TD: 6/19/2014 12:30 hrs \ 20" K-55 133.33#weight Rio Released: 6/24/2014 6:00 his \\ To' Bottom MD 0' 2,072' 1 TVD 0' 2,072' 26"hole cmt w/3,200 sks of Class-G Tree cxn=9-1/2"Otis 8.0"Seal Diameter A ) 5-1/8"Modified ID Bore ZIntermediate Casing 13-3/8" BTC TOC(USIT 7/3/14)-1,850' "12g Bottom 1 •`RA MkrJt 2,998' MD MD 2,214' 2,214' K-55, 68# 2,336' N-80, 72# 13-3/8"casing cmt top @ 2,130'(CBL 6/08/76) 17-1/2"hole cmt w/2,750 sks of Class-G, bumped plug Intermediate Casing 9-5/8" BTC Top Bottom MD 0' 2,336' N-80, 47.0# 12-1/4"hole cmt w/3,185 sks of Class-G ' •`RA MkrJt 5,727' Production Casing 5-1/2" P-110 17 ppf DWC/C-HT Top Bottom MD 0' 9,767' ND 0' 8,896' 7-7/8"hole Colt w/791 sks(245 bbls)of 11.5 ppg, Lite Crete,413 sks(100 bbls)of 15.3 ppg,Class G cmt w/EASYBLOK ' •`RA Mkr Jt 8,536' Casing/Cementing Detail - - 9.4 ppg Mud LB-23 - 10.5 ppg Mud Push(35 bbl) - 11.5 ppg Cement(245 bbl) I `RA Mkr Jt 8,678' - 15.3 ppg Cement(100 bbl) TOC - 8.4 ppg Lease Water(226 bbl) LB-25 = 8,745' LB-26 2 Perforations: Zone MD TVD Size SPF Date LB-23 8,610'-8,620' 7,748'-7,758' 3-3/8" 6 8/08/14 LB-27 = LB-25 8,708'-8,728' 7,845-7,864' 3-3/8" 6 8/08/14 LB-26 8,770'-8,780' 7,906'-7,916' 3-3/8" 6 8/08/14 I . •`RA Mkr Jt 8,999' LB-27 8,820'-8,830' 7,955-7,965' 3-3/8" 6 8/08/14 TOC LB-29 9,045-9,060' 8,178'-8,193' 3-3/8" 6 7/25/14 LB-29 = 9,052' LB-30 9,123'-9,135' 8,255-8,267' 3-3/8" 6 7/20/14 LB-30 9,155'-9,165' 8,287-8,297' 3-3/8" 6 7/20/14 LB-31 9,210'-9,221' 8,341'-8,352' 3-3/8" 12 7/16/14 Jewelry Depth LB-30 - 3 1.Swell Packer(21'Long) 1,869' LB-30 2.5-1/2"CIBP 8,750 , ••RA MkrJt 9,188' 3.5-1/2"CIBP(Tested to 2,260 psi N2) 9,110' LB-31 4 Casing Shoe @ 9,767' Openhole Casing 33'off bottom Max Dogleg: 11.84°/100'@ 2,353' TD: PBTD: 9,800'MD 9,682'MD Max Inclination: 8,929'ND 8,811'ND 39.9°@ 3,350' _ Well Name&Number:_ Beaver Creek Unit#7A Lease: A-028118 County or Parish. Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth: 0.0°@ 2,336' Angle/Perfs:l 3.5°to 10.0° Maximum Deviation: 39.9°@ 3,350' Date Completed: 6/23/2014 Ground Level(above MSL): 122.7' RKB(above GL): 18.5' Revised By: Donna Ambruz Downhole Revision Date: 8/8/2014 Schematic Revision Date: 3/23/2016 OF Tit • y7:is. THE STATE Alaska Oil and Gas F -s-�a31; of LA S KA Conservation Commission 333 West Seventh Avenue '10.5" , . 1 GOVERNOR BILL WALKER'NIFAIAnchorage, Alaska 99501-3572 rn. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager SCANNED JJ 4 ,L'.!' Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Beaver Creek Field,Beaver Creek Oil and Beluga Gas Pools,BCU 07A Permit to Drill Number: 214-060 Sundry Number: 316-177 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this /O day of March,2016. RBDMS 0V MAR 1 1 2016 • 11 RECEIVED STATE OF ALASKA MAR 0 4 201 • ALASKA OIL AND GAS CONSERVATION COMMISSION D.rS UI/0//,4 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 11.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ i Suspend ElPerforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: iik ,2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5. Permit to Drill Number: Exploratory ❑ Development E . 214-060 3.Address. 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20284-01 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237A Beaver Creek Unit(BCU)07A ' Will planned perforations require a spacing exception? Yes ❑ No 9. Property Designation(Lease Number): 10. Field/Pool(s): FEDA028118 " Beaver Creek/Beaver Creek Oil-Beluga Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,800' ' 8,929' • 9,682' 8,811' —813 psi 9,110' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 35' 30" 35' 35' Surface 2,072' 20" 2,072' 2,077' 3,060 psi 1,500 psi Intermediate 2,336' 13-3/8" 2,336' 2,336' 3,450 psi 1,950 psi Production 2,336' 9-5/8" 2,336' 2,336' 6,870 psi 4,750 psi Liner 9,767' 5-1/2" 9,767' 8,896' 10,640 psi 7,460 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Swell Packer;N/A 1,869'MD/TVD 12.Attachments: Proposal Summary Q Wellbore schematic E 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: March 21,2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS j • WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser-777-8393 Email jkaiserl7a hilcorn.com Printed Name Chad Helgeson Title Operations Manager Signature ]% � Phone 907-777-8405 Date ��//6✓ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 5 '\ - \❑I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No LI Subsequent Form Required: /c. - "1�,1 RBDMS 1, 1/ MAR 1 1 2016 APPROVED BY Approved by:�AI_ COMMISSIONER THE COMMISSION Date:3 ../a- (6 ISubmit Form and Form 10-403 Rei d-1-1/20t RrI6aIPiA4lid for 12 months from the date of approval. ttachments inDijicate l GCf----- ,--------SL '3, 7 /cf., • Well Prognosis • Well: BCU-07A ilii`'"'"Alaska.LL' Date:3/4/2016 Well Name: BCU-07A API Number: 50-133-20284-01 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: March 215t, 2016 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: E-line Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-060 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) AFE Number: Maximum Expected BHP: — 1,632 psi @ 8,191' TVD (Based on current SI pressure and 0.1 psi/ft gradient to BHP) Max. Potential Surface Pressure: — 813 psi (Current shut-in pressure) Brief Well Summary The BCU 7A well was sidetracked with Saxon #169 as Beaver Creek Unit#7A and the 5-1/2" production longstring was cemented in late June 2014. February 2016 a production survey was run indicating all gas was comingfrom the LB 23 and 25 sands.,This well is producing small amounts of water. The purpose of this work/sundry is to set a 5-1/2" CIBP to shut off water production below the LB-25 sand and prevent any cross flow. Notes Regarding Wellbore Condition • Plan to tag and drift with slickline before running E-line. E-line Procedure: 1. MIRU E-line, PT lubricator to 2,000 psi Hi 250 Low. 2. MU 5-1/2" CIBP. RIH w/CIBP. Set CIBP at 8,750'. POOH. 3. MU Bailer assembly. RIH w/ bailler and dumpbail approx. 5' of cement on CIBP. (Note: More cement will plug perforation above). POOH. 4. RD E-line. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic • • . 11 BCU - 7A ACTUAL Pad 7 SCHEMATIC 1,800 FNL, 2,050'FEL, Sec.4, T6N, R10W, S.M. tlil('.00p Alaska,LIA: Conductor Permit#: 214-060 30" LP-B 310#weight Ig2 Bottom API#: 50-133-20284-01 MD 0' 35' Prop.Des: FED A-028118 TVD 0' 35' KB elevation: 141.2' (18.5'AGL) 36"hole cmt w/500 sks of Class-G Lat: N60° 38' 32.402" Long: W151° 2' 16.440" 01: �� Spud: 6/02/2014 01:00 hrs Surface Casinq TD: 6/19/2014 12:30 his --- 20" K-55 133.33#weight Rig Released: 6/24/2014 6:00 hrs \ TOp Bottom MD 0' 2,072' 1 TVD 0' 2,072' 26"hole cmt w/3,200 sks of Class-G Tree cxn=9-1/2"Otis 8.0"Seal Diameter • 5-1/8"Modified ID Bore '.." �`` Intermediate Casinq 13 3/8 TOC(USIT 7/3/14)-1,850' i TOS Bottom BTC RA MkrJt 2,998' MD 0' 2,214' K-55, 68# PA * MD 2,214' 2,336' N-80, 72# 13-3/8"casing cmt top @ 2,130'(CBL 6/08/76) 17-1/2"hole cmt w/2,750 sks of Class-G, r. bumped plug Intermediate Casinq 9-5/8" BTC 0•" y*, Top Bottom MD 0' 2,336' N-80, 47.0# 12-1/4"hole cmt wl 3,185 sks of Class-G ".4 RA MkrJt5,727' Production Casinq 64.1.41 i 5-112" P-110 17 ppf DWC/C-HT Top Bottom MD 0' 9,767' 4 y TVD 0' 8,896' 7-7/8"hole Cmt w1791 sks(245 bbls)of 11.5 ppg, Lite Crete,413 sks(100 bbls)of 15.3 ppg,Class G cmt w/EASYBLOK 4 4 RA Mkr Jt 8,536' Casing/Cementing Detail .* - 9.4 ppg Mud - 10.5 ppg Mud Push(35 bbl) LB-23ll 4 - 11.5 ppg Cement(245 bbl) RA Mkr Jt 8,678' - 15.3 ppg Cement(100 bbl) - 8.4 ppg Lease Water(226 bbl) LB-25 LB-26 - Perforations: Zone MD TVD Size SPF Date LB-23 8,610'-8,620' 7,746-7,758' 3-3/8" 6 8/08/14 LB-27 LB-25 8,708'-8,728' 7,845'-7,864' 3-3/8" 6 8/08/14 LB-26 8,770'-8,780' 7,906-7,916' 3-3/8" 6 8/08/14 RA Mkr Jt 8,999' LB-27 8,820'-8,830' 7,955'4,965' 3-3/8" 6 8/08/14 LB-29 9,045'-9,060' 8,178'-8,193' 3-3/8" 6 7/25/14 LB-29 s LB-30 9,126-9,135' 8,255'-8,267' 3-3/8" 6 7/20/14 LB-30 9,156-9,165' 8,287'-8,297' 3-3/8" 6 7/20/14 LB-31 9,210'-9,221' 8,341'-8,352' 3-3/8" 12 7/16/14 Jewelry Depth LB-30 2 1.Swell Packer(21'Long) 1,869' LB-30 a.-7--. 2.5-1/2"CIBP(Tested to 2,260 psi N2) 9,110' ' •RA Mkr Jt 9,188' • LB-31 Casing Shoe @ 9,767' - Openhole Casing 33'off bottom Max Dogleg: 11.84°/100'@ 2,353' TD: PBTD: Max Inclination: 9,800'MD 9,682'MD 8,929'ND 8,811'ND 39.9°@ 3,350' Well Name&Number: Beaver Creek Unit#7A Lease: A-028118 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth: 0.0°@ 2,336' Angle/Perfs:I 3.5°to 10.0° Maximum Deviation: 39.9°@ 3,350' Date Completed: 6/23/2014 Ground Level(above MSL): 122.7' RKB(above GL): 18.5' Revised By: Stan Porhola Downhole Revision Date: 8/8/2014 Schematic Revision Date: 8/11/2014 ! • • • ll BCU - 7A PROPOSED Pad 7 1,800 FNL, 2,050'FEL, SCHEMATIC Sec.4, T6N, R10W, S.M. Hilt'orp Alaska. I.I.(' Conductor Permit#: 214-060 30" LP-B 310#weight API#: 50-133-20284-01 % # TO�J Bottom Prop.Des: FED A-028118 "" TVD 0' 35' KB elevation: 141.2' (18.5'AGL) 36"hole cmt w/500 sks of Class-G Lat: N60° 38' 32.402" Long: W151° 2' 16.440" Spud: 6/02/2014 01:00 hrs Surface Casinq TD: 6/19/2014 12:30 hrs ) 20" K-55 133.33#weight Rio Released: 6/24/2014 6:00 hrs \ TOp Bottom MD 0' 2,072' 1 TVD 0' 2,072' 26"hole cmt w/3,200 sks of Class-G Tree cxn=9-112"Otis 8.0"Seal Diameter 5-1/8"Modified ID Bore ZbJ ' Intermediate Casinq 13-3/8" BTC TOC(USIT 7/3/14)-1,850' Top Bottom - RA MkrJt 2,998' MD 0' 2,214' K-55, 68# MD 2,214' 2,336' N-80, 72# 13-3/8"casing cmt top @ 2,130'(CBL 6/08/76) V 17-1/2"hole cmt w/2,750 sks of Class-G, bumped plug I.,, Intermediate Casinq 9-5/8" BTC Top Bottom MD 0' 2,336' N-80, 47.0# `' 12-1/4"hole cmt w/3,185 sks of Class-G i . ' RA MkrJt 5,727' Production Casinq 5-1/2" P-110 17 ppf DWC/C-HT . Top Bottom MD 0' 9,767' - . ND 0' 8,896' 7-7/8"hole Cmt WI 791 sks(245 bbls)of 11.5 ppg, Lite Crete,413 sks 1 100 bbls)of 15.3 ppg,Class G cmt w/EASYBLOK RA Mkr Jt 8,536' Casina/Cementina Detail - 9.4 ppg Mud LB-23 �_ - 10.5 ppg Mud Push(35 bbl) 11.5 ppg Cement(245 bbl) Ir ,RA M kr Jt 8,678' - 15.3 ppg Cement(100 bbl) 8.4 ppg Lease Water(226 bbl) LB-25 LB-26 - 2 U Perorations: a f' Zone MD TVD Size SPF Date LB-23 8,610'-8,620' 7,746-7,758' 3-3/8" 6 8/08/14 LB-27 - LB-25 8,708'-8,728' 7,845-7,864' 3-3/8" 6 8/08/14 LB-26 8,770'-8,780' 7,906-7,916' 3-3/8" 6 8/08/14 RA MkrJt 8,999' LB-27 8,820'-8,830' 7,955'-7,965' 3-3/8" 6 8/08/14 LB-29 9,046-9,060' 8,178'-8,193' 3-3/8" 6 7/25/14 LB-29 = - LB-30 9,123'-9,135' 8,255'-8,267' 3-3/8" 6 7/20/14 LB-30 9,156-9,165' 8,287'-8,297' 3-3/8" 6 7/20/14 LB-31 9,210'-9,221' 8,341'-8,352' 3-3/8" 12 7/16/14 Jewelry Depth LB-30 - - 3 1.Swell Packer(21'Long) 1,869' LB-30 - 2.5-1/2"CIBP(Proposed) 53,750' ' •4 RA MkrJt 9,188' 3.5-1/2"CIBP(Tested to 2,260 psi N2) 9,110' LB-31 • w' Casing Shoe @ 9,767' Openhole ''ti`, { ,' Casing 33'off bottom Max Dogleg: 11.84°/100'@ 2,353' TD: PBTD: 9,800'MD 9,682'MD Max Inclination: 8,929'ND 8,811'ND 39.9°@ 3,350' Well Name&Number: Beaver Creek Unit#7A Lease: A-028118 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle©KOP and Depth: 0.0°@ 2,336' Angle/Perfs:I 3.5°to 10.0° Maximum Deviation: 39.9°@ 3,350' Date Completed: 6/23/2014 _ Ground Level(above MSL): 122.7' RKB(above GL): 18.5' Revised By: Joe Kaiser Downhole Revision Date: 8/8/2014 Schematic Revision Date: 3/4/2016 21 4060 Seth Nolan Hilcorp Alaska, LLC 2 6 7 7 0 GeoTech II 3800 Centerpoint Drive - Anchorage, AK 99503 Tele: 907 777-8308 Hilrnrp SIst4a.I.t.t. Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED 2•A1/2014 M.K.BENDER DATE 01/20/16 RECEIVED To: Alaska Oil & Gas Conservation Commission FEB 0 2 2010 Makana Bender Natural Resource Technician AOGCC W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 7A NED Alm 0 2 2016 Elog data RST-GR-CCL USIT-GR-CCL CD 1: Final Well Data Run 1A 1/19/7016 4:49 PM File folder Run 1B 1/19/70164:49 PM 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 Received By. Date: 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 direct inspection of the file. b . 1 - 0 160 Well Histo File Identifier Organizing (done) Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: Color Items: ❑ Ma s: rayscale Items: ogs: ❑ Poor Quality Originals: E Other: ❑ Other: BY: Maria Date: S isi 7 � Project Proofing BY: Maria Date: _ S /s/ Scanning Preparation � x 30 = I ao + g - TOTAL PAGES 1 a.9 (Count does not include cover sheet) BY: (Maria Date: 7 a7//45". /s/ Production Scanning Stage 1 Page Count from Scanned File: 13 v(Count does include cove heet) Page Count Matches Number in Scanning7/c7/i5 Preparation: YES NO BY: __ Date: /s/ 04 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Aii- .?,---' Stage 2 Additional Well Reports: GI 11NO TOTAL PAGES.'") 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Dat Comp.,Susp.,or 12. Permit to Drill Number: Hilcorp Alaska,LLC Aband.: f:f-`84!`LQ14 • 214-060 - 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Drive STE 1400 Anchorage,AK 99503 6/2/2014 50-133-20284-01-00 - 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 1783'FNL,2033'FEL.Sec 4,T6N, R1OW, SM,AK • June 19,2014 Beaver Creek(BCU)7A • Top of Productive Horizon: 8. KB(ft above MSL): 143.6'•15. Field/Pool(s): 1172'FNL,893'FWL,Sec 3,T6N, R1OW, SM,AK GL(ft above MSL): 125' • Beaver Creek Total Depth: 9. Plug Back Depth(MD+TVD): Beluga Gas Pool - 1133'FNL. 1029'FWL.Sec 3.T6N, R1OW,SM.AK •9590'MD/87191-VD - 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 313703.08- y- 2428177.429 - Zone- 4 - 9,800'MD/8,9281-VD • A028118 TPI: x- 316632.56 y- 2428750.93 Zone- 4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth x- 316768.75 y- 2428788.16 Zone- 4 NA N/A 18. Directional Survey: Yes r✓ - No ❑ 19.Water Depth, if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MC/TVD: ROP, DGR.EWR-Phase4,ALD,CTN, RST-GR-CCL. MUDLOGS(already submitted) • 2,344'MD/TVD 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 5-1/2" 17 P-110 Surf 9.766.58' Surf 8.896' 7-7/8" 1204sks/345bb1 24.Open to production or injection? Yes E 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 1,869'MD/TVD Zone Top(MD/TVD) Btm(MD/TVD) Size SPF, --,,,,,,..�/ LB-23 8,610'/7,748' 8,62077,758' 3-3/8" 6 4?s C1' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. LB-25 8,708'/7,845' 8,72877,864' 3-3/8" 6Meas hydraulic fracturing used during completion? Yes L No ❑✓ LB-26 8,770'/8,770' 8,780/7,916' 3-3/8" 6 �� DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LB-27 8,820'/7,955' 8,830'/7,965' 3-3/8" 6 LB-29 9,045'/8,178' 9,060'/8,193' 3-3/8" 6 7�5•ly4 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing,gas lift,etc.): 8/9/2014 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 8/14/2014 24.00 Test Period -O.0 1820 0 3 N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 2275 0 24-Hour Rate . 0 1820 - 0 N/A 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No r❑ . Sidewall Cores Acquired? Yes ❑ No❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RBI M? OCT 14 2014-7 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only 2y. GEOLOGIC MARKERS (List all formations -1 markers encountered): 30. FORMATION TESTS , NAME TVD Well testes YLd - , If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base STERLING_B 5300 4862 BC_B1ST 5317 4876 BC_B3ST 5601 5109 BC_B4ST 5782 5257 BELUGA 6500 5845 M_BELUGA 7163 6392 SR_LBGT 8051 7201 BC_B17ST 8069 7219 BC_B18UST 8165 7312 BC_B19ST 8233 7378 BC_B2OST 8311 7454 LWR_BELUGA 8388 7529 BC_B21ST 8415 7556 BC_B22ST 8490 7630 BC_B23ST 8556 7695 BC_B24ST 8699 7836 BC_B25ST 8722 7858 BC_B26ST 8744 7880 BC_B27ST 8767 7903 BC_B28ST 8820 7955 BC_B29ST 9016 8149 BC_B3OST 9122 8254 BC_B31ST 9208 8339 BC_B31_B_ST 9303 8434 SR_TYONEK 9662 8791 Formation at total depth:Tyonek 9800 8928 31. List of Attachments: Schematic, Days v Depth,MW v Depth.Directional Suvery,Daily Composites,Casing and Cement Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Monty Mack Myers Email: mmyers(a)hilcorp.com Printed Name: Monty Mack Myers Title: Drilling Engineer Signature: — - Phone: 907-777-8431 Date: 10/14/2014 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 1 b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical BCU - 7A ACTUAL Pad 7 1,800 FNL, 2,050'FEL, SCHEMATIC Sec.4, T6N, R10W, S.M. /lilt urp Alaska.IAA: Conductor 'Permit#: 214-060 I, 30" LP-B 310#weight API#: 50-133-20284-01TOS Bottom MD 0' 35' Prop.Des: FED A-028118 TVD 0' 35' KB elevation: 141.2' (18.5'AGL) 36"hole cmt w/500 sks of Class-G Lat: N60° 38' 32.402" Long: W151° 2' 16.440" Spud: 6/02/2014 01:00 hrs Surface Casing TD: 6/19/2014 12:30 hrs \ 20" K-55 133.33#weight Rig Released: 6/24/2014 6:00 hrs \\ TOS Bottom MD 0' 2,072' TVD 0' 2,072' 1 26"hole cmt w/3,200 sks of Class-G Tree can=9-1/2"Otis 8.0"Seal Diameter 5-1/8"Modified ID Bore :li Intermediate Casing 13-3/8" BTC TOC(USIT 7/3/14)-1,850' lain Bottom •RA Mkr Jt 2,998' MD 0' 2,214' K-55, 68# . MD 2,214' 2,336' N-80, 72# 13-3/8"casing cmt top @ 2,130'(CBL 6/08/76) 17-1/2"hole cmt w/2,750 sks of Class-G, bumped plug Intermediate Casing 9-5/8" BTC Top Bottom MD 0' 2,336' N-80, 47.0# 12-1/4"hole cmt w/3,185 sks of Class-G a•RA Mkr Jt 5,727' Production Casing 5-112" P-110 17 ppf DWC/C-HT Top Bottom • MD 0' 9,767' TVD 0' 8,896' 7-7/8"hole Cmt w/791 sks(245 bbls)of 11.5 ppg, Lite Crete,413 sks(100 bbls)of 15.3 ppg,Class G cmt w/EASYBLOK '•RA Mkr Jt 8,536' Casing/Cementinn Detail - 9.4 ppg Mud - 10.5 ppg Mud Push(35 bbl) LB-23 - 11.5 ppg Cement(245 bbl) a•RA Mkr Jt 8,678' - 15.3 ppg Cement(100 bbl) - 8.4 ppg Lease Water(226 bbl) LB-25 LB-26 Perforations: Zone MD TVD Size SPF Date L8-23 8,616-8,620' 7,746-7,758' 3-3/8" 6 8/08/14 LB 27 LB-25 8,708'-8,728' 7,845-7,864' 3-3/8" 6 8/08/14 LB-26 8,776-8,780' 7,906-7,916' 3-3/8" 6 8/08/14 '•RA Mkr Jt 8,999' LB-27 8,820'-8,830' 7,955'-7,965' 3-3/8" 6 8/08/14 LB-29 9,045'-9,060' 8,178'-8,193' 3-3/8" 6 7/25/14 LB-29 LB-30 9,123'-9,135' 8,255'-8,267' 3-3/8" 6 7/20/14 LB-30 9,156-9,165' 8,287'-8,297' 3-3/8" 6 7/20/14 • ` _ LB-31 9,210'-9,221' 8,341'-8,352' 3-3/8" 12 7/16/14 Jewelry Depth LB-30 2 1.Swell Packer(21'Long) 1,869' LB-30 2.5-1/2"CI BP(Tested to 2,260 psi N2) 9,110' •RA Mkr Jt 9,188' LB-31 Casing Shoe @ 9,767' Openhole Casing 33'off bottom Max Dogleg: 11.84°/100'@ 2,353' TD: PBTD: 9,800'MD 9,682'MD Max Inclination: 8,929'TVD 8,811'TVD 39.9°@ 3,350' Well Name&Number: Beaver Creek Unit#7A Lease: A-028118 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:I USA Angle @KOP and Depth. 0.0°X2,336' Angle/Perfs:l 3.5°to 10.0° Maximum Deviation: 39.9°@ 3,350' Date Completed: 6/23/2014 Ground Level(above MSL): 122.7' RKB(above GL): 18.5' Revised By: Stan Porhola Downhole Revision Date: 8/8/2014 Schematic Revision Date: 8/11/2014 BCU SECTION 33 T7N R10W PAD No.1-A .._ _.._ _.—.— —..— —..— —..—._._.._ —•'— —. —"— —"— — — —.._._.._ 33 34 SECTION 4 T6N R10W '-'- -"- —'— — — — — - N:2429928.96 4 3 E:315760.77 1 NOTES 1) BASIS OF GEODETIC CONTROL AND NAD83 POSITION(EPOCH 2003)IS AN OPUS SOLUTION FROM NGS COORDINATES STATIONS"KEN1 CORS ARP","TLKA TALKEETNA CORS ARP",AND"POT3 POTATO POINT 3 ARP"TO ESTABLISH THE POSITION OF MCI BC1.THE GEODETIC POSITION OF BC1 WAS DETERMINED TO HAVE A LATITUDE OF 60°38'50.02777"N AND A LONGITUDE OF AS-BUILT WELL �LL 151°02'22.30311"W.THE ALASKA STATE PLANE BCU 7 ^ COORDINATES(ASP)ZONE 4 ARE N:2428177.429' N=2429933.534 E:313703.081' E=1453863.065 ELEV.131.31'(NAVD88) LAT:60°38'32.406"N LONG:-151°02'16.440"W 2) BASIS OF VERTICAL CONTROL IS NGS BM V80 ASP ZONE 4 NAD27 PID TT0508 LOCATED WITHIN THE KENAI SPUR o ! ,, FEL=2033' HIGHWAY RIGHT OF WAY AT MILE POST 3.75 E FNL= 1783' HAVING AN ELEVATION OF 164.55 FEET NAVD ! 88 ACCORDING TO NGS PUBLISHED DATA. z I z ELEV= 126.94'(NAVD88) I- i 1-- SECTION 4,T6N, R1OW,SM,AK 3) COORDINATES CONVERTED TO NAD27 USING z i z CORPSCON6 CONVERSION SOFTWARE l IIII w i w co I co 2033' BCU FEL PAD No.7 SECTION 4 T6N R10W S.M.,AK ___„_IN ....„„„,I k '(EQFA(4lit� P ' ��49 x:70 NORTH i ill' H e� •.STAN A. 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Q O N Nco (O U co - QV r- �v - a0oa O CD 0 0 G N N ON N J a+ .ci- Co C CD N NN r 0-3 o0 Hilcorp Energy Company Beaver Creek Unit Beaver Creek Unit Rig: BCU-07A 501332028401 Sperry flrilling Definitive Survey Report 07 July, 2014 HALLIBURTON Sperry Drilling L :t: Beaver Creek Unit WELL DETAILS: Beaver 7 NAD 1927(NADCONCONUS) Alaska Zone 04 HALLIBLIRTON cite: Beaver Creek Unit Ground Level: 126.94 Well: Beaver CK Unit 7 +N/-S +E1-W Northing Easting Latittude Longitude Slot Sperry Grilling Services Wellbore: BCU-07A 0.00 0.00 2428177.43 313703.08 60.6423350 -151.0379001 Plan: BCU-07A REFERENCE INFORMATION 1000— Co-ordinate(N/E)Reference:Well Beaver CK Unit 7,True North Vertical(TVD)Reference:BCU-7A Actual @ 144.54usft Measured Depth Reference:BCU-7A Actual @ 144.54058 Calculation Method:Minimum Curvature 1500- 2000— i.20" 2500- 3000— 3500- 4000— _ 4500— c_ u) o 5000— o - o - r - 5500— CI 6000— a) - H - 6500- 7000— 7500— _ 8000- 8500- 9000— BCU-07A 9500— BCU-07A wP2c - __BCU 7 10000 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 IF III if -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 Vertical Section at 78.17°(1000 usft/in) ri I lilcorp k§ | ,•-.!: - . (kk - s k :D § , § §)) ( •°! ) » ® •-•'A 2 g»»E @!t, c !§§k ® , z1' _ r )_ § • w t it \ o ] _ , a �.J, d ( ce (kms -- ©1!0 — • !«, _ , a /�1 - «a 2 $` - cv $$ - - cg\ el - o o o \ __� , \ /5 —r ; ) Y - k}) oo « & § §2\ - , % ) m $\/ \fid ==c== _ \ ƒ® ©§ A § 2] } 24RE - - a ƒ - o 0 �,~ \ : kk 7 f= I °° 6 \\ - ' k ' _ . ®f 7{\]6 § ^ & - U) -0 2‹....... 0.z | r- \ 0 ; ■ - § i 1 III II , 1111111111 111111 III III , II [ I 11111111111111111 I 11111 1 1 i I / / § ® qJ ® - - - , , Ii (uyusn mQ(+)9KNR q Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 7 Project: Beaver Creek Unit ND Reference: BCU-7A Actual @ 144.54usft Site: Beaver Creek Unit MD Reference: BCU-7A Actual @ 144.54usft Well: Beaver CK Unit 7 North Reference: True Wellbore: Rig:BCU-07A Survey Calculation Method: Minimum Curvature Design: BCU-07A rig surveys 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 7 Well Position +N/-S 0.00 usft Northing: 2,428,177.43 usft Latitude: 60°38'32.406 N +EI-W 0.00 usft Easting: 313,703.08 usft Longitude: 15V 2'16.440W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 126.94 usft Wellbore Rig:BCU-07A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2013 6/1/2014 16.99 73.62 55,459 Design BCU-07A rig surveys Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,336.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 17.60 0.00 0.00 78.17 Survey Program Date 7/7/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 98.34 2,335.00 BCU-7(Gyro)(BCU 7) NS-Gyro-MS Fixed:v2:North-seeking gyro multishot 06/06/2014 2,336.00 2,603.91 BCU-7A(MWD_Interp Azi+Sag)(Rig:BC MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sag 06/03/2014 2,666.84 9,761.85 BCU-7A Rig Survey(Rig:BCU-07A) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 06/04/2014 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 17.60 0.00 0.00 17.60 -126.94 0.00 0.00 2,428,177.43 313,703.08 0.00 0.00 UNDEFINED 98.34 0.54 160.92 98.34 -46.20 -0.36 0.12 2,428,177.07 313,703.20 0.67 0.05 NS-Gyro-MS(1) 198.34 0.56 149.88 198.33 53.79 -1.23 0.52 2,428,176.19 313,703.59 0.11 0.26 NS-Gyro-MS(1) 298.34 0.42 155.12 298.33 153.79 -1.98 0.92 2,428,175.43 313,703.97 0.15 0.50 NS-Gyro-MS(1) 398.34 0.44 161.97 398.33 253.79 -2.68 1.20 2,428,174.73 313,704.23 0.06 0.62 NS-Gyro-MS(1) 498.34 0.27 153.94 498.33 353.79 -3.26 1.42 2,428,174.15 313,704.45 0.18 0.72 NS-Gyro-MS(1) 598.34 0.22 180.07 598.32 453.78 -3.66 1.52 2,428,173.74 313,704.54 0.12 0.74 NS-Gyro-MS(1) 698.34 0.19 154.00 698.32 553.78 -4.00 1.59 2,428,173.40 313,704.61 0.10 0.74 NS-Gyro-MS(1) 798.34 0.20 175.03 798.32 653.78 -4.32 1.68 2,428,173.08 313,704.69 0.07 0.76 NS-Gyro-MS(1) 898.34 0.09 169.66 898.32 753.78 -4.58 1.71 2,428,172.83 313,704.72 0.11 0.74 NS-Gyro-MS(1) 998.34 0.10 118.57 998.32 853.78 -4.69 1.80 2,428,172.71 313,704.81 0.08 0.80 NS-Gyro-MS(1) 1,098.34 0.07 162.07 1,098.32 953.78 -4.79 1.90 2,428,172.60 313,704.90 0.07 0.87 NS-Gyro-MS(1) 7/7/2014 5:09:56PM Page 3 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 7 Project: Beaver Creek Unit TVD Reference: BCU-7AActual©144.54usft Site: Beaver Creek Unit MD Reference: BCU-7AActual @ 144.54usft Well: Beaver CK Unit 7 North Reference: True Wellbore: Rig:BCU-07A Survey Calculation Method: Minimum Curvature Design: BCU-07A rig surveys Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,198.34 0.06 359.43 1,198.32 1,053.78 -4.80 1.92 2,428,172.60 313,704.92 0.13 0.89 NS-Gyro-MS(1) 1,298.34 0.17 314.23 1,298.32 1,153.78 -4.64 1.81 2,428,172.76 313,704.82 0.13 0.82 NS-Gyro-MS(1) 1,398.34 0.06 30.12 1,398.32 1,253.78 -4.50 1.73 2,428,172.91 313,704.74 0.17 0.77 NS-Gyro-MS(1) 1,498.34 0.18 33.95 1,498.32 1,353.78 -4.32 1.84 2,428,173.08 313,704.86 0.12 0.92 NS-Gyro-MS(1) 1,598.34 0.19 7.80 1,598.32 1,453.78 -4.03 1.95 2,428,173.37 313,704.97 0.08 1.09 NS-Gyro-MS(1) 1,698.34 0.16 31.40 1,698.32 1,553.78 -3.74 2.05 2,428,173.65 313,705.07 0.08 1.24 NS-Gyro-MS(1) 1,798.34 0.03 305.87 1,798.32 1,653.78 -3.61 2.10 2,428,173.79 313,705.12 0.16 1.32 NS-Gyro-MS(1) 1,898.34 0.15 58.69 1,898.32 1,753.78 -3.52 2.19 2,428,173.87 313,705.22 0.16 1.42 NS-Gyro-MS(1) 1,998.34 0.07 102.05 1,998.32 1,853.78 -3.47 2.36 2,428,173.92 313,705.39 0.11 1.60 19S-Gyro-MS(1) 2,098.34 0.09 25.55 2,098.32 1,953.78 -3.41 2.46 2,428,173.98 313,705.48 0.10 1.70 NS-Gyro-MS(1) 2,198.34 0.09 102.20 2,198.32 2,053.78 -3.36 2.57 2,428,174.03 313,705.59 0.11 1.82 NS-Gyro-MS(1) 2,298.34 0.03 171.68 2,298.32 2,153.78 -3.40 2.65 2,428,173.99 313,705.67 0.08 1.89 NS-Gyro-MS(1) 2,298.74 0.03 171.68 2,298.72 2,154.18 -3.40 2.65 2,428,173.99 313,705.67 0.00 1.89 NS-Gyro-MS(1) 2,336.00 0.03 108.26 2,335.98 2,191.44 -3.41 2.66 2,428,173.98 313,705.68 0.08 1.90 MWD_InterpAzi+sag(2) 2,417.19 3.90 52.31 2,417.11 2,272.57 -1.73 4.86 2,428,175.62 313,707.92 4.78 4.41 M1ND_InterpAzi+sag(2) 2,479.72 5.72 53.45 2,479.42 2,334.88 1.43 9.05 2,428,178.71 313,712.15 2.91 9.15 MWD_InterpAzi+sag(2) 2,542.72 7.56 54.05 2,541.99 2,397.45 5.73 14.93 2,428,182.92 313,718.10 2.92 15.78 MWD_InterpAzi+sag(2) 2,603.91 9.35 54.41 2,602.51 2,457.97 10.99 22.23 2,428,188.06 313,725.48 2.93 24.01 MWD_InterpAzi+sag(2) 2,666.84 11.02 58.81 2,664.45 2,519.91 17.08 31.53 2,428,194.00 313,734.88 2.93 34.36 MWD+SC+sag(3) 2,729.38 13.20 63.48 2,725.60 2,581.06 23.36 43.04 2,428,200.11 313,746.48 3.82 46.91 MWD+SC+sag(3) 2,790.12 17.26 70.05 2,784.19 2,639.65 29.53 57.72 2,428,206.05 313,761.26 7.25 62.55 MWD+SC+sag(3) 2,853.31 17.73 75.50 2,844.47 2,699.93 35.14 75.85 2,428,211.37 313,779.47 2.70 81.44 MWD+SC+sag(3) 2,915.38 21.69 79.03 2,902.89 2,758.35 39.69 96.27 2,428,215.60 313,799.96 6.66 102.36 MWD+SC+sag(3) 2,976.47 23.30 81.60 2,959.33 2,814.79 43.61 119.30 2,428,219.15 313,823.06 3.09 125.71 MWD+SC+sag(3) 3,039.61 25.65 80.21 3,016.79 2,872.25 47.76 145.13 2,428,222.89 313,848.94 3.83 151.83 MWD+SC+sag(3) 3,102.57 30.87 78.08 3,072.23 2,927.69 53.41 174.38 2,428,228.08 313,878.28 8.44 181.63 MWD+SC+sag(3) 3,162.99 31.72 78.14 3,123.86 2,979.32 59.88 205.09 2,428,234.06 313,909.09 1.41 213.01 MWD+SC+sag(3) 3,226.93 33.31 78.16 3,177.78 3,033.24 66.94 238.73 2,428,240.59 313,942.84 2.49 247.38 MWD+SC+sag(3) 3,288.27 36.57 78.97 3,228.05 3,083.51 73.89 273.16 2,428,247.00 313,977.37 5.37 282.50 MWD+SC+sag(3) 3,350.03 39.85 80.33 3,276.57 3,132.03 80.74 310.73 2,428,253.25 314,015.05 5.48 320.68 MWD+SC+sag(3) 3,410.47 38.97 80.58 3,323.27 3,178.73 87.10 348.57 2,428,259.01 314,052.99 1.48 359.02 MWD+SC+sag(3) 3,472.80 39.47 81.05 3,371.56 3,227.02 93.39 387.48 2,428,264.69 314,091.99 0.93 398.39 MWD+SC+sag(3) 3,536.12 38.41 80.97 3,420.81 3,276.27 99.61 426.79 2,428,270.29 314,131.39 1.68 438.14 MWD+SC+sag(3) 3,598.13 38.11 81.51 3,469.50 3,324.96 105.46 464.74 2,428,275.53 314,169.42 0.72 476.48 MWD+SC+sag(3) 3,659.54 36.87 80.30 3,518.23 3,373.69 111.36 501.64 2,428,280.85 314,206.42 2.35 513.81 MWD+SC+sag(3) 3,721.94 35.76 80.36 3,568.51 3,423.97 117.57 538.07 2,428,286.49 314,242.94 1.78 550.74 MWD+SC+sag(3) 3,784.05 35.02 79.89 3,619.14 3,474.60 123.73 573.51 2,428,292.09 314,278.47 1.27 586.69 MWD+SC+sag(3) 3,846.37 33.92 79.23 3,670.52 3,525.98 130.12 608.19 2,428,297.93 314,313.25 1.86 621.95 MWD+SC+sag(3) 3,908.50 34.40 78.92 3,721.93 3,577.39 136.73 642.45 2,428,304.00 314,347.61 0.82 656.83 MWD+SC+sag(3) 3,970.71 33.71 78.87 3,773.47 3,628.93 143.44 676.63 2,428,310.17 314,381.89 1.11 691.67 MWD+SC+sag(3) 7/7/2014 5:09:56PM Page 4 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 7 Project: Beaver Creek Unit TVD Reference: BCU-7AActual @ 144.54usft Site: Beaver Creek Unit MD Reference: BCU-7AActual @ 144.54usft Well: Beaver CK Unit 7 North Reference: True Wellbore: Rig:BCU-07A Survey Calculation Method: Minimum Curvature Design: BCU-07A rig surveys Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E1-W Northing Easting DIS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,032.70 33.87 77.75 3,824.99 3,680.45 150.43 710.39 2,428,316.62 314,415.76 1.04 726.14 MWD+SC+sag(3) 4,094.10 35.27 77.60 3,875.55 3,731.01 157.87 744.43 2,428,323.52 314,449.91 2.28 760.98 MWD+SC+sag(3) 4,156.51 35.33 76.70 3,926.48 3,781.94 165.89 779.59 2,428,330.99 314,485.19 0.84 797.04 MWD+SC+sag(3) 4,219.31 35.47 77.36 3,977.67 3,833.13 174.05 815.04 2,428,338.59 314,520.76 0.65 833.41 MWD+SC+sag(3) 4,280.48 34.71 76.57 4,027.72 3,883.18 181.98 849.29 2,428,345.98 314,555.14 1.45 868.56 MWD+SC+sag(3) 4,343.12 34.89 77.01 4,079.16 3,934.62 190.15 884.10 2,428,353.60 314,590.07 0.49 904.30 MWD+SC+sag(3) 4,405.32 35.03 78.24 4,130.14 3,985.60 197.79 918.91 2,428,360.68 314,625.00 1.16 939.94 MWD+SC+sag(3) 4,467.68 34.67 78.56 4,181.31 4,036.77 204.95 953.82 2,428,367.30 314,660.01 0.65 975.57 MWD+SC+sag(3) 4,528.89 34.20 78.05 4,231.80 4,087.26 211.97 987.71 2,428,373.78 314,694.01 0.90 1,010.19 MWD+SC+sag(3) 4,590.10 35.47 79.33 4,282.04 4,137.50 218.82 1,021.99 2,428,380.08 314,728.40 2.39 1,045.15 MWD+SC+sag(3) 4,652.43 36.31 79.85 4,332.53 4,187.99 225.42 1,057.93 2,428,386.12 314,764.44 1.43 1,081.67 MWD+SC+sag(3) 4,715.58 35.65 80.27 4,383.64 4,239.10 231.82 1,094.47 2,428,391.94 314,801.08 1.12 1,118.75 MWD+SC+sag(3) 4,777.82 34.70 79.43 4,434.51 4,289.97 238.14 1,129.77 2,428,397.70 314,836.47 1.71 1,154.59 MWD+SC+sag(3) 4,840.19 35.13 80.34 4,485.65 4,341.11 244.41 1,164.91 2,428,403.41 314,871.71 1.08 1,190.27 MWD+SC+sag(3) 4,902.35 34.19 80.10 4,536.78 4,392.24 250.41 1,199.75 2,428,408.87 314,906.63 1.53 1,225.60 MWD+SC+sag(3) 4,964.51 35.58 78.71 4,587.77 4,443.23 256.95 1,234.69 2,428,414.86 314,941.67 2.58 1,261.14 MWD+SC+sag(3) 5,026.95 35.12 78.58 4,638.70 4,494.16 264.07 1,270.11 2,428,421.41 314,977.20 0.75 1,297.27 MWD+SC+sag(3) 5,089.06 34,50 78.74 4,689.70 4,545.16 271.04 1,304.87 2,428,427.83 315,012.07 1.01 1,332.72 MWD+SC+sag(3) 5,151.32 34.78 78.78 4,740.92 4,596.38 277.94 1,339.58 2,428,434.18 315,046.88 0.45 1,368.11 MWD+SC+sag(3) 5,213.44 35.05 77.68 4,791,86 4,647.32 285.19 1,374.39 2,428,440.88 315,081.80 1.10 1,403.66 MWD+SC+sag(3) 5,275.67 35.66 76.26 4,842.61 4,698.07 293.31 1,409.47 2,428,448.45 315,117.00 1.64 1,439.66 MWD+SC+sag(3) 5,337.79 35.24 75.85 4,893.22 4,748.68 301.99 1,444.43 2,428,456.58 315,152.10 0.78 1,475.66 MWD+SC+sag(3) 5,399.88 34.77 76.25 4,944.08 4,799.54 310.58 1,479.00 2,428,464.62 315,186.80 0.84 1,511.26 MWD+SC+sag(3) 5,462.12 35.29 77.54 4,995.04 4,850.50 318.68 1,513.79 2,428,472.17 315,221.72 1.45 1,546.97 MWD+SC+sag(3) 5,524.35 34.93 77.76 5,045.95 4,901.41 326.33 1,548.76 2,428,479.27 315,256.80 0.61 1,582.76 MWD+SC+sag(3) + + 5,585.80 34.31 78.36 5,096.52 4,951.98 333.56 1,582.91 2,428,485.95 315,291.06 1.15 1,617.67 MWD SC sag(3) 5,647.80 35.38 77.90 5,147.40 5,002.86 340.85 1,617.58 2,428,492.69 315,325.84 1.78 1,653.10 MWD+SC+sag(3) 5,710.21 35.24 78.31 5,198.33 5,053.79 348.28 1,652.88 2,428,499.57 315,361.25 0.44 1,689.17 MWD+SC+sag(3) 5,771.75 35.08 78.82 5,248.64 5,104.10 355.31 1,687.61 2,428,506.05 315,396.09 0.54 1,724.61 MWD+SC+sag(3) 5,833.88 34.51 78.20 5,299.66 5,155.12 362.37 1,722.35 2,428,512.56 315,430.94 1.08 1,760.06 MWD+SC+sag(3) 5,895.85 34.81 80.29 5,350.64 5,206.10 368.94 1,756.97 2,428,518.59 315,465.66 1.98 1,795.29 MWD+SC+sag(3) 5,957.46 33.72 80.34 5,401.55 5,257.01 374.78 1,791.17 2,428,523.88 315,499.94 1.77 1,829.96 MWD+SC+sag(3) 6,018.42 35.04 80.43 5,451.86 5,307.32 380.53 1,825.11 2,428,529.09 315,533.97 2.17 1,864.35 MWD+SC+sag(3) 6,080.82 34.84 80.67 5,503.02 5,358.48 386.40 1,860.36 2,428,534.40 315,569.31 0.39 1,900.06 MWD+SC+sag(3) 6,143.62 34.52 80.84 5,554.66 5,410.12 392.14 1,895.63 2,428,539.59 315,604.66 0.53 1,935.76 MWD+SC+sag(3) 6,205.38 35.83 80.39 5,605.14 5,460.60 397.94 1,930.73 2,428,544.84 315,639.85 2.16 1,971.30 MWD+SC+sag(3) 6,267.55 35.59 81.04 5,655.62 5,511.08 403.80 1,966.54 2,428,550.12 315,675.75 0.72 2,007.55 MWD+SC+sag(3) 6,329.57 35.10 81.71 5,706.21 5,561.67 409.18 2,002.01 2,428,554.95 315,711.30 1.01 2,043.37 MWD+SC+sag(3) 6,392.06 34.79 82.03 5,757.43 5,612.89 414.24 2,037.44 2,428,559.45 315,746.81 0.58 2,079.09 MWD+SC+sag(3) 6,453.48 35.49 80.70 5,807.66 5,663.12 419.55 2,072.39 2,428,564.21 315,781.84 1.69 2,114.39 MWD+SC+sag(3) 7/7/1014 5:09:56PM Page 5 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 7 Project: Beaver Creek Unit TVD Reference: BCU-7A Actual @ 144.54usft Site: Beaver Creek Unit MD Reference: BCU-7A Actual @ 144.54usft Well: Beaver CK Unit 7 North Reference: True Wellbore: Rig:BCU-07A Survey Calculation Method: Minimum Curvature Design: BCU-07A rig surveys Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 6,516.02 35.71 79.68 5,858.51 5,713.97 425.75 2,108.27 2,428,569.84 315,817.81 1.01 2,150.77 MWD+SC+sag(3) 6,577.92 35.41 80.31 5,908.87 5,764.33 432.01 2,143.72 2,428,575.54 315,853.35 0.76 2,186.75 MWD+SC+sag(3) 6,639.53 35.37 77.70 5,959.10 5,814.56 438.81 2,178.73 2,428,581.79 315,888.47 2.45 2,222.42 MWD+SC+sag(3) 6,701.76 35.16 77.74 6,009.91 5,865.37 446.45 2,213.84 2,428,588.87 315,923.70 0.34 2,258.35 MWD+SC+sag(3) 6,762.94 34.68 78.25 6,060.07 5,915.53 453.74 2,248.10 2,428,595.62 315,958.06 0.92 2,293.37 MWD+SC+sag(3) 6,826.73 34.84 76.39 6,112.48 5,967.94 461.72 2,283.57 2,428,603.04 315,993.66 1.68 2,329.73 MWD+SC+sag(3) 6,887.89 34.76 76.01 6,162.70 6,018.16 470.05 2,317.47 2,428,610.83 316,027.69 0.38 2,364.61 MWD+SC+sag(3) 6,948.33 34.40 75.81 6,212.46 6,067.92 478.40 2,350.74 2,428,618.65 316,061.08 0.62 2,398.89 MWD+SC+sag(3) 7,011.53 33.92 76.50 6,264.76 6,120.22 486.89 2,385.20 2,428,626.60 316,095.67 0.98 2,434.35 MWD+SC+sag(3) 7,074.28 33.47 76.49 6,316.97 6,172.43 495.02 2,419.05 2,428,634.20 316,129.64 0.72 2,469.15 MWD+SC+sag(3) 7,136.25 33.09 76.42 6,368.77 6,224.23 502.99 2,452.11 2,428,641.64 316,162.82 0.62 2,503.14 MWD+SC+sag(3) 7,198.89 32.63 75.74 6,421.39 6,276.85 511.16 2,485.10 2,428,649.29 316,195.94 0.94 2,537.11 MWD+SC+sag(3) 7,261.24 31.83 75.55 6,474.13 6,329.59 519.40 2,517.31 2,428,657.02 316,228.28 1.29 2,570.33 MWD+SC+sag(3) 7,323.60 31.48 75.75 6,527.22 6,382.68 527.52 2,549.02 2,428,664.63 316,260.11 0.59 2,603.02 MWD+SC+sag(3) 7,384.35 30.28 76.31 6,579.35 6,434.81 535.05 2,579.27 2,428,671.68 316,290.48 2,03 2,634.18 MWD+SC+sag(3) 7,447.01 27.25 76.19 6,634.28 6,489.74 542.21 2,608.56 2,428,678.39 316,319.87 4.84 2,664.31 MWD+SC+sag(3) 7,508.87 25.44 76.63 6,689.71 6,545.17 548.66 2,635.24 2,428,684.42 316,346.65 2.94 2,691.75 MWD+SC+sag(3) 7,571.05 24.62 76.54 6,746.05 6,601.51 554.77 2,660.83 2,428,690.12 316,372.34 1.32 2,718.04 MWD+SC+sag(3) 7,633.32 23.45 76.47 6,802.92 6,658.38 560.68 2,685.49 2,428,695.64 316,397.09 1.88 2,743.40 MWD+SC+sag(3) 7,695.77 21.32 76.96 6,860.66 6,716.12 566.15 2,708.63 2,428,700.75 316,420.32 3.42 2,767.17 MWD+SC+sag(3) 7,756.28 19.44 76.67 6,917.38 6,772.84 570.96 2,729.15 2,428,705.23 316,440.91 3.11 2,788.23 MWD+SC+sag(3) 7,819.20 16.86 76.48 6,977.16 6,832.62 575.51 2,748.21 2,428,709.47 316,460.04 4.10 2,807.83 MWD+SC+sag(3) 7,880.70 15.09 75.29 7,036.29 6,891.75 579.62 2,764.63 2,428,713.33 316,476.52 2.93 2,824.74 MWD+SC+sag(3) 7,942.13 14.50 74,92 7,095.68 6,951.14 583.65 2,779.79 2,428,717.12 316,491.74 0.97 2,840.40 MWD+SC+sag(3) 8,005.58 13.94 74,60 7,157.18 7,012.64 587.75 2,794.83 2,428,720.98 316,506.84 0.89 2,855.96 MWD+SC+sag(3) 8,067.55 13,67 76.16 7,217.36 7,072.82 591.49 2,809.13 2,428,724.49 316,521.20 0.74 2,870.73 MWD+SC+sag(3) 8,128.64 13.38 76.58 7,276.76 7,132.22 594.85 2,823.02 2,428,727.64 316,535.14 0.50 2,885.01 MWD+SC+sag(3) 8,191.27 13.24 76.12 7,337.71 7,193.17 598.25 2,837.03 2,428,730.82 316 549.20 0.28 2,899.42 MWD+SC+sag O 3 8,253.33 12.59 77.09 7,398.20 7,253.66 601.47 2,850.52 2,428,733.82 316,562.74 1.10 2,913.28 MWD+SC+sag(3) 8,316.12 12.46 76.95 7,459.49 7,314.95 604.53 2,863.79 2,428,736.67 316,576.06 0.21 2,926.90 MWD+SC+sag(3) 8,378.04 11.51 76.59 7,520.06 7,375.52 607.47 2,876.31 2,428,739.41 316,588.62 1.54 2,939.75 MWD+SC+sag(3) 8,440.28 10.83 74.84 7,581.12 7,436.58 610.44 2,887.99 2,428,742.20 316,600.35 1.22 2,951.80 MWD+SC+sag(3) 8,501.90 10.54 74.44 7,641.68 7,497.14 613.47 2,899.01 2,428,745.05 316,611.41 0.49 2,963.20 MWD+SC+sag(3) 8,560.91 10.20 73.06 7,699.72 7,555.18 616.44 2,909.21 2,428,747.86 316,621.66 0.71 2,973.79 MWD+SC+sag(3) 8,626.20 9.79 73.67 7,764.02 7,619.48 619.68 2,920.06 2,428,750.93 316,632.56 0.65 2,985.08 MWD+SC+sag(3) 8,688.48 9.49 72.45 7,825.42 7,680.88 622.72 2,930.04 2,428,753.81 316,642.59 0.58 2,995.47 MWD+SC+sag(3) 8,750.41 9.22 73.64 7,886.53 7,741.99 625.65 2,939.67 2,428,756.59 316,652.26 0.54 3,005.49 MWD+SC+sag(3) 8,812.49 8.55 73.50 7,947.86 7,803.32 628.37 2,948.87 2,428,759.16 316,661.50 1.08 3,015.05 MWD+SC+sag(3) 8,874.98 8.25 71.83 8,009.68 7,865.14 631.08 2,957.58 2,428,761.74 316,670.26 0,62 3,024.14 MWD+SC+sag(3) 8,937.43 8.51 74.81 8,071.47 7,926.93 633.69 2,966.30 2,428,764.21 316,679.01 0.81 3,033.20 MWD+8C+sag(3) 7/7!2014 5:09:56PM Page 6 COMPASS 5000.1 Build 70 , Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 7 Project: Beaver Creek Unit TVD Reference: BCU-7A Actual @ 144.54usft Site: Beaver Creek Unit MD Reference: BCU-7A Actual @ 144.54usft Well: Beaver CK Unit 7 North Reference: True Wellbore: Rig:BCU-07A Survey Calculation Method: Minimum Curvature Design: BCU-07A rig surveys 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) (°1100') (ft) Survey Tool Name 8,999.80 8.58 76.87 8,133.14 7,988.60 635.96 2,975.28 2,428,766.33 316,688.03 0.50 3,042.46 MWD+SC+sag(3) 9,058.92 8.36 77.04 8,191.62 8,047.08 637.92 2,983.76 2,428,768.16 316,696.54 0.37 3,051.17 MWD+SC+sag(3) 9,123.88 8.24 77.96 8,255.90 8,111.36 639.95 2,992.92 2,428,770.05 316,705.73 0.28 3,060.54 MWD+SC+sag(3) 9,186.05 7.93 78.98 8,317.45 8,172.91 641.70 3,001.48 2,428,771.66 316,714.32 0.55 3,069.29 MWD+SC+sag(3) 9,247.10 7.28 76.32 8,377.96 8,233.42 643.42 3,009.38 2,428,773.26 316,722.24 1.21 3,077.36 MWD+SC+sag(3) 9,309.62 6.83 75.15 8,440.01 8,295.47 645.31 3,016.82 2,428,775.03 316,729.71 0.76 3,085.04 MWD+SC+sag(3) 9,370.85 6.19 73.86 8,500.84 8,356.30 647.16 3,023.51 2,428,776.77 316,736.43 1.07 3,091.96 MWD+SC+sag(3) 9,433.18 5.73 74.80 8,562.84 8,418.30 648.91 3,029.74 2,428,778.43 316,742.69 0.75 3,098.42 MWD+SC+sag(3) 9,495.10 5.23 75.83 8,624.47 8,479.93 650.41 3,035.46 2,428,779.84 316,748.43 0.82 3,104.33 MWD+SC+sag(3) 9,556.86 4.75 71.82 8,686.00 8,541.46 651.90 3,040.62 2,428,781.24 316,753.61 0.96 3,109.68 MWD+SC+sag(3) 9,619.88 4.23 66.11 8,748.83 8,604.29 653.66 3,045.22 2,428,782.92 316,758.24 1.09 3,114.55 MWD+SC+sag(3) 9,681.89 3.83 64.09 8,810.68 8,666.14 655.49 3,049.18 2,428,784.69 316,762.23 0.68 3,118.79 MWD+SC+sag(3) 9,743.55 3.58 59.92 8,872.21 8,727.67 657.35 3,052.69 2,428,786.50 316,765.77 0.60 3,122.62 MWD+SC+sag(3) 9,761.85 3.44 60.02 8,890.48 8,745.94 657.91 3,053.66 2,428,787.05 316,766.75 0.77 3,123.68 MWD+SC+sag(3) 9,800.00 3.44 60.02 8,928.56 8,784.02 659.06 3,055.65 2,428,788.16 316,768.75 0.00 3,125.86 PROJECTED to TD Checked By: Cary Taylor ,,,,, :,,,�m -• Approved By: Date: 7/7/2014 5:09:56PM Page 7 COMPASS 5000.1 Build 70 BCU-07A 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 7 H WELLPATH: Rig: BCU-07A H DEPTHUNT: usft H SURVDATE: 6/30/2014 H H WELL INFORMATION H WELL EW MAP : 313703.08 H WELL NS MAP : 2428177.43 H DATUM ELEVN : 144.54 H VSECT ANGLE : 78.17 H VSECT NORTH : 0.00 H VSECT EAST : 0.00 H H SURVEY TYPE INFORMATION H 98.34 - 2335.00 BCU-7 (GYRO) : NS-GYRO-MS H 2336.00 - 2603.91 BCU-7A (MWD_INTERP AZI+SAG) : MWD_INTERP AZI+SAG H 2666.84 - 9761.85 BCU-7A RIG SURVEY : MWD+SC+SAG H H SURVEY LIST H MD INC AZI TVD NS EW 17.60 0.00 0.00 17.60 0.00 0.00 98.34 0.54 160.92 98.34 -0.36 0.12 198.34 0.56 149.88 198.33 -1.23 0. 52 298.34 0.42 155.12 298.33 -1.98 0.92 398.34 0.44 161.97 398.33 -2.68 1.20 498.34 0.27 153.94 498.33 -3.26 1.42 598.34 0.22 180.07 598.32 -3.66 1. 52 698.34 0.19 154.00 698.32 -4.00 1. 59 798.34 0.20 175.03 798.32 -4.32 1.68 898.34 0.09 169.66 898.32 -4. 58 1.71 998.34 0.10 118. 57 998.32 -4.69 1.80 1098.34 0.07 162.07 1098.32 -4.79 1.90 1198.34 0.06 359.43 1198.32 -4.80 1.92 1298.34 0.17 314.23 1298.32 -4.64 1.81 1398.34 0.06 30.12 1398.32 -4. 50 1.73 1498.34 0.18 33.95 1498.32 -4.32 1.84 1598.34 0.19 7.80 1598.32 -4.03 1.95 1698.34 0.16 31.40 1698.32 -3.74 2.05 1798.34 0.03 305.87 1798.32 -3.61 2.10 1898.34 0.15 58.69 1898.32 -3.52 2.19 1998.34 0.07 102.05 1998.32 -3.47 2.36 2098.34 0.09 25. 55 2098.32 -3.41 2.46 2198.34 0.09 102.20 2198.32 -3.36 2. 57 2298.34 0.03 171.68 2298.32 -3.40 2.65 2298.74 0.03 171.68 2298.72 -3.40 2.65 2336.00 0.03 108.26 2335.98 -3.41 2.66 2417.19 3.90 52.31 2417.11 -1.73 4.86 2479.72 5.72 53.45 2479.42 1.43 9.05 2542.72 7.56 54.05 2541.99 5.73 14.93 2603.91 9.35 54.41 2602. 51 10.99 22.23 2666.84 11.02 58.81 2664.45 17.08 31.53 2729.38 13.20 63.48 2725.60 23.36 43.04 2790.12 17.26 70.05 2784.19 29. 53 57.72 2853.31 17.73 75. 50 2844.47 35.14 75.85 2915.38 21.69 79.03 2902.89 39.69 96.27 2976.47 23.30 81.60 2959.33 43.61 119.30 3039.61 25.65 80.21 3016.79 47.76 145.13 3102.57 30.87 78.08 3072.23 53.41 174.38 3162.99 31.72 78.14 3123.86 59.88 205.09 Page 1 BCU-07A Definitive surveys 3226.93 33.31 78.16 3177.78 66.94 238.73 3288.27 36. 57 78.97 3228.05 73.89 273.16 3350.03 39.85 80.33 3276. 57 80.74 310.73 3410.47 38.97 80. 58 3323.27 87.10 348. 57 3472.80 39.47 81.05 3371. 56 93.39 387.48 3536.12 38.41 80.97 3420.81 99.61 426.79 3598.13 38.11 81. 51 3469. 50 105.46 464.74 3659.54 36.87 80.30 3518.23 111.36 501.64 3721.94 35.76 80.36 3568. 51 117. 57 538.07 3784.05 35.02 79.89 3619.14 123.73 573.51 3846.37 33.92 79.23 3670. 52 130.12 608.19 3908. 50 34.40 78.92 3721.93 136.73 642.45 3970.71 33.71 78.87 3773.47 143.44 676.63 4032.70 33.87 77.75 3824.99 150.43 710.39 4094.10 35.27 77.60 3875. 55 157.87 744.43 4156. 51 35.33 76.70 3926.48 165.89 779. 59 4219.31 35.47 77.36 3977.67 174.05 815.04 4280.48 34.71 76.57 4027.72 181.98 849.29 4343.12 34.89 77.01 4079.16 190.15 884.10 4405.32 35.03 78.24 4130.14 197.79 918.91 4467.68 34.67 78.56 4181.31 204.95 953.82 4528.89 34.20 78.05 4231.80 211.97 987.71 4590.10 35.47 79.33 4282.04 218.82 1021.99 4652.43 36.31 79.85 4332. 53 225.42 1057.93 4715. 58 35.65 80.27 4383.64 231.82 1094.47 4777.82 34.70 79.43 4434.51 238.14 1129.77 4840.19 35.13 80.34 4485.65 244.41 1164.91 4902.35 34.19 80.10 4536.78 250.41 1199.75 4964. 51 35.58 78.71 4587.77 256.95 1234.69 5026.95 35.12 78.58 4638.70 264.07 1270.11 5089.06 34.50 78.74 4689.70 271.04 1304.87 5151.32 34.78 78.78 4740.92 277.94 1339. 58 5213.44 35.05 77.68 4791.86 285.19 1374.39 5275.67 35.66 76.26 4842.61 293.31 1409.47 5337.79 35.24 75.85 4893.22 301.99 1444.43 5399.88 34.77 76.25 4944.08 310.58 1479.00 5462.12 35.29 77. 54 4995.04 318.68 1513.79 5524.35 34.93 77.76 5045.95 326.33 1548.76 5585.80 34.31 78.36 5096.52 333.56 1582.91 5647.80 35.38 77.90 5147.40 340.85 1617. 58 5710.21 35.24 78.31 5198.33 348.28 1652.88 5771.75 35.08 78.82 5248.64 355.31 1687.61 5833.88 34. 51 78.20 5299.66 362.37 1722.35 5895.85 34.81 80.29 5350.64 368.94 1756.97 5957.46 33.72 80.34 5401. 55 374.78 1791.17 6018.42 35.04 80.43 5451.86 380. 53 1825.11 6080.82 34.84 80.67 5503.02 386.40 1860.36 6143.62 34. 52 80.84 5554.66 392.14 1895.63 6205.38 35.83 80.39 5605.14 397.94 1930.73 6267. 55 35. 59 81.04 5655.62 403.80 1966.54 6329. 57 35.10 81.71 5706.21 409.18 2002.01 6392.06 34.79 82.03 5757.43 414.24 2037.44 6453.48 35.49 80.70 5807.66 419. 55 2072.39 6516.02 35.71 79.68 5858.51 425.75 2108.27 6577.92 35.41 80.31 5908.87 432.01 2143.72 6639. 53 35.37 77.70 5959.10 438.81 2178.73 6701.76 35.16 77.74 6009.91 446.45 2213.84 6762.94 34.68 78.25 6060.07 453.74 2248.10 6826.73 34.84 76.39 6112.48 461.72 2283. 57 6887.89 34.76 76.01 6162.70 470.05 2317.47 6948.33 34.40 75.81 6212.46 478.40 2350.74 7011.53 33.92 76.50 6264.76 486.89 2385.20 7074.28 33.47 76.49 6316.97 495.02 2419.05 Page 2 BCU-07A Definitive surveys 7136.25 33.09 76.42 6368.77 502.99 2452.11 7198.89 32.63 75.74 6421.39 511.16 2485.10 7261.24 31.83 75. 55 6474.13 519.40 2517.31 7323.60 31.48 75.75 6527.22 527. 52 2549.02 7384.35 30.28 76.31 6579.35 535.05 2579.27 7447.01 27.25 76.19 6634.28 542.21 2608. 56 7508.87 25.44 76.63 6689.71 548.66 2635.24 7571.05 24.62 76.54 6746.05 554.77 2660.83 7633.32 23.45 76.47 6802.92 560.68 2685.49 7695.77 21.32 76.96 6860.66 566.15 2708.63 7756.28 19.44 76.67 6917.38 570.96 2729.15 7819.20 16.86 76.48 6977.16 575. 51 2748.21 7880.70 15.09 75.29 7036.29 579.62 2764.63 7942.13 14. 50 74.92 7095.68 583.65 2779.79 8005.58 13.94 74.60 7157.18 587.75 2794.83 8067.55 13.67 76.16 7217.36 591.49 2809.13 8128.64 13.38 76. 58 7276.76 594.85 2823.02 8191.27 13.24 76.12 7337.71 598.25 2837.03 8253.33 12.59 77.09 7398.20 601.47 2850. 52 8316.12 12.46 76.95 7459.49 604. 53 2863.79 8378.04 11. 51 76.59 7520.06 607.47 2876.31 8440.28 10.83 74.84 7581.12 610.44 2887.99 8501.90 10. 54 74.44 7641.68 613.47 2899.01 8560.91 10.20 73.06 7699.72 616.44 2909.21 8626.20 9.79 73.67 7764.02 619.68 2920.06 8688.48 9.49 72.45 7825.42 622.72 2930.04 8750.41 9.22 73.64 7886. 53 625.65 2939.67 8812.49 8. 55 73. 50 7947.86 628.37 2948.87 8874.98 8.25 71.83 8009.68 631.08 2957. 58 8937.43 8. 51 74.81 8071.47 633.69 2966.30 8999.80 8. 58 76.87 8133.14 635.96 2975.28 9058.92 8.36 77.04 8191.62 637.92 2983.76 9123.88 8.24 77.96 8255.90 639.95 2992.92 9186.05 7.93 78.98 8317.45 641.70 3001.48 9247.10 7.28 76.32 8377.96 643.42 3009.38 9309.62 6.83 75.15 8440.01 645.31 3016.82 9370.85 6.19 73.86 8500.84 647.16 3023. 51 9433.18 5.73 74.80 8562.84 648.91 3029.74 9495.10 5.23 75.83 8624.47 650.41 3035.46 9556.86 4.75 71.82 8686.00 651.90 3040.62 9619.88 4.23 66.11 8748.83 653.66 3045.22 9681.89 3.83 64.09 8810.68 655.49 3049.18 9743. 55 3.58 59.92 8872.21 657.35 3052.69 9761.85 3.44 60.02 8890.48 657.91 3053.66 9800.00 3.44 60.02 8928. 56 659.06 3055.65 Page 3 Well:BCU-07A ad Cony -0.904658 Date:14-Ju1-14 HALLIBURTON • DDI:5.627 144.54 R V.S.Plane:78.17° Unwrapped Disphcem .79 Sperry Drilling Bprvte„ MD Inc Atimrfh TVDSS TVD local Coordinates Map Coordinates DIS Vertical SV)/N (°/100 Section Comments (soft) () (°) (usft) (usft) N/S E/W Fasting Northing usft) (usft) 1 17.60 0.00 0.00 -126.94 17.60 0.00 N 0.00 E 313703.08 E 2428177.43 N 0.00 0.00 2 98.34 0.54 160.92 -46.20 98.34 -0.36 S 0.12 E 313703.20 E 2428177.07 N 0.67 0.05 3 198.34 0.56 149.88 53.79 198.33 -1.23 S 0.52 E 313703.59 E 2428176.19 N 0.11 0.26 4 298.34 0.42 155.12 153.79 298.33 -1.98 S 0.92 E 313703.97 E 2428175.43 N 0.15 0.50 5 398.34 0.44 161.97 253.79 398.33 -2.68 S 1.20 E 313704.24 E 2428174.73 N 0.06 0.62 6 498.34 0.27 153.94 353.79 498.33 -3.26 S 1.42 E 313704.45 E 2428174.15 N 0.18 0.72 7 598.34 0.22 180.07 453.78 598.32 -3.66 S 1.52 E 313704.55 E 2428173.75 N 0.12 0.74 8 698.34 0.19 154.00 553.78 698.32 -4.00 S 1.59 E 313704.61 E 2428173.40 N 0.10 0.74 9 798.34 0.20 175.03 653.78 798.32 -4.32 S 1.68 E 313704.70 E 2428173.08 N 0.07 0.76 10 898.34 0.09 169.66 753.78 898.32 -4.58 S 1.71 E 313704.72 E 2428172.83 N 0.11 0.74 lI 998.34 0.10 118.57 853.78 998.32 -4.69 S 1.80 E 313704.81 E 2428172.71 N 0.08 0.80 12 1098.34 0.07 162.07 953.78 1098.32 -4.79 S 1.90 E 313704.90 E 2428172.61 N 0.07 0.87 13 1198.34 0.06 359.43 1053.78 1198.32 -4.80 S 1.92 E 313704.92 E 2428172.60 N 0.13 0.89 14 1298.34 0.17 314.23 1153.78 1298.32 -4.64 S 1.81 E 313704.82 E 2428172.76 N 0.13 0.82 IS 1398.34 0.06 30.12 1253.78 1398.32 -4.50 S 1.73 E 313704.74 E 2428172.91 N 0.17 0.77 16 1498.34 0.18 33.95 1353.78 1498.32 -4.32 S 1.84 E 313704.86 E 2428173.08 N 0.12 0.92 17 1598.34 0.19 7.80 1453.78 1598.32 -4.03 S 1.95 E 313704.97 E 2428173.37 N 0.08 1.09 18 1698.34 0.16 31.40 1553.78 1698.32 -3.74 S 2.05 E 313705.07 E 2428173.66 N 0.08 1.24 19 1798.34 0.03 305.87 1653.78 1798.32 -3.61 S 2.10 E 313705.12 E 2428173.79 N 0.16 1.32 20 1898.34 0.15 58.69 1753.78 1898.32 -3.52 S 2.19 E 313705.22 E 2428173.87 N 0.16 1.42 21 1998.34 0.07 102.05 1853.78 1998.32 -3.47 S 2.36 E 313705.39 E 2428173.92 N 0.11 1.60 22 2098.34 0.09 25.55 1953.78 2098.32 -3.41 S 2.46 E 313705.48 E 2428173.98 N 0.10 1.70 23 2198.34 0.09 102.20 2053.78 2198.32 -3.36 S 2.57 E 313705.59 E 2428174.03 N 0.11 1.82 24 2298.34 0.031 171.68 2153.78 2298.32 -3.40 S 2.65 E 313705.67 E 2428173.99 N 0.08 1.89 - 25 2298.74 0.03 171.68 2154.18 2298.72 -3.40 S 2.65 E 313705.67 E 2428173.99 N 0.00 1.89 26 2336.00 0.03 108.26 2191.44 2335.98 -3.41 S 2.66 E 313705.68 E 2428173.98 N 0.08 1.90 27 2417.19 3.90 52.31 2272.57 2417.11 -1.73 S4.86 E 313707.92 E 2428175.62 N 4.78 4.41 28 2479.72' 5.72 53.45 2334.88 2479.42 1.43 N 9.05 E 313712.15 E 2428178.71 N 2.91 9.15 29 2542.72 7.56 54.05 2397.45 2541.99 5.73 N 14.93 E 313718.10 E 2428182.92 N 2.92 15.78 30 2603.91 9.35 54.41 2457.97 2602.51 10.99 N 22.23 E 313725.48 E 2428188.06 N 2.93 24.01 31 2666.84 11.02 58.81 2519.91 2664.45 17.08 N 31.53 E 313734.88 E 2428194.01 N 2.93 34.36 32 2729.38 13.20 63.48 2581.06 2725.60 23.36 N 43.04 E 313746.48 E 2428200.11 N 3.82 46.91 33 2790.12 17.26 70.05 2639.65 2784.1929.53 N 57.72 E 313761.26 E 2428206.05 N 7.25 62.55 34 2853.31 17.73 75.50 2699.93 2844.47 35.14 N 75.85 E 313779.47 E 2428211.37 N 2.70 81.44 35 2915.38 21.69 79.03 2758.35 2902.89 39.69 N 96.27 E 313799.96 E 2428215.60 N 6.66 102.36 36 2976.47 23.30 81.60 2814.79 2959.33 _43.61 N 119.30 E 313823.06E 2428219.15 N _3.09 125.71 37 3039.61 25.65 80.21 2872.25 3016.79 47.76 N 145.13 E 313848.95 E 2428222.89 N 3.83 151.83 38 3102.57 30.87 78.08 2927.69 3072.23 53.41 N 174.38 E 313878.28 E 2428228.08 N 8.44 181.63 39 3162.99 31.72 78.14 2979.32 3123.86 59.88 N 205.09 E 313909.09 E 2428234.06 N 1.41 213.01 40 3226.93 33.31 78.16 3033.24 3177.78 66.94 N 238.73 E 313942.84 E 2428240.59 N 2.49 247.38 41 3288.27 36.57 78.97 3083.51 3228.05 73.89 N 273.16 E 313977.37 E 2428247.00 N 5.37 282.50 42 3350.03 39.85 80.33 3132.03 3276.57 80.74 N 310.73 E 314015.05 E 2428253.25 N 5.48, 320.68 43 3410.47 38.97 80.38 3178.73 3323.27 87.10 N 348.57 E 314052.99 E 2428259.01 N 1.48 359.02 44 3472.80 39.47 r 81.05 3227.02 3371.56 93.39 N 387.48 E 314091.99 E 2428264.69 N 0.93 398.39 45 3536.12 38.41 80.97 3276.27 3420.81 99.61 N 426.79 E 314131.39E 2428270.29 N 1.68 438.14 46 3598.13 38.11 81.51 3324.96 3469.50 105.46 N 464.74 E 314169.42 E 2428275.54 N 0.72 476.48 47 3659.54 36.87 80.30 3373.69 3518.23 111.36 N 501.64 E 314206.42 E 2428280.85 N 2.35 513.81 48 3721.94 35.76 80.36 3423.97 3568.51 117.57 N. 538.07 E 314242.94 E2428286_49 N 1.78 550.74 49 3784.05 35.02 79.89 3474.60 3619.14 123.73 N 573.51 E 314278.47 E 2428292.09-14 1.27 586.69 50 3846.37 33.92 79.23 3525.98 3670.52 130.12 N 608.19 E 314313.25 E 2428297.93 N 1.86 621.95 513908.50 34.40 78.92 3577.39 3721.93 136.73 N 642.45 E 314347.61 E 2428304.00N 0.82 656.83 --- 52 3970.71 33.71 78.87 3628.93 3773.47 143.44 N 676.63E 314381.89 F 2428310.17 N 1.11 691.67 53 4032.70 33.87 77.75 3680.45 3824.99 150.43 N 710.39 E 314415.76 E 2428316.62 N 1.04 726.14 54 4094.10 35.27 77.60 3731.01 3875.55 157.87 N 744.43 E 314449.91 E 2428323.52 N 2.28 760.98 55 4156.51 35.33 76.70 3781.94 3926.48 165.89 N 779.59 E 314485.19 E 2428330.99 N 0.84 797.04 56 4219.31 35.47 77.36 3833.13 3977.67 174.05 N 815.04 E 314520.76 E 2428338.59 N 0.65 833.41 57 4280.48 34.71 76.57 3883.18 4027.72 181.98 N 849.29 E 314555.14 E 2428345.98 N 1.45 868.56 58 4343.12 34.89 77.01 3934.62 4079.16 190.15 N 884.10 E 314590.07 E 2428353.60 N 0.49 904.30 59 4405.32 35.03 78.24 3985.60 4130.14 197.79 N 918.91 E 314625.00 E 2428360.68 N 1.16 939.94 60 4467.68 34.67 78.56 4036.77 4181.31 204.95 N 953.82 E 314660.01 E 2428367.30 N 0.65 97537 61 4528.89 34.20 78.05 4087.26 4231.80 211.97 N 987.71 E 314694.01 E 2428373.78 N 0.90 1010.19 62 4590.10 35.47 79.33 4137.50 4282.04 218.82 N 1021.99 E 314728.40 E 2428380.08 N 2.39 1045.15 63 4652.43 36.31 79.85 4187.99 4332.53 225.42 N 1057.93 E 314764.44 E 2428386.12 N 1.43 1081.67 64 4715.58 35.65 80.27 4239.10 4383.64 231.82 N 1094.47 E 314801.08 E 2428391.94 N 1.12 1118.75 65 4777.82 34.70 79.43 4289.97 4434.51 238.14 N 1129.77 E 314836.47 E 2428397.70 N 1.71 1154.59 66 4840.19 35.13 80.34 4341.11 4485.65 244.41 N 1164.91 E 314871.71 E 2428403.41 N 1.08 1190.27 67 4902.35 34.19 80.10 4392.24 4536.78 250.41 N 1199.75 E 314906.63 E 2428408.87 N 1.53 1225.60 68 4964.51 35.58 78.71 4443.23 4587.77 256.95 N 1234.69 E 314941.67 E 2428414.86 N 2.58 1261.14 69 5026.95 35.12 78.58 4494.16 4638.70 264.07 N 1270.11 E 314977.20 E 2428421.41 N 0.75 1297.27 70 5089.06 34.50 78.74 4545.16 4689.70 271.04 N 1304.87 E 315012.07 E 2428427.83 N 1.01 1332.72 71 5151.32 34.78 78.78 4596.38 4740.92 277.94 N 1339.58 E 315046.88 E 2428434.18 N 0.45 1368.11 72 5213.44 35.05 77.68 4647.32 4791.86 285.19 N 1374.39 E 315081.80 E 2428440.89 N 1.10 1403.66 73 5275.67 35.66 76.26 4698.07 4842.6! 293.31 N 1409.47 E 315117.00 E 2428448.45 N 1.64 1439.66 74 5337.79 35.24 75.85 4748.68 4893.22 301.99 N 1444.43 E 315152.10 E 2428456.58 N 0.78 1475.66 75 5399.88 34.77 76.25 4799.54 4944.08 310.58 N 1479.00 E 315186.80 E 2428464.62 N 0.84 1511.26 76 5462.12 35.29 7734 4850.50 4995.04 318.68 N 1513.79 E 315221.72 E 2428472.17 N 1.45 1546.97 77 5524.35 34.93 77.76 4901.41 5045.95 326.33 N 1548.76 E 315256.80 E 2428479.27 N 0.61 1582.76 78 5585.80 34.31 78.36 4951.98 5096.52 33336 N 1582.91 E 315291.06 E 2428485.95 N 1.15 1617.67 79 5647.80 35.38.,;:.;77.90 5002.86 5147.40 340.85 N 1617.58 E 315325.84 E 2428492.69 N 1.78 1653.10 80 5710.21 35.24 78.31 5053.79 5198.33 348.28 N 1652.88 E 315361.25 E 2428499.57 N 0.44 1689.17 Page 1 of 2 MD Inc Azimuth TVDSS T Local Coordinates Map Coordinates DIS heal • SVY# (usft (°/l0t cion Comments (°) (°) (usft) (ie N/S E/W Fasting Northing usft) lush) 81 5771.75 35.08 78.82 5104.10 5248.64 355.31 N 1687.61 E 315396.09 E 2428506.05 N 0.54 1724.61 82 5833.88 34.51 78.20 5155.12 5299.66 362.37 N 1722.35 E 315430.94 E 2428512.56 N 1.08 1760.06 83 5895.85 34.81 80.29 5206.10 5350.64 368.94 N 1756.97 E 315465.66 E 2428518.59 N 1.98 1795.29 845957.46 33.72 80.34 5257.01 5401.55 374.78 N 1791.17 E315499.94 E 2428523.88 N 1.77 1829.96 85 6018.42 35.04 80.43 5307.32 5451.86 380.53 N 1825.11 E 315533.97 E 2428529.09 N 2.17 1864.35 86 6080.82 34.84 80.67 5358.48 5503.02 386.40 N 1860.36 E 315569.31 E 2428534.40 N 0.39 1900.06 87 6143.62 34.52 80.84 5410.12 5554.66 392.14 N 1895.63 E 315604.66 E -2428539.59 N 0.53 1935.76 88 6205.38 35.83' 80.39 5460.60 5605.14 397.94 N 1930.73 E 315639.85 E 2428544.84 N 2.16 1971.30 89 6267.55 35.59 81.04 5511.08 5655.62 403.80 N 1966.54 E 315675.75 E 2428550.13 N 0.72 2007.55 90 6329.57 35.10 81.71 5561.67 5706.21 409.18 N 2002.01 E 315711.30 E 2428554.95 N 1.01 2043.37 91 6392.06 34.79 82.03 5612.89 5757.43 414.24 N 2037.44 E 315746.81 E 2428559.45 N 0.58 2079.09 92 6453.48 35.49 80.70 5663.12 5807.66 419.55 N 2072.39 E 315781.84 E 2428564.21 N 1.69 2114.39 93 6516.02 35.71 79.68 5713.97 5858.51 425.75 N 2108.27 E 315817.81 E 2428569.84 N 1.01 2150.77 94 6577.92 35.41 80.31 5764.33 5908.87 432.01 N 2143.72 E 315853.35 E 2428575.54 N 0.76 2186.75 95 6639.53 35.37 77.70 5814.56 5959.10 438.81 N 2178.73E 315888.47 E 2428581.79 N 2.45 2222.42 96 6701.76 35.16 77.74 5865.37 6009.91 446.45 N 2213.84 E 315923.70 E 2428588.87 N 0.34 2258.35 97 6762.94 34.68 78.25 5915.53 6060.07 453.74 N 2248.10 E 315958.06 E 2428595.62 N 0.92 2293.37 98 6826.73 34.84 76.39 5967.94 6112.48 461.72 N 2283.57 E 315993.66 E 2428603.04 N 1.68 2329.73 99 6887.89 34.76 76.01 6018.16 6162.70 470.05 N 2317.47 E 316027.69 E 2428610.83 N 0.38 2364.61 100 6948.33 34.40 75.81 6067.92 6212.46 478.40 N 2350.74 E 316061.08 E 2428618.65 N 0.62 2398.89 101 7011.53 33.92 76.50 6120.22 6264.76 486.89 N 2385.20 E 316095.67 E 2428626.60 N 0.98 2434.35 102 7074.28 33.47 76.49 6172.43 6316.97 495.02 N 2419.05 E 316129.64 E 2428634.20 N 0.72 2469.15 103 7136.25 33.09 76.42 6224.23 6368.77 502.99 N 2452.11 E 316162.82 E 2428641.64 N 0.62 2503.14 104 7198.89 32.63 75.74 6276.85 6421.39 511.16 N 2485.10 E 316195.94 E 2428649.29 N 0.94 2537.11 108 7261.24 31.83 75.55 6329.59 6474.13 519.40 N 2517.31 E 316228.28 E 2428657.02 N 1.29 2570.33 106 7323.60 31.48 75.75 6382.68 6527.22 527.52 N 2549.02 E 316260.11 E 2428664.63 N 0.59 2603.02 107 7384.35 30.28 76.31 6434.81 6579.35 535.05 N 2579.27 E 316290.48 E 2428671.68 N 2.03 2634.18 108 7447.01 27.25 76.19 6489.74 6634.28 542.21 N 2608.56 E 316319.87 E2428678.39 N 4.84 2664.31 109 7508.87 25.44 76.63 6545.17 6689.71 548.66 N 2635.24 E 316346.65 E 2428684.42 N 2.94 2691.75 110 7571.05 24.62 76.54 6601.51 6746.05 554.77 N 2660.83 E 316372.34 E 2428690.12 N 1.32 2718.04 I I 1 7633.32 23.45 76.47 6658.38 6802.92 560.68 N 2685.49 E 316397.09 E 2428695.64 N 1.88 2743.40 112 7695.77 21.32 76.96 6716.12 6860.66 566.15 N 2708.63E 316420.32 E 2428700.75 N 3.42 2767.17--- -_- 113 7756.28 19.44 76.67 6772.84 6917.38 570.96 N 2729.15 E 316440.91 E 2428705.23 N 3.11 2788.23 114 7819.20 16.86` 76.48 6832.62 6977.16 575.51 N 2748.21 E 316460.04 E 2428709.47 N 4.10 2807.83 115 7880.70 15.09 75.29 6891.75 7036.29 579.62 N 2764.63 E 316476.52 E 2428713.33 N 2.93 2824.74 116 7942.13 14.50 74.92 6951.14, 7095.68 583.65 N 2779.79 E 316491.74 E 2428717.12 N 0.97 2840.40 117 8005.58 13.94 74.60 7012.64 7157.18 587.75 N 2794.83 E 316506.84 E 2428720.98 N0.89 2855.96 118 8067.55 13.67 76.16 7072.82 7217.36 591.49 N 2809.13 E 316521.20 E 2428724.49 N 0.74 2870.73 119 8128.64 13.38 76.58 7132.22 7276.76 594.85 N 2823.02 E 316535.14 E 2428727.64 N 0.50 2885.01 120 8191.27 13.24 76.12 7193.17 7337.71 598.25 N 2837.03 E 316549.20 E 2428730.82 N 0.28 2899.42 121 8253.33" 1.2.59 77.09 7253.66 7398.20 601.47 N 2850.52 E 316562.74 E 2428733.82 N 1.10 2913.28 122 8316.12 12.46 76.95 7314.95 7459.49 604.53 N 2863.79 E 316576.06 E 2428736.67 N 0.21 2926.90 123 8378.04 11.51 76.59 7375.52 7520.06 607.47 N 2876.31 E 316588.62 E 2428739.41 N 1.54 2939.75 -- 124 8440.28 10.83 74.84 7436.58 7581.121 610.44 N 2887.99 E 316600.35 E 2428742.20 N 1.22 2951.80 125 8501.90 10.54 74.44 7497.14 7641.68 613.47 N 2899.01 E 316611.41 E 2428745.05 N 0.49 2963.20 126 8560.91 10.20 73.06 7555.18 7699.72 616.44 N 2909.21 E 316621.66 E 2428747 86 N 0.71 2973.79 127 8626.20 9.79 73.67 7619.48 7764.02 619.68 N 2920.06 E 316632.56 E 2428750.93 N 0.65 2985.08 128 8688.48 9.49 72.45 7680.88 7825.42 622.72 N 2930.04 E 316642.59 E 2428753.81 N 0.58 2995.47 129 8750.41 9.22 73.64 7741.99 7886.53 625.65 N 2939.67 E 316652.26 E 2428756.59 N 0.54 3005.49 130 8812.49 8.55 73.50 7803.32 7947.86 628.37 N 2948.87 E 316661.50 E 2428759.16 N 1.08 3015.05 131 8874.98 8.25 71.83 7865.14 8009.68 631.08 N 2957.58 E 316670.26 E 2428761.74 N 0.62 3024.14 132 8937.43 8.51 74.81 7926.93 8071.47 633.69 N 2966.30 E 316679.01 E 2428764.21 N 0.81 3033.20 133 8999.80 8.58 76.87 7988.60 8133.14 635.96 N 2975.28 E 316688.03 E 2428766.33 N 0.50 3042.46 134 9058.92 8.36 77.04 8047.08 8191.62 637.92 N 2983.76E 316696.54 E 2428768.16 N 0.37 3051.17 135 9123.88 8.24 77.96 8111.36 8255.90 639.95 N 2992.92E 316705.73 E 2428770.05 N 0.28 3060.54 136 9186.05 7.93 78.98 8172.91 8317.45 641.70 N 3001.48 E 316714.32 E 2428771.66 N 0.55 3069.29 137 9247.10 7.28 76.32 8233.42 8377.96 643.42 N 3009.38 E 316722.24 E 2428773.26 N 1.21 3077.36 138 9309.62 6.83 75.15 8295.47 8440.01 645.31 N 3016.82 E 316729 71 E 2428775.03 N 0.76 3085.04 139 9370.85 6.19 73.86 8356.30 8500.84 647.16 N 3023.51 E 316736.43 E 2428776.77 N 1.07 3091.96 140 9433.18 5.73 74.80 8418.30 8562.84 648.91 N 3029.74 E 316742.69 E 2428778.43 N 0.75 3098.42 141 9495.10 5.2375.83 8479.93 8624.47 650.41 N 3035.46 E 316748.43 E 2428779.84 N 0.82 3104.33 ....----------------------------._ -- --- v 142 9556.86 4.75 71.82 8541.46 8686.00 651.90 N 3040.62 E 316753.61 E 2428781.24 N 0.96 3109.68 143 9619.88 4.23 66.11 8604.29 8748.83 653.66 N 3045.22 E 316758.24 E 2428782.92 N 1.09 3114.55 144 9681.89 3.83 64.09 8666.14 8810.68 655.49 N 3049.18 E 316762.23 E 2428784.69 N 0.68 3118.79 ,---------- 145 9743.55 3.58 59.92 8727.67 8872.21 657.35 N 3052.69 E 316765 77 E 2428786.50 N 0.60 3122.62 146 9761.85 3.44 60.02 8745.94 8890.48 657.91 N 3053.66 E 316766.75 E 2428787.05 N 0.77 3123.68 147 9800.00 3.44 60.02 8784.02 8928.56 659.06 N 3055.65 E 316768.75 E 2428788.16 N 0.00 3125.86 Page 2 of 2 Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. BCU-7A Date 22-Jun-14 County Kenai Peninsula Burough State Alaska Supv. Rance Pederson/Jimmy Greco CASING RECORD TD 9800.00 Shoe Depth: 9766.60 PBTD: 9682.03 Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 5.5" DWC/C H" WFD 1.54 9,766.58 9,765.04 2 _ 5.5" 17# P110 DWC/C H" 81.97 9,725.50 9,683.07 Float 5.5" DWC/C H- WFD 1.04 9,683.07 9,682.03 71 JTS&6 PUP 5.5" 17# P110 DWC/C H- 7,792.25 9,682.03 1,868.73 Swell PKR 5.5"x 8" 17# P110 DWC/C H" Baker 21.05 1,889.78 1,868.73 41 jts 5.5" 17# P110 DWC/C H" 1,847.08 1,868.73 21.65 Pup 5.5" 17# P110 DWC/C H- 3.30 21.65 18.35 Hanger 5.5"X 11" DWC/C H1 ACME 0.85 18.35 17.50 RKB 17.50 17.50 0.00 Totals Csg Wt.On Hook: 162,950 Type Float Collar: Float No.Hrs to Run: 27 Csg Wt.On Slips: N/A Type of Shoe: Bull Nose Casing Crew: WFD Fluid Description: 9.4 ppg /6%KCUPHPA Mud/PV=14 YP=21 HTHP=12.9 Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: 1 every otherjt F/TD T/9000',1 every jt F/9000 T/5000',1 every otherjt F/5000 T/surface(Ran 145 total CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 10.5 Volume pumped(BBLs) 35 BBLS Lead Slurry Type: Lite Crete Lead Cement Density(ppg) 11.5 Volume pumped(BBLs) 245.5 Mixing/Pumping Rate(bpm): 4.1 Tail Slurry Type: Class G Gasblok Density(ppg) 15.3 Volume pumped(BBLs) 100 Mixing/Pumping Rate(bpm): 4.3 N Post Flush(Spacer) w Type: Density(ppg) Rate(bpm): Volume: 0 LL Displacement: Type: Water Density(ppg) 8.34 Rate(bpm): 5 Volume(actual/calculated): 227/225.6 FCP(psi): 2300psi Pump used for disp: Schlumberger Plug Bumped? _Yes X No Bump press Casing Rotated? Yes X No Reciprocated? Yes X No %Retums during job 100% Cement returns to surface? Yes X No Spacer returns? X Yes No Vol to Surf: 20 bbls Cement In Place At: 23:44 Date: 6/22/2014 Estimated TOC: 336 Method Used To Determine TOC: Calculated volumes 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): N Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: w Displacement: co Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? _Yes No Bump press Casing Rotated? Yes _No Reciprocated? _Yes_No %Returns during job Cement returns to surface? Yes_No Spacer returns? Yes_No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: WELLHEAD Make Cactus Wellhead Type CTH-P(temporary) Serial No. Size 13 5/8" W.P. 5000 Test Head To 3000 PSIG 30 MIN Yes OK Remarks: Tested casing and temporary tree cap at 3000 psi for 30 minutes.Good test. BCU 7A Days Vs Depth 0 BCU 7A ACTUAL BCU 7A Plan 2000 4000 r a v 6000 ro C1) 2 8000 10000 12000 0 5 10 15 20 25 30 Days • BCU 7A MW Vs Depth 0 500 1000 - 1500 - 2000 - 2500 1 = 3000 3500 4000 — 4500 MW vs Depth 5000 — BCU 7A Plan -C cu 5500 -o 2 6000 co co ( 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 ----- — 11500 — — — 8 9 10 11 12 13 14 Mud Density(ppg) 2k -1CGO L .a Oudean Hilcorp Alaska, L. GeoTech II 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 il.I ig-i, tla 4.,.i.i i Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 10/1/14 To: Alaska Oil & Gas Conservation Commission RECEIVED Makana Bender Natural Resource Technician OCT 0 1 201 333 W 7th Ave Ste 100 4 Anchorage, AK 99501AOGCC DATA TRANSMITTAL BCU 7A Mudlog data Prints: 5" Formation Log MD 5" Formation Log TVD Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMM- _.ON GAS WELL OPEN FLOW POTENTIAL TEST REPORT 1a.Test: U Initial U Annual U Special lb.Type Test: U Stabilized U Non Stabilized U Multipoint ❑Constant Time ❑ Isochronal ❑Other: 2.Operator Name: 5.Date Completed 11.Permit to Drill Number: Hilcorp Alaska,LLC 8/8/2014 214-060 3.Address: 6.Date TD Reached: 12.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 6/19/2014 50- 133-20284-01 4a.Location of Well(Governmental Section): 7.KB Elevation above MSL(feet): 13.Well Name and Number: Surface: 1783'FNL,2033'FEL,Sec 4,T6N,R1OW,SM,AK 141 Beaver Creek Unit(BCU)07A . Top of Productive Horizon: 8.Plug Back Depth(MD+TVD): 14.Field/Pool(s): 1172'FNL,893'FWL,Sec 3,T6N,R1 OW,SM,AK 9,110'MD/8,242'ND Total Depth: 9 Total Depth(MD+ND): Beaver Creek/Beluga Gas Pool 1133'FNL, 1029'FWL,Sec 3,T6N,R1 OW,SM,AK 9,682'MD/8,811'ND 4b.Location of Well(State Base Plane Coordinates NAD 27) 10.Land Use Permit: 15 Property Designation: Surface: x- 313703 081 y-2428177.429 Zone- 4 N/A A028118 TPI: x- 316632.56 y-2428750.93 Zone- 4 16.Type of Completion(Describe): Total Depth: x- 316768.75 y-2428788.16 Zone- 4 ' 5-1/2"Production String,Perforated 17.Casing Size Weight per foot,lb. I.D.in inches Set at ft. 19.Perforations: From To 5-1/2" 17 4.892" 9,767' 8,610'-8,620' 18.Tubing Size Weight per foot,lb. I.D.in inches Set at ft. 8,706-8,728' N/A 8,770'-8,780' 8,820'-8,830' 9,046-9,060' 20.Packer set at ft: 21.GOR cf/bbl: 22.API Liquid Hydrocardbons: 23.Specific Gravity Flowing Fluid(G): N/A 0 N/A 0.56 24a.Producing through: 24b.Reservoir Temp: 24c.Reservoir Pressure: 24d.Barometric Pressure(Pa): ❑Tubing 2 Casing 130 F° 3,079 psia @ Datum 7,606 TVDSS psia 25.Length of Flow Channel(L): Vertical Depth(H): Gg: %CO2: %N2: %H2S: Prover: Meter Run: Taps: N/A N/A 0.56 0 0 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice Size(in.) Size(in.) psig Hw F° psig F° psig F° Hr. 1. X 2,503 60 2,593 60 4 2. X 2,391 60 2,391 60 4 3. X 2,300 60 2,300 _ 60 4 4. X 2,157 60 2,157 60 4 5. X Basic Coefficient Flow Temp. Super Comp. No (24-Hour) h� Factor Pressure Factor Gravity Factor Rate of Flow Fb or Fp Pm Ft Fg O Fpvj�Mcfd��* D 2. 3. . - SEP 1 2 2014 4. _ 5. AOGCC Temperature for Separator for Flowing No. PrT Tr z Gas Fluid Gg G 1. 520 0.56 2. 520 0.56 i 3. 520 Critical Pressure 0.56 4. - 520 Critical Temperature - 0.56 5. Fnrm 111_,491 Rau 7/9nno C(IAITIAIi IFr' (lii PM/FRCP CIIIF __ C.,hmif in fl,nlinefa NA Pc 2,573 pct 6,618,78t 3,094 pf2 9,570,981 No. Pt Pte Pc2-Pt2 Pw Pw2 Pc2-Pw2 Ps Ps2 Pf-Ps2 1. 2,518 6,338,813 3- ,025 9,148,180 422,170 2. 2,406 5,787,392 2- ,891 8,356,146 1,214,833 3. 2,315 5,357,836 2,782 7,737,855 1,833,125 4. 2,172 4,716,281 2,609 6,805,316 2,765,664 5. 25. AOF (Mcfd) 3,278 n 0.44 Remarks: I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Reservoir Engineer Date '9//a-// 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= -17/2—dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas (air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet(TVD) L Length of flow channel, feet(MD) n Exponent(slope)of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back-Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 7/2009 Side 2 (" C _ N 0 N N L$) In CO < v _ S 73 CO (O C) I- I". U) `4- N N N N N ti II O L> M M M co- M (V NO LL `4 2 < hi Ccr)) _ Q Q co cr, 3 uO b0. . Q i O r LL� 0 co co O : O II o c rn n a v v � � 0 � s n N C 0000 II II I- 0 M CD LL > O >. Q Q N CO C) N CI_ oM � � ai G 1 N O N CO C) ° e, a `I d V NCO O LL l� � � N ') p < O) Q w V IN y o o N CO II CO oe0000 m 3 z O O N ''.0 r .N ) I I co D oc•icos- � n M 0 , I l7 N N Li. MI N3 ca cu J 4 o a v v v v v Q . � rnrnrnrnrn 00000 m V 3 co m 2 r • A C) 0_ 04 .CCI 0 V) O II CO 0. a t` _ W N _ d m CL CO N O) CO O LL (O I O O CO t` O o C) M N N N c C O O O p pp '-I o O O S O� m O o ti 0.co CO (O Lt, N '-1 C--- %-. 0 r ri LO LO v CO (ZvSd-ZvJd) 2 N N N N N LL I-- V co N V O N V 13 N ''N O N O 10 - (y N II II II CO N ,- CO D r•-- U 0 N < N N S- V L L co M II N t` Q) O) C d CO M C) O) .. N p O CO Y O N O) O) n _p N Q 3 0 .-• O CO co M d < II co F,1 (-c' .<.- )6 V 7) a 3 u_ . N O L- am 0 _O 00 II' `. N. d I•- N 1 Q O) d II 0 > N N N RCO••••• 00 - fro CO �O `O II '<'- O M J m Li 00 m , >,a a Q 0 c v m a- 0 0 w W N U '- ti E 2 ¢ (i ,n Ellison G HiIcorp Alaska, LL. � / f eoTeCh 3800 Centerpoint Drive, Suite 10 0 Anchorage, AK 99503 Tele: 907 777-8339 v Niirnrp:itlawka-Ulf Fax: 907 777 8510 E-mail: lellison@hilcorp.com DATE 08/22/2014 To: Alaska Oil & Gas Conservation Commission 0,4 $6 GulhANk 333 W 7th Ave Ste 100 • 14Atte Anchorage, AK �'f N • 99501 DATA TRANSMITTA Transmitted herewith are cuttings from BCU 7A WELL SAMPLE INTERVAL BCU 7A 2370'-3900' BCU 7A 3900'-5610' BCU 7A 5610'-7200' BCU 7A 7200'-8610' BCU 7A 8610'-9800' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this tra r 777.8510 Received By: Date: AUG 2 2 2014 Angela K. Singh AOGCC Z 4-060 11 Lai. .n Ellison Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 DATA LOGGED Tele: 907 777-8339 it/a/2014 Itilencp U;EAka_1,TA, Fax: 907 777-8510 M.K.BENDER �'� +►�, E-mail: lellison@hilcorp.com RECE AuG 12 ZO\4 C DATE 08/11/14QGC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 7 A 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 CD 1: Final Well Data 2. ,61 14 y Name Date modified Type CGM 7,9/20149:29 AM File folder DLIS+LAS 7;9120149:29AM File folder EMF 7/9/2014 9:29 AM File folder PDF 7/9/2014 9:29 AM File folder TIFF 7/9,.2014 9:30 AM File folder CD 2: Directional survey data 'L.l"`Gil 5 Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By,v410 yz& 4/ Date: (J�/ 6,0e.eget 11,31,14 II La. n Ellison Hilcorp Alaska, LLQ 2."l�oZ(o GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 DATA LOGGED Tele: 907 777-8339 Abi13/2014 Hilrnrp-U:t.ka.1.1.{. CE I V D Fax: 907 777-8510 M K.BENDER E-mail: lellison@hilcorp.com AUG 12 2014 AOGCC DATE 08/11/14 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 7A Mudlog data Prints: Final Well Report, DML Logging Data Formation Log 2in MD Formation Log 2in TVD Formation Log 5in MD Formation Log 5in TVD LWD Combo Log 2in MD LWD Combo Log 2in TVD Gas Ratio Log 2in MD Gas Ratio Log 2in TVD Drilling Dynamics Log 2in MD Drilling Dynamics Log 2in TVD CD: Final Well Data Files Currently on the Disc (6) Daily Reports 7/25/2014 2:50 PM File folder DML Data 7/25/2014 2:50 PM File folder Final Well Report 7/25/2014 2:50 PM File folder LAS Data 7/25/2014 2:50 PM File folder . Log PDFs 7/25/2014 2:50 PM File folder Log TIFFS 7/25/2014 2:50 PM File folder Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received BY/ ,J uL, / j ate: (17) 11 .andon Ellison Hilcorp Alaska .0 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8339 Hilnurr Alaska,i.u.4: Fax: 907 777-8510 E-mail: Jellison©hilcorp.com Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: PTO Z! F -0 40 Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Tuesday,July 22, 2014 9:59 AM To: 'Stan Porhola' Cc: Davies, Stephen F (DOA); Schwartz, Guy L (DOA) Subject: RE: Procedure Change Request - Sundry 314-398 Follow Up Flag: Follow up Flag Status: Completed Approved as written. 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.ferquson at ialaska.00v 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 [ -iilto:sporhola(ahilcorp.com] Sent: Tuesday, July 22, 2014 9:17 AM To: Ferguson, Victoria L(DOA) Cc: Davies, Stephen F (DOA) Subject: FW: Procedure Change Request- Sundry 314-398 Victoria, With Guy out of the office,see the request below. Stan From: Stan Porhola Sent: Tuesday,July 22, 2014 9:15 AM To: guv.schwartz@alaska.gov Cc: Davies, Stephen F(DOA) (steve.davies©alaska.gov) Subject: Procedure Change Request - Sundry 314-398 Guy, Would like to change the perforation depth for well BCU-07A under Sundry 314-398. Change the perf depth of the LB-29 interval... 1 from: 9,049'-9,053' to: 9,045'-9,060' Regards, Stan Porhola Operations Engineer North Kenai Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 2 2A OCo O OP'\�� , T H.E STATE c_L ,_ _ - r� 333 west Seventh Avenue l('(•G I_.I:''` CR pARNLI-J, Aild(r) c)Ce, Alaska 99 (-ll-35/2 Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek Unit 07A Sundry Number: 314-398 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 �yof July, 2014. Encl. QuI c RECEIVED STATE OF ALASKA JUL 01 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS /01OGGC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril El Perforate New Pod El Repair Well❑ Change Approved Program 0 Suspend❑ Plug Perforations❑ - Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ 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 ❑✓ 214-060 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service ❑ • 6.API Number. Anchorage,Alaska 99503 50-133-20284-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 237A Beaver Creek Unit(BCU)07A Will planned perforations require a spacing exception? Yes ElNo ✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028118 - 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 8,929 9,682 8,811 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 40' 30" 40' 40 Surface 2,077' 20" 2,077' 2,077' 3,060 psi 1,500 psi Intermediate 2,336' 13-3/8" 2,336' 2,336' 3,450 psi 1,950 psi Production 2,336' 9-5/8" 2,336' 2,336' 6,870 psi 4,750 psi Liner 9,767' 5-1/2" 9,767' 8,896' 10,640 psi 7,460 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): N/A N/A N/A WA N/A Packers and SSSV Type: Packers and SSSV MD(t)and 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 ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development n Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 07/08/14 Commencing Operations: Oil ❑ Gas ❑✓ ^ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR El SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Pothole Phone: 907-777-8412 Email sDorholanhilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature ___0 / 1 Phone 907-777-8412 Date D i /t COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: r 3\14.—361 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ ( Location Clearance ❑ Other: .4 y S- OS &:-.P Czz 4- Cr ) Spacing Exception Required? Yes El No [4 Subsequent Form Required: / t qC ii ' / APPROVED BY �" Approved by: COMMISSIONER THE COMMISSION Date: 7/7 9 Submit Form and Form 10-403(Revised 10/2012) i"- Ali v R)lf 2 months from the date of approv > a7'encs uupiicate DSAS JUL - 9 M / 3 f`i Well Prognosis Well: BCU-07A Hilcory Alaska,LL Date:7/01/2014 Well Name: BCU-07A API Number: 50-133-20284-01 Current Status: New Sidetrack Gas Well Leg: N/A Estimated Start Date: July 8th, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-060 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: 1411045C Current Bottom Hole Pressure: —0 psi @ 8,341' TVD (No open perforations) Maximum Expected BHP: --2,900 psi @ 8,341'TVD (Based on offset wells) Max. Allowable Surface Pressure: —2,066 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#7 was drilled as a Grass roots oil exploration well in 1976.The oil intervals were found to be unproductive and the well was plugged back to test gas intervals in the Beluga and Sterling in 1976.The Beluga zones were unproductive.The well was plugged back to 5,600'on July 1976. After plugging back,the Sterling B- 3 was perforated and tested at rates up to 7.3 MMCF/D.A workover was performed in 1982 to change out the completion and add additional zones in the Sterling.A coil tubing cleanout and cement squeeze was performed and the well reperforated in the Sterling in 1987 and 1993.The well had been shut-in since July 1993.The well was sidetracked with Saxon#169 as Beaver Creek Unit#7A and the 5-1/2" production longstring was cemented in late June 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. High dogleg near window. • Will run Cement Bond Log before perforating. !� c �"d • Well will be displaced with Nitrogen before initial perforating at+/-2000 psi SITP. • Z-�C 4' L.r /e/'c, f -' A �j 71/1 -Pres-5'. �S r �/} -� p � 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 0 psi (no open perfs). 2. RU 3-3/8" 6 spf Connex HC wireline guns(will use 1 each 11'gun). 3. RIH and perforate Lower Beluga (LB-31 interval from 9,210'-9,221' (2 run,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=1,420'to BCU-1B. h. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool. 4. RD E-line. Well Prognosis Well: BCU-07A Llileorp Alaska, Date: 7/01/2014 5. Turn well over to production. 6. If LB-31 is non-productive. 7. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be+/- 1,500 psi (remaining gas or applied Nitrogen pressure). 8. RIH and set 5-1/2" CIBP at+/-9,200'. 9. RU 3-3/8" 6 spf Connex HC wireline guns (will use 1 each 10' gun and 1 each 12'gun). Z, 10. RIH and perforate Lower Beluga (L 30) interval from 9,155'-9,165' and 9,123'-9,135' (4 runs, total of 12 spf). c. Bleed tubing pressure to 1,500 psi before perforating. d. Proposed perfs shown on the proposed schematic in red font. e. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. f. Correlate using SLB Cement USIT Log (pending) (Tie-in log depth pending). g. Use Gamma/CCL/to correlate. h. Record tubing pressures before and after each perforating run. i. Distance to nearest well open in same sands= 1,420'to BCU-1B. j. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool. 11. RD E-line. 12. Turn well over to production. 13. If LB-30 is non-productive. 14. 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). 15. RIH and set 5-1/2" CIBP at+/-9,110'. 16. RU 3-3/8" 6 spf Connex HC wireline guns (will use 1 each 4' gun and 1 each 8' gun). 17. RIH and perforate Lower Beluga (LB-29 and LB-28) interval from 9,049'-9,053' and 8,970'-8,978' (4 runs, total of 12 spf). c. Bleed tubing pressure to 1,500 psi before perforating. d. Proposed perfs shown on the proposed schematic in red font. e. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. f. Correlate using SLB Cement USIT Log(pending) (Tie-in log depth pending). g. Use Gamma/CCL/to correlate. h. Record tubing pressures before and after each perforating run. i. Distance to nearest well open in same sands= 1,420'to BCU-1B. j. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool. - 18. RD E-line. 19. Turn well over to production. 20. If LB-29 and LB-28 is non-productive. 21. 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). ,U 22. RIH and set 5-1/2" CIBP at+/-8,960'. l 23. RU 3-3/8" 6 spf Connex HC wireline guns (will use 1 each 8' gun and 1 each 10' gun). 24. RIH and perforate Lower Beluga (LB-26 and LB-25) interval from 8,771'-8,779' and 8,708'-8,718' (4 runs, total of 12 spf). c. Bleed tubing pressure to 1,500 psi before perforating. d. Proposed perfs shown on the proposed schematic in red font. e. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. f. Correlate using SLB Cement USIT Log(pending) (Tie-in log depth pending). g. Use Gamma/CCL/to correlate. Well Prognosis Well: BCU-07A Hilcorp Alaska,LL Date:7/01/2014 h. Record tubing pressures before and after each perforating run. i. Distance to nearest well open in same sands= 1,420'to BCU-1B. j. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool. 25. RD E-line. 26. Turn well over to production. 27. If LB-26 and LB-25 is non-productive. 28. 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). 29. RIH and set 5-1/2" CIBP at+/-8,700'. 30. RU 3-3/8" 6 spf Connex HC wireline guns (will use 1 each 6'gun). 31. RIH and perforate Lower Beluga LB-23) interval from 8,612'-8,618' (2 run, total of 12 spf). c. Bleed tubing pressure to 1,500 psi before perforating. d. Proposed perfs shown on the proposed schematic in red font. e. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. f. Correlate using SLB Cement USIT Log(pending) (Tie-in log depth pending). g. Use Gamma/CCL/to correlate. h. Record tubing pressures before and after each perforating run. i. Distance to nearest well open in same sands= 1,420'to BCU-1B. j. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool. 32. RD E-line. 33. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic •, BCU — 7A ACTUAL Pad 7 1,800 FNL, 2,050'FEL, SCHEMATIC Sec.4, T6N, R10W, S.M. Iiilt•urit Alaska. 1.1.1; Conductor 1 30" LP-B 310#weight Permit#: 214-060 API#: 50-133-20284-01TOP 0' Bottom Prop.Des: FED A-028118 SuTVD 0' 35' KB elevation: 141.2' (18.5'AGL) 36"hole cmt wl 500 sks of Class-G .1::)pBott Lat: N60° 38' 32.402" Long: W151° 2' 16.440" / ' M 35' Spud: 6/02/2014 01:00 hrs �/ rfCasing TD: 6/19/2014 12:30 hrs 20"ace K-55 133Bottweight Rio Released: 6/24/2014 6:00 hrsLL om MD 0' 2,072' 1 TVD 0' 2,072' 26"hole cmt w/3,200 sks of::s '5-1/8"ModifiedID Bore y„ '/ . ' _ InrdteCasing TOC(Est)-366' T� Bottom l RA MkrJt 2,998' MD 0' 2,214' K-55, 68# MD 2,214' 2,336' N-80, 72# 13-3/8"casing cmt top @ 2,130'(CBL 6/08/76) 17-1/2"hole cmt w/2,750 sks of Class-G, • bumped plug Intermediate Casinq 9-5/8" BTC Top Bottom MD 0' 2,336' N-80, 47.0# 12-1/4"hole cmt w/3,185 sks of Class-G RA Mkr Jt 5,727' Production Casinq 5-112" P-110 17 ppf DWCIC-HT Top Bottom MD 0' 9,767' TVD 0' 8,896' • 7-718"hole Cmt wl 791 sks(245 bbls)of 11.5 ppg, •• Lite Crete,413 sks(100 bbls)of 15.3 ppg,Class G cmt w/EASYBLOK Casinq/Cementing Detail 6 4 RA MkrJt 8,536' - 9.4ppg Mud- 10.5 ppg Mud Push(35 bbl) . - 11.5 ppg Cement(245 bbl) • - 15.3 ppg Cement(100 bbl) •. - 8.4 ppg Lease Water(226 bbl) RA Mkr Jt 8,678' • RA Mkr Jt 8,999' Jewelry ! Depth 1.Swell Packer(21'Long) 1,869' - RA MkrJt 9,188' • Casing Shoe @ 9,767' +' Zi.` ''" Openhole -S,t Casing 33'off bottom Max Dogleg: -- _ 11.84°/100'@ 2,353' TD: PBTD: 9,800'MD 9,682'MD Max Inclination: 8,929'TVD 8,811'TVD 39.9°@ 3,350' Well Name&Number.i Beaver Creek Unit#7A Lease._ A-028118 County or Parish._ Kenai Peninsula Borough State/Prov: Alaska Country.IUSA Angle @KOP and Depth._ 0.0°@ 2,336' Angle/Perfs:I N/A Maximum Deviation. 39.9°@ 3,350' Date Completed i 6/23/2014 _ Ground Level(above MSL): 122.7' RKB(above GL): 18.5' Revised By. Stan Porhola Downhole Revision Date: 6/23/2014 Schematic Revision Date: 7/1/2014 ., BCU - 7A PROPOSED Pad 7 1,800 FNL, 2,050'FEL, SCHEMATIC Sec.4, T6N, R10W, S.M. flilvorp Alaska, LI A: Conductor Permit#: 214-060 30" LP-B 310#weight API#: 50-133-20284-01p Bottom Si7 M D 0' 35' Prop.Des: FED A-028118 . ND 0' 35' KB elevation: 141.2' (18.5'AGL) 36"hole cmt w/500 sks of Class-G Lat: N60° 38' 32.402" Long: W151° 2' 16.440" Spud: 6/02/2014 01:00 hrs Surface Casinq TD: 6/19/2014 12:30 hrs \ 20" K-550' 133.33#2,0weight Rig Released: 6/24/2014 6:00 hrs T_Os Bottom MD 0' 2,072' 1 TVD 0' 2,072' • 26"hole cmt w/3,200 sks of Class-G Tree cxn=9-1/2"Otis ; 8.0"Seal Diameter 1 5-1/8"Modified ID Bore . .__ Intermediate Casinq 13-3/8" BTC TOC(Est)-366' Igg Bottom W RA MkrJt 2,998' MD 0' 2,214' K-55, 68# MD 2,214' 2,336' N-80, 72# 13-3/8"casing cmt top @ 2,130'(CBL 6/08/76) 17-1/2"hole cmt w/2,750 sks of Class-G, bumped plug Intermediate Casinq 9-5/8" BTC Top Bottom MD 0' 2,336' N-80, 47.0# . 12-1/4"hole cmt w/3,185 sks of Class-G • ti RA Mkr Jt 5,727' Production Casing 5-112" P-110 17 ppf DWC/C-HT Top Bottom MD 0' 9,767' ND 0' 8,896' 7-7/8"hole Cmt wI 791 sks(245 bbls)of 11.5 ppg, Lite Crete,413 sks(100 bbls)of 15.3 ppg,Class G cmt yid EASYBLOK RA Mkr Jt 8,536' Casing/Cementing Detail - 9.4 ppg Mud 10.5 ppg Mud Push(35 bbl) L8-2.5 - 11.5 ppg Cement(245 bbl) RA MkrJt 8,678' - 15.3 ppg Cement(100 bbl) - 8.4 ppg Lease Water(226 bbl) • LB-25 2 LB-26 - Perforations: Zone MD ND Size SPF Date LB-23 8,612'-8,618' 7,750'-7,756' 3-3/8" 12 Proposed i "' LB-25 8,708'-8,718' 7,845'-7,855' 3-3/8" 12 Proposed LB-28 - - 3 LB-26 8,771'-8,779' 7,907'-7,915' 3-3/8" 12 Proposed a RA MkrJt 8,999' LB-28 8,970'-8,978' 8,104'-8,112' 3-3/8" 12 Proposed LB-29 9,049'-9,053' 8,182'-8,186' 3-3/8" 12 Proposed LB-29 - LB-30 9,123'-9,135' 8,255'-8,267' 3-3/8" 12 Proposed LB-30 9,155-9,165' 8,287'-8,297' 3-3/8" 12 Proposed it r:,. LB-31 9,210'-9,221' 8,341'-8,352' 3-3/8" 12 Proposed Jewelry Depth LB-30 4 - 1.Swell Packer(21'Long) 1,869' LB-30 3.5-1/2"GIBP 8,960' -4 RA MkrJt 9,188' 4.5-1/2"CIBP 9,110' LB-31 - ` 5 5.5-1/2"CIBP 9,200' R, il1. sR � ,. 1 Casing Shoe @9,767' �� Openhole Casing 33'offbottomMax Dogleg: 11.84°/100'@ 2,353' TD: PBTD: 9,800'MD 9,682'MD Max Inclination: 8,929'ND 8,811'ND 39.9°@ 3,350' Well Name&Number.i Beaver Creek Unit#7A Lease: A-028118 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth. 0.0°@ 2,336' Angle/Perfs:I 3.5°to 10.0° Maximum Deviation.. 39.9°@ 3,350' Date Completed:_ 6/23/2014 Ground Level(above MSL): 122.7' RKB(above GL): 18.5' Revised By. Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date. 7/1/2014 �� STATE . _ � � % T �: a a49 -� =� sly _ ), 333 \Ates Sever-WIP.cnut (ovFRY(sR SF?,A' ;'-AR\FII. Anchorage, Alaska 99501-3572 - './.710 907 n7n ,2. Monty Mack Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek (BCU) 7A Hilcorp Alaska, LLC Permit No: 214-060 Surface Location: 1783' FNL, 2033' FEL, SEC. 4, T6N, R1 OW, SM, AK Bottomhole Location: 1171' FNL, 1076' FWL, SEC. 3, T6N, R1 OW, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to re-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, 0 Daniel T. Seamount, Jr. Commissioner DATED thi day of May, 2014. RECEIVED STATE OF ALASKA ;KA OIL AND GAS CONSERVATION COMM N APR 3 0 2014 PERMIT TO DRILL 20 AAC 25.005 AOGCC 1 a Type of Work: 1 b Proposed Well Class Development-Oil ❑ Service- Win) ❑ Single Zone Q ' 1 c.Specify if well is proposed for Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑✓ ` Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑✓ - Reentry❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2 Operator Name 5 Bond Blanket Q Single Well ❑ 11.Well Name and Number Hilcorp Alaska,LLC Bond No 022035244 • ' Beaver Creek(BCU)7A ' 3 Address. 6 Proposed Depth c/47 2/ 12 Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 MD 10,500' ' TVD: Q 7311/5) Beaver Creek 4a Location of Well(Governmental Section) 7.Property Designation(Lease Nunf6er) y•/'f Beluga Gas Pool ' y Surface 1783'FNL,2033'FEL,Sec 4,T6N,R1OW,SM,AK • A028118 Top of Productive Horizon 8 Land Use Permit 13.Approximate Spud Date: 1364'FNL,52'FEL,Sec 4,T6N,R1 OW,SM,AK NA 5/24/2014 • Total Depth 9 Acres in Property 14.Distance to Nearest Property 1171'FNL,1076'FWL,Sec 3,T6N,R1 OW,SM,AK 2,400 acres 2,933 ft from the Unit boundary .' 4b Location of Well(State Base Plane Coordinates-NAD 27) 10 KB Elevation above MSL. 143.6 feet ,15.Distance to Nearest Well Open Surface x=313703 081 - y=2428177.429 ' Zone-4 GL Elevation above MSL 125 feet. to Same Pool 1350' 16 Deviated wells. Kickoff depth 2420' feet • 17 Maximum Antics ated Pressures in psig(see 20 AAC 25 0 ) Maximum Hole Angle 35 degrees Downhole: psi 42,Z.3 Surface psi eZ ,A) ,:-.z.i}' 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' 1E75O0` 300 bbls cmt(includes 20%excess on OH vol) ti ij/-I-t" yi-. 4'7I'1 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): 15,476' 15,476' 5,600' 5,145' 5,145' NA Casing Length Size Cement Volume MD TVD Conductor/Structural 40' 30" 500 sks 40 40 Surface 2,077' 20" 3,200 sks of Class-G 2,077' 2,077' Intermediate 5,625' 13-3/8" 2,750 sks of Class-G 5,625' 5,625' Production 12,526' 9-5/8" 3,185 sks of Class-G 12,501' 12,501' Liner Perforation Depth MD(ft) Perforation Depth TVD(ft) Interval Zone FT SPF Date Interval Zone FT SPF Date 5,114'-5,129' B-3 15 6 6/24/93 5,114'-5,129' 13-3 15 6 6/24/93 (no deviation same as MD) 20 Attachments Property Plat U BOP Sketch U Drilling Program U Time v.Depth Plot U Shallow Hazard Analysis LJ Diverter Sketch n Seabed Report n Drilling Fluid Program n 20 AAC 25 050 requirements n 21 Verbal Approval. Commission Representative. Date 22 I hereby certify that the foregoing is true and correct Monty Mack Myers Contact MMverS@hilCOrp.COM Email Printed Name Monty Mack Myers Title Drilling Engineer Signature Phone 907-777-8431 Date 4/30/2014 ..., s_.• Commission Use Only Permit to Drill er: Permit Approval 513 Secover letter for other NumberZ� -�-1� API Numb50-� '�A � (�-�'1' -'Date I requirements Conditions of approval If box is checked,well may not be used to explore for,test,or produce coalbe methane,gas hydrates,or gas contained in shales [i Other Samples req'd Yes ID Nor' Mud log req'd YeC, NoO+ -fir 500 s< <, E' 1�� B H2S measures Yes Nog Directional svy req'd Yea No "X a1 L_ (G- / /11-/ T✓A Spacing exception req'd Yes❑ No[ Inclination-only svy req'd YeiJ No k ''Lc/L-ce t (.c.,...1. g .(,y 8_,�--,l0 r - / l� APPROVED BY 4.Approved by COMMISSIONER THE COMMISSION Date �7"/�> /CL--- 5-1•fr1ORIGINAL j;b s- 2`!y $1y, Submit Form and Form 10-401(Revised 10/2012) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate Monty Myers Hilcorp Alaska, LLC HilcorpDrilling Engineer P.O. Box 244027 Enemy Company Anchorage,AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com April 30, 2014 Commissioner Alaska Oil &Gas Conservation Commission RECEIVED 333 W.7th Avenue Anchorage,Alaska 99501 APR 3±±0 2014 Re: Beaver Creek Unit 7A AOGCC Dear Commissioner, Beaver Creek#7A is a sidetrack to replace the original Beaver Creek#7 lower Beluga production hole section with a new well. The asset team believes that the Sterling and Lower Beluga has been underdeveloped on the southern part of the Beaver Creek structure. Our intent is to sidetrack the well to the NE and target the Sterling and Lower Beluga from the • original Beaver Creek#7. The new well will utilize the existing casing program down to 2400' MD. The base plan is a deviated wellbore reaching a maximum inclination of 35 deg and a 3163' vertical separation at TD. Drilling operations are expected to commence approximately May 24th, 2014 with the Saxon Rig#169. This rig will be used to sidetrack the existing Beaver Creek#7 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"2400'. POOH standing back DP. 4. Run and set whipstock, displace to drilling fluid at 9.0 ppg. Mill window and 20' of new formation. Conduct FIT to 11.0 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 A spacing exception is not required for Beaver Creek Unit 7A,Conservation order 237, Rule 3A. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, <77.----- --......, . ..rs Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 2 of 2 11 Hilcorp Alaska, LLC Beaver Creek 7A Drilling Program Beaver Creek Reviewed;-.>---,,__;: • W 2.7 . zo ty Mani lyers---- Approved: / �e 4- Paul Mauli Revision 0 April 16, 2014 Beaver Creek 7A Drilling Procedure Rev 0 Ilikor1 ,Va>ka,I.IA: 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 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 5.5"Production Casing 21 16.0 Cement 5.5"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 Surface Plat(As Built)(NAD 27) 38 29.0 Surface Plat(As Built)(NAD 83) 39 30.0 Directional Program (P1) 40 Beaver Creek 7A 11 Drilling Procedure Rev 0 Hilcorp Alasku,LI.0 1.0 Well Summary Well Beaver Creek#7A • Pad&Old Well Designation Sidetrack of existing well Beaver Creek 7 • Planned Completion Type 5-1/2" 17#P-110 Longstring Target Reservoir(s) Beluga Planned Well TD,MD/TVD 10500' MD/9731' TVD • PBTD,MD/TVD 10380' MD/9611' TVD Surface Location(Governmental) 1783'FNL,2033' FEL, Sec 4,T6N,R1OW, SM,AK • Surface Location(NAD 27) X=313703.081,Y=2428177.429 • Surface Location(NAD 83) Top of Productive Horizon (Governmental) 1364'FNL, 52'FEL, Sec 4,T6N,R1OW, SM,AK TPH Location(NAD 27) X=315684,Y=2428573 TPH Location(NAD 83) BHL(Governmental) 1171'FNL, 1076'FWL, Sec 3,T6N,R1OW, SM,AK BHL(NAD 27) X=316783.1,Y=2428783.8 BHL(NAD 83) AFE Number 1411045D ME Drilling Days 21 ME Drilling Amount $4.45 MM Work String 4-1/2" 16.6#S-135 CDS-40 RKB—GL 18.6' Ground Elevation 125' 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 April 14,2014 Beaver Creek 7A Drilling Procedure Rev 0 Ililrorp Alaska,LLA: 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Emu; Changes to Approved Permit to Drill Date: April 16,2014 Subject Changes to Approved Permit to Drill for Beaver Creek #7A File#: Beaver Creek #7A 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 April 14, 2014 Beaver Creek 7A Drilling Procedure Rev 0 Ililcorp Alu•ka. 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 April 14,2014 Beaver Creek 7A 11 Drilling Procedure Rev 0 llilrorp A6,121.1,11; 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 Drilling 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 April 14,2014 Beaver Creek 7A II Drilling Procedure Rev 0 Hileorp Alaska,LEE 6.0 Planned Wellbore Schematic BCU - 7A PROPOSED (Vertical Well) Pad 7 SCHEMATIC 1,800 FNL, 2,050'FEL, 'Wort)Alaska.LLC Sec.4, T6N, R10W, S.M. Existing Conductor Permit#* 176-006 30" LP-B 310#weight API#' 50-133-20284-00 1 k ' MD 0' X40'm Prop.Des: FED A-028118 - .+ ND 0' 40' KB elevation' 146.2' (23.5'AGL) •-� 36"hole cmtw/500 sks ofClass-G Y: 2,428,169.44 • + 5-1/2"X9-518"SwellPkr 313,680.54 a 61900. Spud: 3/30/1976 12:00 hrs I q Existing Surface Casino TD' 720/1976 i ti 20" K-55 133.33#weight )Zig Released: 8/5/1976 12:00 hrs \ KOP 2400' s ZR Bottom per. MD 0' 2,07T Big; Brinkerhoff#43 } t' ` ND 0'? r/ : 2t •i •. ,, EdstingInterme13-3/8" TC 1y Proposed CementSqueeze in annulus of l3-3/8" ./ y, i1 y Top Bottom /` X9-5/8"for Milling window thru 2 strings. VVV 4 MD 28' 2,214' K-55, 68# Z MD 2,214' 5,153' P480,72# ' MD 5,153' 5,625' S-95,72# y • ND 0' 5,625' 17-1/2"hole cm t wl 2,750 sks of Class-G, 3- `• �1 bumpedplug 13-318"casing cm t top @ 2,130'(CBL 6!08!76) $. • •'� .1 3 Existing Production 9-5/8"casing cmt top§5,14T ELM(6/24/93) w :I.' 4 9-5/ 8" BTC 4. - -_ ''.. 5 lop .130_01_31 _ MD 25' 4,646' N-80,47.09 Fill tagged @- 5,154'SLM (3/18/14) rMD 4,646' 11,104' S-95, 53.5# ar ' MD 11,104' 12,526' P-110,53.5# B-3 CND 0' 12,526' (' • 12-114"hole cmtw13,185sks of Class-G ". ' - 13-3,, .� ,.,9:= 8-3b Inclination Detail Bare Foot Section Drill 7-7/8"Hole 8-172"hole -_- 9 ' KOP:2400' lop Bottom \6 Azimuth:78 degrees MD 0' 15,476' 7 Build:5 deg per 100'DLS Fold:29 Deg inclination from 3005'to 7153' TVD 0' Drop:3 deg per 100'to vertical Class-B cmt Plum w TD at 10,500' 12,476'-12576' (100 sks) • ;i , 14,500'-14,600' (50 sks) 14,70044,800' (50 sks) , 15,000'-15,100' (50 sks) ;+ 8 15,30045,400' (40 sks) i ' Pronos ed Production Cas lnq 5-1/2" P-110 17# DWC/C =e,•••';'•.,; -13p Bottom Jewelry Depth e: Beluga MD 18' 10,500' 3.Otis XA Orc.Sleeve(2.75'1D) 4,889' _ ND 18' 9,731' 4.Baker Mod.F}i Rv.(3.00'ID) 4,922' - - • 9 . ; Proposed to Cmt to Inside window with 300 5.Baker Shear Sub w/WL Guide(3.00"ID) 4,959' bbls cm t(includes 20%exce ss on OH vo l) 6.Top of Sand and Cement Rug 5,145' , 7.HOWCO Q-Drill Bridge Rug 5,600' 1 8.Top of 250 sack Cement Rug 7,830' ., I 9.1OWC2 Bridge Rug 8,555' ; ,,''' , ;, 10 J 71 1-3 10.Top of 50 sack Cement plug above HOWCO CIBP 12,426' 11.110WC 3 Cast Iron Bridge Rug 12,630' 11 ri l b PBTD: 5,600'MD y-•' 5,600'ND Ilz 15,476'MD -y:',4e. 15,476'TVD Page 6 Revision 0 April 14,2014 Beaver Creek 7A Drilling Procedure Rev 0 llilwrp Alaska,1J.0 7.0 Drilling Summary Beaver Creek#7A is a sidetrack to replace the original Beaver Creek#7 lower Beluga production hole section with a new well. The asset team believes that the Sterling and Lower Beluga has been underdeveloped on the southern part of the Beaver Creek structure. Our intent is to sidetrack the well to the NE and target the Sterling and Lower Beluga from the original Beaver Creek# 7. The new well will utilize the existing casing program down to 2400' MD. The base plan is a deviated wellbore reaching a maximum inclination of 35 deg and a 3163' vertical • separation at TD. Drilling operations are expected to commence approximately May 24th, 2014 with the Saxon Rig#169. This rig will be used to sidetrack the existing Beaver Creek #7 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. . (� 3 i'1- .210 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 2400'. POOH standing back DP. 4. Run and set whipstock, displace to drilling fluid at 9.0 ppg. Mill window and 20' of new . formation. Conduct FIT to 11.0 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 April 14, 2014 Beaver Creek 7A 14 Drilling Procedure Rev 0 Hil(orp Alaska,LLC 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#14 RD. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. Ensure to provide BLM 48 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/4500 psi & subsequent tests of the BOP equipment will be to 250/4500 psi for 10/10 min (annular to 50%rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system" • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure both AOGCC approved drilling permit and BLM sundry are posted on the rig floor and in Co Man office. 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. ,/ yet_ _5. 7 1'1 Page 8 Revision 0 April 14, 2014 Beaver Creek 7A II Drilling Procedure Rev 0 llilcorp Alaska,1.1.0 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 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/TestWitnessNoti£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 April 14,2014 Beaver Creek 7A 14 Drilling Procedure Rev 0 Ililcarp Alaska,TIC 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. v 7 • Tag &pressure test cmt plug. E-- 3(�f • Run and set a CIBP at 2400' 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 April 14,2014 Beaver Creek 7A 1 ti Drilling Procedure Rev 0 Ifilcorp Ala.ka.I.I.0 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/11"x 5M single ram. • 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 April 14, 2014 Beaver Creek 7A Drilling Procedure Rev 0 flacon)Alaska.1.1.0 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%KC1/PHPA fresh water based drilling fluid. Properties: MD Density Viscosity Plastic Viscosity Yield Point pH HPHT 2400' — 10500' 9-10.5 40-53 15-25 15-25 8.5-9.5 51 1.0 System Formulation: 6% KCI/ EZ Mud DP Product Concentration WATER 0.905 bbl CAUSTIC 22 ppb (29K Chlorides) BARAZAN D+ 0.2 ppb (9 pH) EZ MUD DP 1.25 ppb (as required 18+YP) DEXTRID LT 0.75 ppb (initial .25 ppb) PAC-L 1-2 ppb BARACARB 5/25/50 1.0 ppb STEELSEAL 50/100/400 10 ppb (3.3 ppb each) BAROFIBER as directed BAROTROL PLUS as directed BAROID 41 as directed ALDACIDE G as required for 9.0-10.5 ppg BAROCOR 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 zi overbalanced and have the challenge to mitigate lost circulation while drilling ahead. Page 12 Revision 0 April 14, 2014 Beaver Creek 7A Drilling Procedure Rev 0 Itilwrp Alaska.1.1.1: 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 8-1/2"taper mill (or 8-1/2"mill tooth bit) and a 8-1/2" 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. I 12.2 TIH to CIBP (2400' 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 April 14, 2014 Beaver Creek 7A 14 Drilling Procedure Rev 0 Ililcorp Alaska,LLC 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 1/2 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 April 14,2014 Beaver Creek 7A Drilling Procedure Rev 0 llilcarp Alaska,1.1.0 WindowMaster G2 System on TorqueMaster BTA 9 5/8"40#Csg—WindowMaster G2 On BTA BHA#1 Connection Length O.D. BOTTOM TRIP ANCHOR 4/:IF-Box X Bottom Guide 3.42' 8.352" WINDOW MASTER WHIPSTOCK Shear Bolt X 4/:IF-Pin 18.54' 8.00" WINDOW MILL 4-1/2 Reg-Pin X MiII 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 X 4-1/2 IF-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 April 14,2014 Beaver Creek 7A Drilling Procedure Rev 0 l lilcorp Alaska,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 'A round increments. P/U and S/O on DP to work all torque out(Being careful not to set BTA). Whipstock Orientation Diagram: 25 AZI 75 AZI Desired orientation of the Whipstock face is 25 to 75 degrees azimuth. Hole Angle at window interval (2400' MD) is < 1 deg. The wellbore trajectory is also planned to the right of the existing wellbore. 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). A- 13.5 P/U 5-10' above top of Whipstock. n• , 13.6 Record P/U, S/O weights, and free rotation. Slack off to top of Whipstock and with light weight f1 and low torque. Mill window. Utilize 4 ditch magnets on the surface to catch metal cuttings. ** Please note that we are milling through 2 strings of casing. 9-5/8" and 13-3/8". This may require 2 mill runs and torque could be erratic. 13.7 Install catch trays in shaker underflow chute to help catch iron. \/ 13.8 Keep iron in separate bbls. Record weight of iron recovered on ditch magnets. 7(-c 1A Page 16 Revision 0 April 14, 2014 Beaver Creek 7A Drilling Procedure Rev 0 ttilcorp Alaska,Ii i 13.9 Estimated metal cuttings volume from cutting window: 9-5/8"47#N-80 13-3/8" 72# N-80 Cuttings Weight Casing Window Length Weight Min (lbs) Avg(lbs) Max(lbs) 28 47# 150 225 300 28 72# 82 172 215 13.10 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. 13.11 Circulate Bottoms Up until MW in=MW out. 13.12 Conduct FIT to 11 ppg EMW. • (11 —9) * 0.052 * 4760' tvd=495 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. 13.13 Slug pipe and POOH. Gauge Mills for wear. 13.14 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 '/2 IF-B X 4 % REG-B 5.67 8.50 FLEX JOINT 4 '/ 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 4W 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 April 14,2014 Beaver Creek 7A Drilling Procedure Rev 0 Ifilcorp Alaska,1.I.0 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 0.46 —0.55 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 1.5 deg. Must keep up with 5 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 April 14, 2014 Beaver Creek 7A 11 Drilling Procedure Rev 0 Ititwrp Alaska,IAA: 7-7/8" (2o0mm) FX55 PRODUCT SPECIFICATIONS Cutter Type X3-Extreme Drilling le , ', IADC Coda: M324 Body Type MATRIX Total Cutter Count 37 ' Cutter Distribution 13mm 16ntm Face 0 72 e d Gauge 10 0 1 i r Back Ream 2 0 ( ii I Up Drill 3 0 Number of Large Nozzles 0 Number of Medium Nozzles 0 r Number of Small Nozzles 5 Number of Micro Nozzles 0 .. .. xz, Number of Ports(Size) 0 Number of Replaceable Ports(Size) 0 $ ,+ Junk Slot Area(sq in) 11.54 f Itill tit Normalized Face Volume 41.42% i CO' API Connection 41.2 REG.PINern Recommended Make-Up Torque' 12.461—17,766 Ft'Ibs. +_,*iy Nominal Dimensions** !+ Make-Up Face to Nose 10.13 in-257 min Gauge Length 23 in-61 mm Sleeve Length 0 in-0 mm Shank Diameter 5.75 in-146 mm Break Out Plate(Drat.#/Legacyti) 181954/44040 Approximate Shipping Weight 120Lbs.-54Kg. SPECIAL FEATURES Up-Drill Cutters on Gage Pads,Back Reaming Cutters on Gage Pads. Hexagon TSP Gage,1/I6°Relieved Gage Material#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.8.2. "Design dimensions are nominal and may vary slightly on manufactured product.Halliburton Drill Bits and Services models arc continuously reviewed and refined. Product specifications may change without notice. 4:2014 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 April 14, 2014 Beaver Creek 7A Drilling Procedure Rev 0 ttilcorp Alaska,1.1.1: 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 10,500' 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. • Utilize only CaCO3 for weighting material and LCM • Adjust MW as necessary to maintain hole stability • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain HTHP fluid loss <6. • Take MWD surveys every stand drilled • NO"Black"products to be utilized for coal stabilization without discussion with Anchorage Drilling Team 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 assembly,handle BHA as appropriate. Page 20 Revision 0 April 14,2014 Beaver Creek 7A Drilling Procedure Rev 0 Uncurl)Alaska,LLC 15.0 Run 5.5" Production Casing 15.1 R/U Weatherford 5.5" casing running equipment. • Ensure 5.5"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 5.5"production casing • Fill casing while running using fill up line on rig floor. • Use"API Modified"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every joint across zones of interest, TBD after LWD. • Install solid body centralizers on every other joint to window. Leave the centralizers free floating. • Pick up swell packer and place in string at approximately 1900'. • 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. 5.5" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 5.5" 11,270 ft-lbs 13,770 ft-lbs 12,520 ft-lbs Page 21 Revision 0 April 14, 2014 Beaver Creek 7A Drilling Procedure Rev 0 ltilcorp Alaska,TIC Technical Specifications Connection Type: Size(O.D.): Weight(Wail): Grade: DWC/C-HT Casing 5-112 ui 17.00 Iblft(0.304 in) P-110 standa:-d Material P-110 Grade 110,000 Minimum Yield Strength (psi) U Sao 125,000 Minimum Ultimate Strength(psi) VIM LISA 4424 W.Sam Houston Pkwy.Suite 150 Pipe Dimensions Houston,TX 77641 Phone: 5.500 Nominal Pipe Body O.D-(in) Fax:713-479-3234 4.892 Nominal Pipe Body LD.(in) E-mail,:VAMUSAsalesgi)vam-usa.com 0.304 Nominal Wall Thickness(in) 17.00 Nominal Weight(lbs/ft) 16.89 Plain End Weight(Ibsift) 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) 4.13 Make-up Loss(in) 4.962 Critical Area(sq in) • 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 April 14, 2014 Beaver Creek 7A Drilling Procedure Rev 0 Hikorp Alaska,1.1.0 15.7 Run in hole w/5-1/2"casing to the window. 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 PU 5-1/2" X 8-1/2" swell packer to be placed at approximately 1900'. Swell packer should have 10' handling pups installed on both ends with bow spring centralizers on pups. 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 April 14,2014 Beaver Creek 7A Drilling Procedure Rev 0 iiiker!,:Ua.ka.LLI: 16.0 Cement 5.5" 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 10.5 ppg MUDPUSH II spacer. 16.4 Test surface cmt lines to 4500 psi. 16.5 Pump remaining 25 bbls 10.5 ppg MUDPUSH II spacer. 16.6 Mix and pump 212.7 bbls of 11.0 ppg LiteCrete Lead cmt and 125.1 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 on the slurry, 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. Cement Calculations 9-5/8"Casing x 5-1/2"Ann: Lead 500' x 0.0464= 23.2 bbls 7-7/8"off x 5-1/2"Ann+ Lead(7500' -2400') x.0309 x 1.35 = 212.7 bbls 35%excess 7-7/8"OH x 5-1/2" Ann+ Tail(10500' -7500')x .0309 x 1.35 = 125.1 bbls 35%excess Shoe Track: Tail 120' x 0.02218 = 2.6 bbl Total Volume(bbls): 23.2 +212.7 + 125.1 +2.6= 363.6 bbls Total Volume(ft3): Lead 212.7 bbls x 5.615 ft3/bbl= 1194 ft3 Tail 125.1 bbls x 5.615 ft3/bbl= 702 ft3 Total Volume(sx): Lead 1194 ft3 / 1.88 ft3/sk= 635 sx Tail 702 ft3 / 1.35 ft3/sk= 520 sx Page 24 Revision 0 April 14,2014 Beaver Creek 7A Drilling Procedure Rev 0 Ililcwrp Ala•ka. 16.0 Cement 5.5" 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 stick . a Li 16.3 Pump 10 bbls 10.5 ppg MUDPUSH II spacer. E 16.4 Test surface cmt lines to 4500 psi. 16.5 Pump remaining 25 bbls 10.5 ppg MUDPUSH II spacer. 16.6 Mix and pump 210 bbls of 11.0 ppg LiteCrete Lead cm :nd 94.4 bbls of 15.3 ppg class "G" cmt per below recipe. Ensure cmt is pumped at designed , eight. Job is designed to pump 35% OH excess on the slurry, but if fluid caliper dictates oth; wise we may increase excess volumes. Cement volume is designed to give 500' of ceme, inside window in annulus between 9-5/8" casing and 5-1/2" casing. Cement Calculations e,A." 9-5/8"Casing x 5-1/2"Ann: e Lead 500' x 0.0464= 23.2 bbls 7-7/8"OH x 5-1/2"Ann+ Lead(7 00' -2400')x.0309 x 1.35 = 212.7 bbls 35%excess 7-7/8"OH x 5-1/2"Ann+ Tai 10500' -7500') x .0309 x 1.35 = 125.1 bbls 35%excess Shoe Track: Tail 120' x 0.02218 = 2.6 bbl Total Volume(bbls): 23.2 +212.7+ 125.1 +2.6 = 3 s (30 '68° Total Volume(ft Lead 212.7 bbls x 5.615 ft3/bbl= 1194 ft3 Tail 125.1 bbls x 5.615 ft3/bbl= 702 ft3 Total Volu (sx): Lead 1194 ft3 / 1.88 ft3/sk= 635 sx Tail 702 ft3 / 1.35 ft3/sk= 520 sx SUPERCEDED 7 Page 24 Revision 0 April 14,2014 Beaver Creek 7A 14 Drilling Procedure Rev 0 uaeorp nitt.� ,,►.i.c Slurry Information: LEA TAIL— System LiteCrete Easy BLOK Density 11.0 lb/gal 15.3 lb/gal Yield 2 ft3/sk .35 ft3/sk Water 6.816 gal/ski 5.966 gal/sk Mixed 6.826 gal/sk 5.966 gal/sk Fluid Expected 70 Bc at 07:00 hr:mn 70 Bc at 05:00 hr:mn Thickening API Fluid <80 mL in 30.0 min at 155degF/ <50 mL in 30.0 min at 155degF/ 1000 psi Loss 1000 psi Code Description Concentration Code Description Concentration D962 LiteCRETE 100 lb/sk G Cement 94 lb/sk D046 Anti Foam 0.2%BWOB D046 Anti Foam 0.2%BWOC D065 Dispersant 0.4% BWOB D202 Dispersant 1.0% BWOC 0.35% Gas Additives D167 Fluid Loss BWOB D400 Control 0.8%BWOC Agent D177 Retarder 0.01 gal/sk D154 Extender 8.0%BWOC D174 Expanding 1.5% BWOC Agent D198 Retarder 0.3%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. Page 25 Revision 0 April 14, 2014 Beaver Creek 7A Drilling Procedure Rev 0 HiIcorp Alaska,1.1,1: 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 1/2 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 psi and chart for 30 minutes. Li000 ps> c7PI 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 mmyersAhilcorp.com Page 26 Revision 0 April 14, 2014 Beaver Creek 7A Drilling Procedure Rev 0 ttilcarp Alaska,1.1.1: 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. r JA -� z,s�,o p L Sw�l� p�c`�2 Ckrc k-L-C -1----e s7 `r* Page 27 Revision 0 April 14, 2014 Beaver Creek 7A 1111 Drilling Procedure Rev 0 Ililcorp Alaska,LL( 18.0 BOP Schematic Iil III li 'I5 lII til iii iii Ii i i 3.5" Vj i '..alar 6011i •.-... 1 iii -13 ow _ .., . hump- ftyFVdel7 J12 _ _ - _. : 11"5�0� +a• III I= l D ss 0 III Ill Ill Ill !II ; 2.10' 10111+rTtir bII iI. 11 2 WS SM Kill Side '61°11/8 5M Choke Side • maaa- 1.`,1' :®g �kf�� ,,1: 1 I "'3 2 �� . -Ir:i' :we; 1> :1 _tea- ." Grade fel f1`t1 fft III 11) alr. MEI ' ':',..1 le i 1___ l a111 II IL mi [mom • ii 41111 1 IM !1 to" 7" Page 28 Revision 0 April 14, 2014 Beaver Creek 7A II Drilling Procedure Rev 0 Hikorp Alaska,LLC 19.0 Wellhead Schematic Beaver Creek Tubing hanger,FMC-TC-EN • - BC#7 CL,11 x 3%IBT lift&susp, 20x 133/8 X 95/8 X 31/2 w/3'ISBPV,5.990" extended neck Tree cap FMC B-15-A, 3 1/8 5M FE I P 1.1... ..I III Valve,Swab,OCT-20,3 1/8 rM FE, ifr HWO,DDtrlm 0l uuOO soli 11P' P.„ilif HWO,DD trim Valve,upper master,OCT-20,31/8 5M FE, eloW1741, `i�" HWO,DD trim ,,V` _.1 C Li v,p P. Valve,master, P OCT-20,3 1/8 5M FE, r>- f. HWO,DD trim O,44 100 44Logr 1`'..r I.1'-' Adapter,FMC-ASP-CL, 11 SM FE X3 1/8 5M,prepped for III III 5.990"extended neck Tubing head,OCT-TC-BG, 135/85MX11SM,w/ r�- i1iLL u, 2-2 1/16 SM 550 �_ Valve,OCT-20,2 1/16 SM FE, HWO �� 1)�\)- 1 11 +�� Grade Level ill IN Ai,- Casing spool,OCT-22-BP, '61.1 j - 21%2MX135/8SM, 1uj - 111 Valve,OCT-20,31/85M FE, w/2-31/85MEFO, - - : _ cl HWO 00bottom prep °-�,./ [liii Ii.,,,,ii NIa-1• i . III Ill Casing head,OCT-22, - 21%2MXSOW,w/ 2-2 1/16 5M EFO o t - III Valve,OCT-20,2 1/16 SM FE, II rpl c HWO �n Page 29 Revision 0 April 14,2014 Beaver Creek 7A Drilling Procedure Rev 0 IGkorp Alaska,r.l.c 20.0 Days vs Depth Days Vs Depth 0 2000 — — —— --- 4000 -- c 6000 0 8000 - 10000 — — 12000 -`-- �— ---� D 5 10 15 20 25 30 Days Page 30 Revision 0 April 14, 2014 Beaver Creek 7A Drilling Procedure Rev 0 1.1.1: 21.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: BCU 07 RD(ST out of BCU 07) FIELD: Beaver Creek SURFACE: X=313703.4 LONG:-151.0378.(BCU 7 Pad) STATE: Alaska Y=2428177.4 LAT:60.6423349 BOTTOMHOLE X=316865.2 LONG:-151.0306121 TVD REF DATUM KB Y=2428797.9 LAT: 60.6432964 TVD REF ELEV 142 18'KB(Saxon 169) COORD REF SYSTEM NAD27 GROUND ELEV 124 PROPOSED TD: 10,500'MD/9,731'TVD Objective: Lower Beluga B18-B32 gas sands Geo Summary/ Justification: The lower Beluga has been underdeveloped on the southern part of the Beaver Creek structure. The goal of the BCU 07 RD well is to test the lower Beluga in the southwestern portion of the field and confirm the size/shape of the structure to the south. The KOP is high enough to also test the secondarygas objectives in the Sterling B sands. The Sterling B3L is of particular interest given its anomalous thickness in the BCU 07. ANTICIPATED FORMATION TOPS&GEOHAZARDS EXPECTED Critical Intersection Points TOP TOP NAME FORMATION FLUID TVD(FT) TVDSS(FT) Est.Pressure X Y +/- KOP Sterling 2,400 -2,400 1000-1050 psi • B1 Sterling Gas/Water 4,937 -4,795 1900-2300 psi . 314083.5 2428273.6 20 B3 Sterling Gas/Water 5,103 -4,961 1900-2300 psi • 314174.9 2428291.9 20 B4 Sterling Water/Gas 5,275 -5,133 1900-2300 psi . 314266.3 2428328.5 20 B18 Lower Beluga Gas 7,333 -7,191 1000-3300 psi • 314887.9 2428474.7 30 B20 Lower Beluga Gas 7,490 -7,348 1000-3400 psi 314906.2 2428474.7 30 B23 Lower Beluga Gas 7,734 -7,592 1000-3500 psi • 314924.4 2428493.0 30 B27 Lower Beluga Gas 7,978 -7,836 3000-3600 psi. 314942.7 2428493.0 30 B28B Lower Beluga Gas 8,174 -8,032 3000-3600 psi. 314961.0 2428493.0 30 B31 Lower Beluga Gas 8,396 -8,254 3000-3600 psi• 314979.3 2428493.0 30 TD Lower Beluga 9,731 -9,589 14517 See BHL above =Primary Objective =Secondary Objective TARGET RADIUS 100 ft DATA COLLECTION REQUIREMENTS: Mud Logging: Full crew of 4 on for production hole section. LWD Data: GR for Production Hole section E-Line Log Data: Open Hole Quad Combo COMPLETION TYPE Gas Lift completion ANTICIPATED RATES ARTIFICIAL LIFT EQUIPMENT OD TUBING SIZE 2-7/8" RECEIVED MAY 012014 AOGCC Page 31 Revision 0 April 14, 2014 Beaver Creek 7A II Drilling Procedure Rev 0 Hilcorp Alaska,Ill: 21.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: BCU 07A(ST out ofBCU 07) FIELD: /BeaverCreek SURFACE: X=313703.4 LONG:-151.03785(BCU 7 Pad) STATE: Y=2428177.4 LAT:60.6423349 { BOTTOM HOLE X=315016.7 ,LONG:-151.0306121 TVD REF DATI Y=2428508.2 I LAT: 60.6432964 TVD REF ELEB(Saxon 169) COORD REF. _{ SYSTEM 'NAD27 GROUND EL PROPOSED TD: ,10,500'MD/10,402'TVD I Objective: Lower Beluga B18-B32 gas sands Geo Summary/ Justification: The lower Beluga has been underdeveloped on the southern part o the Beaver Creek structure. The goal of the BCU 07 RD well is to test the lower Beluga in the southweste' portion of the field and confirm the j size/shape of the structure to the south. The KOP is high enou' to also test the secondary gas objectives in' the Sterling B sands. The Sterling B3L is of particular interes given its anomalous thickness in the BCU 07. , • ANTICIPATED FORMATION TOPS&GEOHAZARDS EXPECTED Critical Intersection Points TOP TOP NAME FORMATION FLUID D TVDSS(F7) Est.Pressure X Y +/- I KOP Sterling i ,400 -2,258 1900-2300 psi , B1 Sterling Gas/Water l 4,9 -4,795 1900-2300 psi I_ 314083.5 2428273.6 20i B3 Sterling Gas/Water 103 -4,961 1900-2300 psi I 314174.9 2428291.9 20 B4 Sterling . Water/Gas 5,275 -5,133 1900-2300 psi 314266.3 2428328.5 20 B18 Lower Beluga Gas 7,333 -7,1911000-3300 psi 314887.9 2428474.7 30 B20 Lower Beluga Gas it 7,490 -7,348 J 1000-3400 psi 314906.2 2428474.7 30 B23 Lower Beluga Ga 7,7341 _ -7,592 1000-3500 psi 314924.4 2428493.0 30 B27 Lower Beluga Ga :7,978 -7,836 3000-3600 psi 314942.7 2428493.0 30 B28B Lower Beluga j Qas de It:174 -8,032 3000-3600 psi 314961.0 2428493.0 30 B31 Lower Beluga `Ga \ / 8396 8,25.4 3000-3600 psi 314979.3 2428493.0 30 TD Lower Beluga - 10,402 See BHL above I =Primary Objective =Secondary Objective TARGET RADIUS 100 ft j •DATA COLLECTION REQUIREMENTS: Mud Logging: Full crew of 4 on for production hole section. LWD Data: GR for Production Hole section E-Line Log Data: Open Hole Quad Combo COMPLETION TYPE Gas Lift completion ANTICIPATED RATES ARTIFICIAL LIFT EQUIPMENT OD TUBING SIZE 2-7/8" Page 31 Revision 0 April 14, 2014 Beaver Creek 7A 14 Drilling Procedure Rev 0 Ili'carp Alaska,I.I.0 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. v No abnormal temperatures or pressures are present in this hole section. Page 32 Revision 0 April 14,2014 Beaver Creek 7A II Drilling Procedure Rev 0 Iliicorp Alaska,11C 23.0 Rig Layout FEE T::a; '1 Ran i ::gil i IIDI.- _. FII _ I�N pnuFc r _ RFGFR.F To-NFIE-12411 Pirc vim a L! L 1' ' 'L 'I . I i �� I1I'_ _ .— _'III I U_a , Ip11_ 17—H-11 • =•7 1 mum, • - yr+Pilo,1 r wac.4 mc I 1 [ 5� JI I r. IIIIDl1 e — wWm�WmLr —_I _ :.F II INE I 0 r. ��r f._,.av[TnFu'F t . _rr— tl.FKRI T.WF 1 ._ . `.— WIIIIII I C =. I -.-' litilli --W.III L III to, _ jq nl FI.TFR 141[/74.:11]111 4.- 1I —.1.F. 11.11 .111111.1 Page 33 Revision 0 April 14,2014 Beaver Creek 7A 14 Drilling Procedure Rev 0 Hikorp Alaska.LI.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 April 14,2014 II Beaver Creek 7A Drilling Procedure Rev 0 Hilcorp Alaska,1.I.0 25.0 Choke Manifold Schematic fi(- A.9 97.24 44.62 43.62 ' 47-41. 0.,,,, 0 7,.:• CI'PV ill* 1643 1442 7,-.Apteim 4 14.52 1843 - 0 015 •19 VitlY ..-0,,, 019-- 4011,1;1 (*.'S#S1 ro MIMI.1 I•1 ,01 ii an lin IWO A 1 9. 2 .4. 'AV-v., is %.,e,,,,.., i i 41.7..va„Nt ci 7 r * t:1/4*o-"Po 57.4-#Agi . IlHoo L___, -.----- : - 1,-,,,,:z..ak,...--.-8. ,,, „,-----; : 90 - 1 , . 1 I ii Ei ,!-n--",P71 I i i i ' • I .'"4 1 ai9-1 '•• •,•°..' 1° 0 MIME 0 ig-1 I Nr--1,,, 0 ,„„„ , 010-1 0 734 llf CI 121 mihilat till I l!..,2) ' • '`. 7.e4 rug .iiM,11111 CD 11) 9 94 tor al linlir1121 1 1 1 I 1 MOIMPI gillitiir 0.19-1 1 totiesp0 MI„mil _ IMIII.°1 ..1 38.03 ArTit, no is lin 0 0 0 14.62 0.41,4,4 C' 6fAII6 14, 3"3 ... en, Aar/ 4.444;1:1.-It c) .4'. C, 11110;(14 1 I I mum Cl. t<77.11 ... rals .mmi ,19 J 0 10 50 L.. , , '''''V.IMI I .0 11.4.P/1 ; I?wAil‘ -;4,; 'I AP44.•'• ! ,116.4..z;i4i• a ° 1000 I i 1w.ma kt _,QT9. . 44)4, Air4 ri.) , ae. -0 _ ,,; :4 I 'tide. 4i it-4x. Wig ' . -..; 4 .0 Nuan 111 - __ IL 114V-0.19 -c--.-. 0 0 \-.12 cioct 1.12.,CHCfy/ -0.15 .0.10 0.19 - MANUAL - ACTUATED i 1 .---0.19 OPM411014 -9.31--14.62----1462 -.,-.--14.62 14,62--. -.--.6.31 43.52 43.62 87.24 ...-..-.--W CAD ,E3- r.:A=1=71:4=r.,T,====i'e••" 1.LAYOUT 4101 5 CASICe.13 ....... g.1.41.749743,............ ADO '""' ."--- 7,--e1:: -..7:,- ,rIt• '''.„_...r... s......4 0.unr sEs:0;wann -="7.21.7.=-7..€-43.-44,-"../2 Zi. ""Zr-Lrort tea ar CIA.111%111T.-?7,n1=4125 . 1,7,Ir-a-mus-ss-ii-oq .--.- Page 35 Revision 0 April 14,2014 Calculation & Casing Design Factors Beaver Creek Unit DATE: 04/24/2014 RECEIVED WELL: Beaver Creek#7A MAY 0 2 2014 FIELD: Beaver Creek DESIGN BY:Monty M Myers AOGCC Design Criteria: A`1�J Hole Size Mud Density: Hole Size 7-7/8" Mud Density: 9.0 ppg Hole Size Mud Density: Drilling Mode MASP: 3261 psi (See attached MASP determination &calculation) Production Mode MASP: 3261 psi (See attached MASP determination&calculation) Collapse Calculation: Section Calculation 1, 2 Normal gradient external stress (0.406 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 _ Casing OD 5-1/2" Top(MD) 0 Top(TVD) 0 Bottom (MD) 10,500 Bottom (TVD) 9,621 Length 10,500 Weight(ppf) 17 • Grade P110 Connection DWC/C Weight w/o Bouyancy Factor(lbs) 178,500 Tension at Top of Section(lbs) 178,500 Min strength Tension(1000 lbs) 546 Worst Case Safety Factor(Tension) 3.06 Collapse Pressure at bottom (Psi) 3,906 Collapse Resistance w/o tension(Psi) 7,480 Worst Case Safety Factor(Collapse) 1.91 MASP(psi) 3,261 ✓ Minimum Yield(psi) 10,640 Worst case safety factor(Burst) 3.26 Beaver Creek 7A Drilling Procedure " Rev 0 llilcorp Alaska,I.I.0 26.0 Casing Design Information Calculation &Casing Design Factors Beaver Creek Unit DATE:04/24/2014 WELL:Beaver Creek#7A ' FIELD:Beaver Creek DESIGN BY:Monty M Myers , Design Criteria: Hole Size ," d Density: Hole Size 7-7/8" ud Density: 9.0 ppg Hole Size ; Mud Density: Drilling Mode MASP: 3355 psi(See attached MAS• determination&calculation) Production Mode MASP: 3355 psi(See attached ASP determination&calculation) Collapse Calculation: Section Calculation 1, 2 Normal gradient external stre.s (0.406 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Spe ification 1 2 3 4 Casing oD 5-1/2" Top( D) 0 Top D) 0 \ 'Bot •m (MD) 10,500 B. om(1VD) 10,420 Length 10,500 Weight(ppf) 17 Grade P110 Connection DWC/C ei_ t w/o Bouyancy Factor(lbs) 178,500 nsion at Top of Section(lbs) 178,500 Lin strength Tension(1000 lbs) 546 orst Case Safety Factor(Tension) 3.06 a/ Collapse Pressure at bottom (Psi) 4,231 Collapse Resistance w/o tension(Psi) 7,480 Worst Case Safety Factor(Collapse) 1.77 MASP(psi) 3,355 Minimum Yield(psi) 10,640 Worst case safety factor(Burst) 3.17 Inge 36 Revision 0 April 14, 2014 II Maximum Anticipated Surface Pressure Calculation 7-7/8" Hole Section Hilcorp Beaver Creek#7A RECEIVED Kenai,Alaska MD TVD MAY 0 2 2014 Planned Top: 0 0 Planned TD: 10500' 9621 AOGCC Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad KOP 2,400 1050 Water 8.4 0.438 Sterling B1 4,926 2300 Water 9.0 0.467 Sterling B3 5,079 2300 Gas/Water 8.7 0.453 Sterling B4 5,237 2300 Gas/Water _ 8.4 0.439 Top Beluga B18 7,252 3300 Gas 8.8 0.455 Beluga B23 7,669 3500 Gas _ 8.8 0.456 Beluga B24 7,795 3500 Gas 8.6 0.449 Beluga B28B 8,104 3600 Gas 8.5 0.444 Beluga B30 8,226 3600 Gas 8.4 0.438 Tyonek 8,776 3710-, Gas 8.1 0.422 Total Depth 9,621 4225/i Gas 8.4 0.439 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date Beaver Creek 1B 9.2-9.9 ppg 5,200 10,900 2014 Beaver Creek 11 8.8-9.6 ppg 400 8,684 2003 Beaver Creek 13 8.5- 10.4 ppg 0 10,182 2003 Beaver Creek 14A 9.0-9.4 ppg 5,000 9,450 2014 Assumptions: 1. Maximum planned mud density for the 7-7/8" hole section is 9.5 ppg. 2. Calculations assume reservoirs contain 100%gas (worst case). 3. Calculations assume worst case event is complete evacuation of wellbore to gas. 4. Anticipated fracture gradient at 2400'TVD= 12.5 ppg EMW Fracture Pressure at 8-1/2" window considering a full column of gas from window to surface: 2400(ft)x 0.65(psi/ft)= 1560 psi 1560(psi)- [0.1(psi/ft)*2400(ft)]= 1320 psi MASP from pore pressure;entire wellbore evacuated to gas from TD 9621 (ft)x 0.439(psi/ft)= 4223 psi 4223(psi)- [0.1(psi/ft)*9621 (ft)]= 3261 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. Beaver Crek 7A II Drilling Procedure v0 Ililw.rp Alaska.1.1.1: 27.0 7-7/8" Hole Section MASP 111 Maximum Anticipated Surface Pressure Calculation RECEIVED - 7-7/8"Hole Section TR.,..,,,, Beaver Creek N7A MAY 0 1 2014 Kenai,Alaska MD ND AOGCC Planned Top: 0 0 Planned TD: 10500' 10402' Antiapated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad KOP 2,400 1050 Water 8.4 0.438 Sterling Bl 4,926 2300 Water 9.0 0.467 Sterling B3 5,079 2300 Gas/Water _ 8.7 0.453 SterlingB4 5,237 2300 . Gas/Water 8.4 0.439 Top Beluga B18 7,252 i 3300 Gas 8.8 0.455 Beluga B23 7,669 3500 Gas _ 8.8 0.456 Beluga B24 7,795 3500 Gas 8.6 0.449 Beluga B28B 8,104 3600 Gas 8.5 0.444 Beluga B30 8,226 3600 Gas 8.4 0.438 Tyonek 8, 76 3700 Gas 8.1 0.422 Total Depth 10,420 4400 Gas 8.1 0.422 Offset Well Mud Densities Well MW range Top(ND) Bottom(ND) Date Beaver Creek 1B_ 9.2-9.9ppg 5,200 10,900 2014 BeaverCreekll 8.8-9.6ppg 400 8,684 2003 Beaver Creek 13 8.5-10.4ppg 0 10,182 2003 Beaver Creek 14A 9.0-9.4 ppg 5,000 9,450 2014 Assumptions: /' 1. Maximum planned mud density for the 7-7/8"hole section is 9.5 ppg. C.,' 2. Calculations assume reservoirs contain 100%gas(worst case). 3. Calculations assume worst case event is complete evacuation of wellbore to gas. 4. Anti ci pate,fracture gradient at 5100'ND=15.5 ppg EMW j Fracture ssu a at 8-1/2"window considering a full column of gas from window to surface: " `, 2400(ft)x 0.65(psi/ft)= 1560 psi 1560(psi)-[0.1(psi/ft)'2400(ft)]= 1320 psi r/ from pore pressure;entire wellbore evacuated to gas from TD I\ ,\ • C. 10420(ft)x 0.422(psi/ft)= 4397 psi jd 4397(psi)-[0.1(psi/ft)*10420 ft I= 3355 psi Summary: 1. MASP while drilling 7-7/8"production hole is governed by SI BHP minus entire wellbore evacuated to gas from TD. 2. MASP during production mode isgovemed by SI BHP minus entire wellbore evacuated to gas from TD. Page 37 Revision 0 April 14,2014 Beaver Creek 7A II Drilling Procedure Rev 0 llikwrp Alaska,11.1.0 27.0 7-7/8" Hole Section MASP II Maximum Anticipated Surface Pressure Calculation 7-7/8"Hole Section7 ° ""° Beaver Creek#7A Kenai,Alaska MD TVD Planned Top: 0 0 Planned TD: 10500' 10402' Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad KOP 2,400 2300 Water 18.4 0.958 Sterling Bl 4,926 2300 Water 9.0 0.467 Sterling B3 5,079 2300 Gas/Water 8.7 0.453 Sterling B4 5,237 2300 Gas/Water 8.4 _ 0.439 Top Beluga B18 7,252 3300 Gas 8.8 0.455 Beluga B23 7,669 3500 Gas 8.8 0.456 Beluga B24 7,795 3500 Gas 8.6 _ 0.449 Beluga B28B 8,104 3600 Gas 8.5 0.444 Beluga B30 8,226 3600 Gas 8.4 _ 0.438 Tyonek 8,776 3700 Gas 8.1 _ 0.422 Total Depth 10,420 4400 Gas 8.1 0.422 Offset Well Mud Densities Well MW range Top(ND) Bottom(ND) Date Beaver Creek 1B 9.2-9.9ppg , 5,200 10,900 2014 Beaver Creek 11 8.8-9.6ppg 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 Assumptions: 1. Maximum planned mud density for the 7-7/8"hole section is 9.5 ppg. 2. Calculations assume reservoirs contain 100%gas(worst case). 3. Calculations assume worst case event is complete evacuation of wellbore to gas. 4. Anticip`-ed fracture gradient at 5100'ND=15.5 ppg EMW F ressure at 8-1/2"window considering a full column of gas from window to surface: r i?/ iJ \ 2400(ft)x 0.65(psi/ft)= 1560 psi /_) -7-1 \� 1560(psi)-[0.1(psi/ft)*2400(ft)]= 1320 psi MASP from pore pressure;entire wellbore evacuated to gas from TD vdct 10420(ft)x 0.422(psi/ft)= 4397 psi 4397(psi)-[0.1(psi/ft)*10420(ft)]= 3355 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 April 14,2014 Beaver Creek 7A ti 1-- - Drilling Procedure Rev 0 Hilcorp Alaska,I.I.0 28.0 Surface Plat (As Built) (NAD 27) act, 1 sECtIQN 38 UN R1 PAO No 1-A 9{ .._.._..... , , •.-..TT 1.R7i�114.,�_..—.,.-..,..........�.._. ,. - ._.._.._...,. ..... _..--,.,. ..._......,.�.._....,-�,.�....... Th$"` N:242 12,I ',.- glism, NOT S . I 1) BASIS OF GEODETIC CONTROL ANDNADB1 POSITION(EPOCH 2003)Is AN OPUS SOLUTION FROM NGS COORDINATES I STATIONS'MEM CORS ARP','TLKA I TALKEETNA DORS ARP,AND"POT3 POTATO 1 POINT 3 AAP'TO ESTABLISH THE POSITION OF FACT POI.THE GEODETIC POSITION OF EC1 I WAS DETERMINED TO HAVE A LATITUDE OF i 43860.0277rN AND A LONGITUDE OF i AS-BUILT WELL gz 151'02"22,30411°W.THE ALASKA STATE PLANE ECU 7 COORDINATES(ASP)ZONE 4 ARE I N:2423177.429° N=2425933.534 i E:31371)5,481` E.14.53661.085 i LAT:6OP 38'32.408"N ELEV,131.31'(NAVD ) i I LONG:•161"OZ 16.440'W 2) BASIS OF VERTICAL CONTROL IS NGS 814 trey} ASP ZONE 4 NAD37 PID 170508 LOCATED WITHIN THE KENAI SPUR g!o FEL=2033° HIGHWAY RIGHT OF WAY AT MILE POST 3.75 a I i FNL=1783 HAVING AN ELEVATION OF 16455 FEET NAVD z ELEV=126.94'(NAVOBB) 88 ACCORDING TO NOS PUBLISHED DATA. ti•I g SECTION 4.TON,R1OW,SM,AK 3} COORDINATES CONVERTED TO NAD27 USING a i z CORPSCON6 CONVERSION SOFTWARE .o uV1 _.. . Ju FEL i PAD N[,.7. • SEC:II[31i 4 TEN MM.5.M„AK I s I 1 I i i i ��V1\III i "*.1.419314.*I-lie T - 7 .0 p � X y�y�^ ' • 1IRAli ltj�mama}1 ! ♦if _..°..• i j fiAl' rrao��4.. t `SCALE _. i BCU #7 WELL AS=BUILT SURFACE LOCATION ,i (NAD27) BEAVER CREEK UNIT PAD 7 ENGINEERING x TESTINGOAI ION:SECTION 4, TOWNSHIP NORTH, . / SURVEYING-MA INC RANGE 10 WEST,SEWARD MERIDIAN ALASKA Wimplfurka,Gl.i: (/ PD.BOX 408 SCIM. TF,tA,AK.MN ) 6JOB No. 143035 voice;(807)283-4218 FAX.(947)2B3-32265 DRAWN BY big VVINVW,hicA.ANECG.GQM BGB DATE:3/27114 FIGURE I Page 38 Revision 0 April 14, 2014 Beaver Creek 7A Drilling Procedure Rev 0 lrilcorp Alaska.1.1.1: 29.0 Surface Plat (As Built) (NAD 83) 6Cu i sFCTION33 T7N REM PAD Na.I.A tiii'a"ti."iiiSNi. .. .._..�.,,._,,... �33 54 I+g.atTeh.-6 4:.37".r E::43,37511.43 NOTES II BASIS OF GEODETIC CONTROL AND NAD$3 POSITION(EPOCH 2003)IS AN OPUS SOLUTION FROM NGS COORDINATES STATIONS'KEN1 CORE ARP".`TWA TALKEETNA CORS ARP',AND`POTS POTATO POINT 3 ARP"TO ESTABLISH THE POSITION OF MCI BC I.THE GEODETIC POSITION OF BC 1 WAS DETERMINED TO HAVE A LATITUDE OF 60`6'53.82777'N AND A LONGITUDE OF i<_ 151"02'213031'i'W,THE ALASKA STATE PLANE COORDINATES(ASP)ZONE 4 ARE AS-BUILT WELL N=2420933334 BCU 7 E'=1453463,065 N:2427838_457' ELEV.t31.31'()AVD88) E:1453724.064` LAT:SO"38'30.358"N 2)BASIS OF 8 VERTICAL OL NGS EM i � PID TT#�i08 LOCATED WITHIN THE)SEN#I SPUR �i ' LONG:-151 D2'24.458"4'1 HIGHWAY RIGHT OF WAY AT MILE POST am ASP ZONE 4 NAD83 HAVING AN ELEVATION OF 164.55 FEET NAVD ,rc FEL=2033' 88 ACCORDING TONGS PUBLISHED DATA. z FNL '1783" _ - -.....,.1 °X ELEV-4 126.84'(NAVD85) ''i M SECTION 4,TSN,R1OW,SM,AK l 6 1111 i P ECU - FEL i PAD Na 1 SECRRaN 4 TEN RIM 9.M...AR 1 I i 1 1 V,.......0,1%%11. `.*I .tt 444 4 1 ti, /lir T'')„ I ..*1491 °0 NORTH '- i 1, ^moo w IiuWC l : '' I !r \+Js'r l,/ i lf G 4G', 1 14t1j I i BCU #7 WELL AS-BUILT SURFACE LOCATION 1 (NAD83) BEAVER CREEK UNIT PAD 7 lit ENGINEERING.TESTING LOCATION;SECTION 4, TOWNSHIP 8 NORTH.. SURVEYING-tAAPF'ING RANGE 10 WesT.SEWARD MERIDIAN ALASKA 11i1ivir i m„,1„,IJ.(: ( y P.Q.84X 468 i ... ..._...................... .... . SOLDOTNA.AK.85668 JOB NO. 143035 VOICE:(907)263 1216 FAX:(007)283-3286 DRAWN BY [.rnuttirpinc +MW.MS .ANECG,COM BGB DATE:3127114 FIGURE: 1 Page 39 Revision 0 April 14,2014 Hilcorp Energy Company Beaver Creek Unit Beaver Creek Unit Beaver CK Unit 7 BCU-07A Plan: BCU-07A wp2a Standard Proposal Report 29 April, 2014 me -110 HALLIBURTON MIK ,4111111111111111111E 111111111111111111111 Sperry Drilling Services MALLIBURTON Projee-` Beaver Creek Unit 11=3 Site: Beaver Creek Unit Sperry Drilling Well: BeaverBCU-07A CK Unit 7 Wellbore: SECTION DETAILS BCU-07A wp2a Sec MD Inc Azi TVD +NI-S +E/-W Dleg TFace VSect Target 1 2400.00 0.00 0.00 2400.00 0.00 0.00 0.00 0.00 0.00 CASING DETAILS 2 2420.00 2.40 0.00 2419.99 0.42 0.00 12.00 0.00 0.09 3 2440.00 2.40 0.00 2439.98 1.26 0.00 0.00 0.00 0.26 TVD MD Name Size 4 3005.40 28.69 77.75 2981.45 42.73 135.39 5.00 82.11 141.32 2400.00 2400.00 9 5/8"TOW 9-5/8 5 7153.64 28.69 77.75 6620.41 465.18 2081.51 0.00 0.00 2132.75 9731.37 10500.00 51/2" 5-1/2 6 7187.09 27.95 79.18 6649.86 468.36 2097.05 3.00 138.28 2148.62 7 8830.40 27.95 79.18 8101.51 612.97 2853.53 0.00 0.00 2918.62 8 9595.37 5.00 78.16 8830.19 654.02 3065.07 3.00 -179.77 3134.07 9 9645.37 5.00 78.16 8880.00 654.91 3069.33 0.00 0.00 3138.43 BCU 07A BHL Tgt 10 10500.00 5.00 78.16 9731.37 670.20 3142.23 0.00 0.00 3212.91 750- WELL DETAILS: Beaver CK Unit 7 Ground Level: 125,00 +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 2428177.43 313703.81 60.6423350 -151.0378960 1500- 9 5/8"TOW Hilcorp Energy Company _ II20" Start Build 12.00 Calculation Method: Minimum Curvature - 20 d _--__ Error System:ISCWSA 2250- ----" Scan Method: Closest Approach 3D Error Start 20.00 hold at 2420.00 MD Surface: Elliptical Conic Warning Method: Error Ratio 3000- Start DLS 5.00 TFO 82.11 REFERENCE INFORMATION Co-ordinate(N/E)Reference: Well Beaver CK Unit 7,True North Vertical(TVD)Reference: BCU-07A @ 143.00usft Measured Depth Reference: BCU-07A @ 143.00usft 3750- Calculation Method: Minimum Curvature Start 4148.24 hold at 3005.40 MD FORMATION TOP DETAILS 4500- TVDPath MDPath Formation 4925.00 5220.95 B1 5078.00 5395.36 B3 B3-- 5236.00 5575.48 B4 o 5250- 7251.00 7867.60 B18 0 I B4 7668.00 8339.65 B23 d7794.00 8482,29 B24 13 3/8's s 8103.00 8832.08 B28B _ 8225.00 8967.69 B30 Q 6000- 8775.00 9539.90 Tyonek crtsi Start DLS 3.00 TFO 138.28 Start 1643.31 hold at 7187.09 MD 1 6750- 13 2 F= - B18-- ____TPH at 7874'MD,7252'TVD 7500- B23- B24" _Start DLS 3.00 TFO-179.77 8250- 1328B- 8250- B30 ___Start hold at 9595.37 MD 9000- Tyonek 5 1/2"_ _ TD at 10500.00 9750- - V BCU-07A wp2a 10500- - 11250- - 0500- 11250- - SURVEY PROGRAM Date:2014-04-29T00:00:00 Validated:Yes Version: 12000- Depth From Depth To Survey/Plan Tool 96.00 2400.00 BCU 7(BCU 7) Unknown 2400.00 2700.00 BCU-07A wp2a(BCU-07A) MWD_Interp Azi 2700.00 10500.00 BCU-07Awp2a(BCU-07A) MWD+SC+sag 111111111111111111111111111111111111111111111 1111 1 -3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 L I `Y?L Q 0 N.J.,_ r ON - O O __,N Cb N. 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H I- 20)202 _ o CO C c�ta O "-- .N�. o Ot cmi°� OM Q Z 5WmW..co C4 - c a o U A�+ _� oc U c'3 a+ - vo co ..i _- a to I- _1 - O 2 °O m E .4., o N 0t = r L H m —, 'y Z00) ON�NN NMS p - ti Q 000NM1�,Ot0OVo p m 0 0 0 N m m a m N M I Mao)-.-N m —CO O MM CN NNNj d Cu ko O\ promi 4000.-ONON00 + O - - 0000.-oryonoo 0.,,-,+ ,000000000 3S(+n (Ni I ~ CO _ 0 0❑ N O 00 _o .c o c O 00000000000 / � m0000000000 > Fo-2�� / - 5o�o00oiorioo / d' Q - t o o J OOOQ)�10Mn MM i : Cr" O b 000M 000100 MN } 1:::: �OOOM mrn06(M0(00a "C3 / 1-En p 0iii + N N N C'))CC')M < t / / ~ (N - Z 2 vA O CnoNcomm0NN,-o O > QQ / // N -o OV'NINrC000)N CO w f0orv-66Novon a oo b - ,// Co a,r66mO 0 / / ' .0 - O i� Y 0 UU / / /i -N p00)min�m�won CO o mm / // o CO >ornrnav03u�,-ocO 2 o m m / / '/ p © J-6a; Ornroov- O n N N / N = o r M m NNNN00ctom0 CO m CCV Q. 3 / / _o NNNN pm r 3 "14 oL _000nnmmo ° m a nno �nOO a » / / / . op DC 0oonnnNnnn Z0 N (nmmm 414 _// 0 _- cA 000000)1000000 l� _O . COVm 00)07000 0 0 0 0 NNNN J 1_ - WI 00000 a0)OnnO N N 0 r M N —a on 1L .,OOOa moo'coo 0 V] - J © OJo rin0 no r i O 0010 COm10 Co a aa0,-,-WOCO00 J E000 en NNNMnnm00)O LW m o 01 I I I I I I I I I I I I I I I I 1 1 11 I I I I I I I I I I I I I I I I I I I I I I ! WI : M Q R{ N M a N CO n m O O N N N b O a 000 N 0 0 0 N l� a 0) co b eF M M I (unTsn OOb)(+)LI oN/(-)qinoS Halliburton HALLIBURTONi Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 7 Company: Hilcorp Energy Company TVD Reference: BCU-07A @ 143.00usft Project: Beaver Creek Unit MD Reference: BCU-07A @ 143.00usft . Site: Beaver Creek Unit North Reference: True • Well: Beaver CK Unit 7 Survey Calculation Method: Minimum Curvature • Wellbore: BCU-07A Design: BCU-07Awp2a 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 7 Well Position +N/-S 0.00 usft Northing: 2,428,177.43 usft • Latitude: 60.6423350 +EI-W 0.00 usft Easting: 313,703.81 usft ' Longitude: -151.0378960 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: • 125.00 usft Wellbore BCU-07A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2013 6/30/2014 16.96 73.62 55,457 Design BCU-07A wp2a Audit Notes: Version: Phase: PLAN Tie On Depth: 2,400.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 77.96 Plan Sections Measured Vertical TVD 2::::J Dogleg Build Turn Depth Inclination Azimuth Depth System' +NI-S +EI-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 2,400.00 0.00 0.00 2,400.00 2,257.00 0.00 0.00 0.00 0.00 0.00 0.00 2,420.00 2.40 0.00 2,419.99 2,276.99 0.42 0.00 12.00 12.00 0.00 0.00 2,440.00 2.40 0.00 2,439.98 2,296.98 1.26 0.00 0.00 0.00 0.00 0.00 3,005.40 28.69 77.75 2,981.45 2,838.45 42.73 135.39 5.00 4.65 13.75 82.11 7,153.64 28.69 77.75 6,620.41 6,477.41 465.18 2,081.51 0.00 0.00 0.00 0.00 7,187.09 27.95 79.18 6,649.86 6,506.86 468.36 2,097.05 3.00 -2.22 4.26 138.28 8,830.40 27.95 79.18 8,101.51 7,958.51 612.97 2,853.53 0.00 0.00 0.00 0.00 9,595.37 5.00 78.16 8,830.19 8,687.19 654.02 3,065.07 3.00 -3.00 -0.13 -179.77 9,645.37 5.00 78.16 8,880.00 8,737.00 654.91 3,069.33 0.00 0.00 0.00 0.00 10,500.00 5.00 78.16 9,731.37 9,588.37 670.20 3,142.23 0.00 0.00 0.00 0.00 4/29/2014 2:13:28PM Page 2 COMPASS 5000.1 Build 70 e 2 • • u 0 5 H nill I 3 W wd 9 CD Hi et c . 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I N N ▪ L V I, 00 T T O ee N N M et v1 v1 /0 VD 'D N 00 0o T T T O O - N M et Ul v1 '0 '.0 N N 00 T co ..m N M et F 1D VD b VD \D N N N I's C N [- N N N t- N N N N N N N N 00 00 00 00 00 00 00 00 00 00 00 00 00 00 T T T T T = o v) N In v1 U) In v1 v) v) In In Ir'1 I'. v):Ir'1 Irl et I- et v1 N In v) In In v1'un v) v) v1 Co'1 h In U) v) Cr'. �n v1 In I'. v1 In-.F. n of 00 C co I` Ir I` I\ r r I r I` I` I` I` !` I` r- I` I` I` r I` I` I` p N V V In vi vi In vi In vi vi vi vi 'r Ir'I Ir) vi vi vi et 7 <t 7 et Ti '0 4 Ti et et of R 7 et 4 14 7 Ti Ti et Ti et N N C') 841 v) et U) v) c c ^ c c C C 0 0 0 0 0 0 o c c c C O o - e O O N N N N N N N N Cl N N N N N et et v) et - C 0 0 0 0 0 0 0 0 O O O O C D -- M O t I` et et eet et et et 4 ' 4 4 Ti et et M6 T N 41 In V> vi 41 41 41 41 41 41 v1 v1 v1 vl .4-; IrIn In In Ul Un l , ) I 4 ' N N O O O T O O O O M O O O O 41 O I M 0 0 0 0 0 0 I- O N O O O O C N C N O N O o O o C C 0 - O O O v'1 O O O '0 '0 O O O O [, O I N 00 O O et o N V c - O O O O C M O N O VD C O C O O O O o 0 0 0 et 0 O O CV t+1 0 0 0 C N C IN Ti O O C C 6 — C a; O O O C O v) © C \0 O C O O O O O C C O O O T O O O O O 0 O O O el 0''D r` O O M O N 00 O 0' O O O O O T O WI O U) O o 0 0 0 0 0 0 vV N 00 00 T O - - e. N M et v1 U) 'D '0 '.D N 00 00 T T T C C - N M et v).In 1a VD N N 00 T O - N M et Ire r N tN tN tN 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 T T T T T T TIT T T T T T T O 0 0 0 0 0 x _ y 00 T O N M et un 1D N 00 T O 71 N M et 41 'D r` 00 T O .- Nen et In V t` 00 T O N en et Ul VD N 00 T O i 00 00 T T T T T T T T T T CO 0 0 0 0 0 0 0 0 0 N N N N N N N N N N M v Halliburton HALLI B U RTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 7 Company: Hilcorp Energy Company TVD Reference: BCU-07A @ 143.00usft Project: Beaver Creek Unit MD Reference: BCU-07A @ 143.00usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 7 Survey Calculation Method: Minimum Curvature Wellbore: BCU-07A Design: BCU-07Awp2a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E1-W Northing Easting DLS Vert Section (usft) (°) (•) (usft) usft (usft) (usft) (usft) (usft) 2,257.00 2,400.00 0.00 0.00 2,400.00 2,257.00 0.00 0.00 2,428,177.43 313,703:1 0.00 0.00 Start Build 12.00-9 5/8"TOW _ 2,420.00 2.40 0.00 2,419.99 2,276.99 0.42 0.00 2,428,177.85 31 , 03.82 12.00 0.09 Start 20.00 hold at 2420.00 MD 2,440.00 2.40 0.00 2,439.98 2,296.98 1.26 0.00 2,428,178.69 313,703.83 0.00 0.26 Start DLS 5.00 TFO 82.11 2,500.00 4.09 46.62 2,499.89 2,356.89 3.98 1.56 2,428,181.39 313,705.43 5.00 2.35 2,600.00 8.66 66.29 2,599.25 2,456.25 9.46 11.05 2,428,186.7- 313,715.00 5.00 12.78 2,700 00 13.54 72.17 2,697.36 2,554.36 16.08 29.09 2,428,193 45 313,733.15 5.00 31.81 2,800.00 18.48 74.97 2,793.45 2,650.45 23.78 55.55 2,428,2'8.33 313,759.73 5.00 59 29 2,900.00 23.44 76.61 2,886.81 2,743.81 32.50 23 2,428 08.50 313,794.54 5.00 95 03 3,000.00 28.42 77.70 2,976.71 2,833.71 42.18 2. 2,4 ;,217.51 313,837.32 5.00 138.74 3,005.40 28.69 77.75 2,981.45 2,838.45 42.73 13 2 '28,218.02 313,839.85 5.00 141.32 Start 4148.24 hold at 3005.40 MD 3,100.00 28.69 77.75 3,064.44 2,921.44 52.3617 2,428,226.95 313,884.38 0.00 186.73 3,200.00 28.69 77.75 3,152.16 3,009.16 62.55 26.68 2,428,236.39 313,931.45 0.00 234.74 3,300.00 28.69 77.75 3,239.88 3,096.88 72.73 273 59 2,428,245.83 313,978.52 0.00 282.75 3,400.00 28.69 77.75 3,327.61 3,184.61 82.92 . 320. 2,428,255.27 314,025.59 0.00 330.75 3,500.00 28.69 77.75 3,415.33 3,272.33 93. 0 367 42 2,4 8,264.72 314,072.66 0.00 378.76 3,600.00 28.69 77.75 3,503.05 3,360.05 103 4 4.34 2,42 74.16 314,119.73 0.00 426.77 3,700.00 28.69 77.75 3,590.78 3,447.78 r .47 61.25 4 ,283.60 314,166.80 0.00 474.77 3,800.00 28.69 77.75 3,678.50 3,535.50 3.65 508.17 2,28,293.04 314,213.87 0.00 522.78 3,900.00 28.69 77.75 3,766.22 3,623.22 133.84 555.08 2,428,302.48 314,260.93 0.00 570.79 4,000.00 28.69 77.75 3,853.94 3,710.94 144.02 602.00 2,428,311.93 314,308.00 0.00 618.79 4,100.00 28.69 77.75 3,941.67 3,798.67 . 4.20 648.91 2,428,321.37 314,355.07 0.00 666.80 4,200.00 28.69 77.75 4,029.39 3,88 .3 "" t 4. 8 695.82 2,428,330.81 314,402.14 0.00 714.81 4,300.00 28.69 77.75 4,117.11 3,97 .1 174,1.57 742.74 2,428,340.25 314,449.21 0.00 762.81 4,400.00 28.69 77.75 4,204.84 4,061. 184.7 . 89.65 2,428,349.69 314,496.28 0.00 810.82 4,500.00 28.69 77.75 4,292.56 4,149 194.94 836.57 2,428,359.14 314,543.35 0.00 858.83 4,600.00 28.69 77.75 4,380.28 4,23 8 205.12 % 883.48 2,428,368.58 314,590.42 0.00 906.83 4,700.00 28.69 77.75 4,468.01 4,325.01 215.31 ' 930.40 2,428,378.02 314,637.49 0.00 954.84 4,800.00 28.69 77.75 4,555.73 4,412.73 225.49 977.31 2,428,387.46 314,684.56 0.00 1,002.85 4,900.00 28.69 77.75 4,643.45 4,500.45 235.67 ,024.23 2,428,396.90 314,731.63 0.00 1,050.86 5,000.00 28.69 77.75 4,731.17 4,588.17 245.86 1,071.14 2,428,406.35 314,778.70 0.00 1,098.86 5,100.00 28.69 77.75 4,818.90 4,675.90 256.04 1,118.05 2,428,415.79 314,825.77 0.00 1,146.87 5,200.00 28.69 77.75 4,906.62 4,763.62 266.23 1,164.97 2,428,425.23 314,872.84 0.00 1,194.88 5,220.95 28.69 77.75 4,925.00 4,782.00 268.36 1,174.80 2,428,427.21 314,882.70 0.00 1,204.93 B1 5,300.00 28.69 77.75 4,994.34 4,851.34 276.41 1,211.88 2,428,434.67 314,919.91 0.00 1,242.88 5,395.36 28.69 77 75 5,078.00 4,935.00 286.12 1,256.62 2,428,443.68 314,964.79 0.00 1,288.66 B3 5,400.00 28.69 77.75 5,082.07 4,939.07 286.59 1,258.80 2,428,444.11 314,966.98 0.00 1,290.89 5,500.00 28.69 77.75 5,169.79 5,026.79 296.78 1,305.71 2,428,453.56 315,014.04 0.00 1,338.90 5,575.48 28.69 77.75 5,236.00 5,093.00 304.46 1,341.12 2,428,460.68 315,049.57 0.00 1,375.13 B4 4/29/2014 2:13:28PM Page 3 COMPASS 5000.1 Build 70 Halliburton HALLI B U RTO N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 7 Company: Hilcorp Energy Company ND Reference: BCU-07A @ 143.00usft Project: Beaver Creek Unit MD Reference: BCU-07A @ 143.00usft / Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 7 Survey Calculation Method: Minimum Curvature Wellbore: BCU-07A Design: BCU-07A wp2a 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) 5,114.51 5,600.00 28.69 77.75 5,257.51 5,114.51 306.96 1,352.63 2,428,463.00 31:,061.11 0.00 1,386.90 5,700.00 28.69 77.75 5,345.24 5,202.24 317.15 1,399.54 2,428,472.44 .15,108.18 0.00 1,434 91 5,800.00 2869 77.75 5,432.96 5,289.96 327.33 1,446.46 2,428,481.88 315,155.25 0.00 1,482.92 5,900.00 28.69 77.75 5,520.68 5,377.68 337.51 1,493.37 2,428,491.32 315,202.32 0.00 1,530.92 6,000.00 28.69 77.75 5,608.40 5,465.40 347.70 1,540.28 2,428,500.77 315,24939 0.00 1,578.93 6,100.00 28.69 77.75 5,696.13 5,553.13 357.88 1,587.20 2,428,510 1 315,296.46 0.00 1,626.94 6,200.00 28.69 77.75 5,783.85 5,640.85 368.07 1,634.11 2,428,5 '.65 315,343.53 0.00 1,674.94 6,300.00 28.69 77.75 5,871.57 5,728.57 378.25 1,681.03 2,42:, 29.09 315,390.60 0.00 1,722.95 6,400.00 28.69 77.75 5,959.30 5,816.30 388.43 1,727.94 2, 8,538.53 315,437.67 0.00 1,770.96 6,500.00 28.69 77.75 6,047.02 5,904.02 398.62 1,774.86 ,428,547 97 315,484.74 0.00 1,818.96 6,600.00 2869 77.75 6,134.74 5,991.74 408.80 1,821.77 2,428,557.42 315,531.81 0.00 1,866.97 6,700.00 28.69 77.75 6,222.47 6,079.47 418.99 1,868.68 2,428,566.86 315,578.88 0.00 1,914.98 6,800.00 28.69 77.75 6,31019 6,167.19 429.17 1,915.60 2,428,576.30 315,625.95 0.00 1,962.98 6,900.00 2869 77.75 6,397.91 6,254.91 439.35 1,962.-1 2,428,585.74 315,673.02 0.00 2,010.99 7,000.00 28.69 77.75 6,485.63 6,342.63 449.54 2,00-.43 2,428,595.18 315,720.09 0.00 2,059.00 7,100.00 28.69 77.75 6,573.36 6,430.36 459.72 2,' 6.34 2,428,604.63 315,767.15 0.00 2,107.00 7,153.64 28.69 77.75 6,62041 6,477.41 465.18 ,081.51 2,428,609.69 315,792.40 0.00 2,132.75 Start DLS 3.00 TFO 138.28 7,187.09 27.95 79.18 6,649.86 6,506.86 468 36, 2,097.05 2,428,612 62 315,808.00 3.00 2,148.62 Start 1643.31 hold at 7187.09 MD 7,200.00 27.95 79.18 6,66126 6,518.26 469. 0 2,103.00 2,428,613.66 315,813.96 0.00 2,154.67 7,300.00 27.95 79.18 6,749 60 6,606.60 47 .30 2,149.03 2,428,621.73 315,860.12 0.00 2,201.53 7,400.00 27.95 79.18 6,837.94 6,694.94 487.10 2,195.06 2,428,629.81 315,906.29 0.00 2,248.38 7,500.00 27.95 79.18 6,926 27 6,783.27 /495.90 2,241.10 2,428,637.88 315,952.46 0.00 2,295.24 7,600.00 27.95 79.18 7,014.61 6,871.61 ' 504 70 2,287.13 2,428,645.95 315,998.62 0.00 2,342.10 7,700.00 27.95 79.18 7,102.95 6,959.95 513.50 2,333.17 2,428,654.02 316,044.79 0.00 2,388.95 7,800.00 27.95 79.18 7,191.29 7,048.2g 522.30 2,379.20 2,428,662.10 316,090.96 0.00 2,435.81 7,867.60 27.95 79.18 7,251.00 7,108.00 528.24 2,410.32 2,428,667.55 316,122.17 0.00 2,467.48 B18 7,868.73 27.95 79.18 7,252.00 7,109.00 528.34 2,410.84 2,428,667.64 316,122.69 0.00 2,468.01 TPH at 7874'MD,7252'TVD 7,900.00 27.95 79.18 7,279.62 7,136.62 531.10 2,425.23 2,428,670.17 316,137.13 0.00 2,482.67 8,000.00 27.95 79.18 7,367.96 7,224.96 539.90 2,471.27 2,428,678.24 316,183.29 0.00 2,529.52 8,100.00 27.95 79.18 7,456.30 7,313.30 548.70 2,517.30 2,428,686.31 316,229.46 0.00 2,576.38 8,200.00 27.95 79.18 7,544.63 7,401.63 557.50 2,563.33 2,428,694.38 316,275.63 0.00 2,623.24 8,300.00 27.95 79.18 7,632.97 7,489.97 566.30 2,609.37 2,428,702.46 316,321.79 0.00 2,670.09 8,339.65 27.95 79.18 7,668.00 7,525.00 569.78 2,627.62 2,428,705.66 316,340.10 0.00 2,688.67 1323 8,400.00 27.95 79.1.8 7,721.31 7,578.31 575.09 2,655.40 2,428,710.53 316,367.96 0.00 2,716.95 8,482.29 27.95 79.18 7,794 00 7,651.00 582.34 2,693.28 2,428,717.17 316,405.95 0.00 2,755.51 B24 8,500.00 27.95 79.18 7,809 65 7,666.65 583.89 2,701.44 2,428,718.60 316,414.13 0.00 2,763.81 8,600.00 27.95 79.18 7,897.98 7,754.98 592.69 2,747.47 2,428,726.67 316,460.29 0.00 2,810.66 8,700.00 27.95 79.18 7,986.32 7,843.32 601.49 2,793.50 2,428,734.74 316,506.46 0.00 2,857.52 8,800.00 27.95 79.18 8,074.66 7,931.66 610.29 2,839.54 2,428,742.82 316,552.63 0.00 2,904.38 4/29/2014 2:13:28PM 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 7 Company: Hilcorp Energy Company TVD Reference: BCU-07A @ 143.00usft Project: Beaver Creek Unit MD Reference: BCU-07A @ 143.00usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 7 Survey Calculation Method: Minimum Curvature Wellbore: BCU-07A Design: BCU-07Awp2a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Fasting DLS Vert Section (usft) (•) (•) (usft) usft (usft) (usft) (usft) (usft) 7,958.51 8,830.40 27.95 79.18 8,101.51 7,958.51 612.97 2,853.53 2,428,745., 316,566.66 0.00 2,918.62 Start DLS 3.00 TFO-179.77 8,832.08 27.90 79.18 8,103.00 7,960.00 613.12 2,854.31 2,428, '5.41 316,567.44 3.00 2,919.41 B28B 8,900.00 25.86 79.16 8,163.58 8,020.58 618.89 2,884.46 2,, 8,750.70 316,597.68 3.00 2,950.11 8,967.69 23.83 79.14 8,225.00 8,082.00 624.24 2,912.39 ,428,755.61 316,625.70 3.00 2,978.54 B30 9,000.00 22 86 79.13 8,254.66 8,111.66 626.66 2,924.97 2,428,757.83 316,638.31 3.00 2,991.34 9,100 00 19.86 79.08 8,347.78 8,204 78 633.54 2,960.73 2,428,764.14 316,674.17 3.00 3,027.75 9,200.00 16.86 79.03 8,442.68 8,299.68 639.52 2,991.•• 2,428,769.63 316,705.19 3.00 3,059 24 9,300.00 13.86 78.95 8,539.10 8,396.10 644.58 3,017.5 2,428,774.28 316,731.26 3 00 3,085.72 9,400.00 10.86 78.82 8,636.77 8,493.77 648.70 3,0 :.65 2,428,778.07 316,752.33 3 00 3,107.13 9,500.00 786 78.61 8,735.43 8,592.43 651.88 3 454.60 2,428,781.00 316,768.33 3.00 3,123.39 9,539.90 6.66 78.47 8,775.00 8,632.00 652.88 :,059.55 2,428,781.92 316,773.28 3.00 3,128.43 Tyonek 9,595.37 5.00 78.16 8,830.19 8,687.19 654.02 3,065.07 2,428,782.97 316,778.82 3.00 3,134.07 Start hold at 9595.37 MD 9,600.00 5.00 78.16 8,834.80 8,691.80 654. 0 3,065.46 2,428,783.05 316,779.22 0.00 3,134.47 9,645.37 5.00 78.16 8,880.00 8,737.00 65'.91 3,069.33 2,428,783.80 316,783.10 0.00 3,138.43 9,700.00 5.00 78.16 8,934.42 8,791.42 •.5.89 3,073 99 2,428,784.70 316,787.77 0.00 3,143.19 9,800.00 5.00 78.16 9,034.04 8,891.04 •57.68 3,082.52 2,428,786.36 316,796.33 0.00 3,151.90 9,900.00 5.00 78.16 9,133.66 8,990.66 659.47 3,091.05 2,428,788.01 316,804.89 0.00 3,160.62 10,000 00 5.00 78.16 9,233.28 9,090.28 661.25 3,099.58 2,428,789.66 316,813.45 0.00 3,169.33 10,100.00 5.00 78.16 9,332.90 9,189.90 663.04 3,108.11 2,428,791.32 316,822 00 0.00 3,178.05 10,200.00 5.00 78.16 9,432.51 9,289.5 664.83 3,116.64 2,428,792.97 316,830 56 0.00 3,186.76 10,300.00 5.00 78.16 9,532.13 9,389. 3 666.62 3,125.17 2,428,794.62 316,839.12 0.00 3,195.48 10,400.00 5.00 78.16 9,631.75 9,48:.75 668.41 3,133.70 2,428,796.28 316,847.68 0.00 3,204.19 , 10,500.00 5.00 78.16 9,731.37 9,58.37 670.20 3,142.23 2,428,797.93 316,856.23 0.00 3,212.91 TD at 10500.00-5 1/2" / Targets tr Target Name / -hit/miss target t9ip Angle Dip Dir. TVD +N/-S +EI-W Northing Fasting -Shape (1 (1 (usft) (usft) (usft) (usft) (usft) BCU 07A BHL Tgt 0.00 0.00 8,880.00 654.91 3,069.33 2,428,783 80 316,783.10 -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (1 (") 2,400.00 2,400.00 9 5/8"TOW 9-5/8 12-1/4 10,500.00 9,731.37 5 1/2" 5-1/2 7-7/8 4/292014 2:13:28PM Page 5 COMPASS 5000.1 Build 70 Halliburton HALLIBLiRTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 7 Company: Hilcorp Energy Company TVD Reference: BCU-07A @ 143.00usft Project: Beaver Creek Unit MD Reference: BCU-07A @ 143.00usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 7 Survey Calculation Method: Minimum Curvature Wellbore: BCU-07A Design: BCU-07Awp2a Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (1 (') 5,220.95 4,925.00 B1 7,867.60 7,251.00 B18 5,575.48 5,236.00 B4 8,832.08 8,103.00 B28B 8,339.65 7,668.00 B23 8,967.69 8,225.00 B30 5,395.36 5,078.00 B3 8,482.29 7,794.00 B24 9,539.90 8,775.00 Tyonek Plan Annotations Measured Vertical Local Coordinates Depth Depth +Nl-S +El-W (usft) (usft) (usft) (usft) Comment 2,400.00 2,400.00 0.00 0.00 Start Build 12.00 2,420.00 2,419.99 0.42 0.00 Start 20.00 hold at 2420.00 MD 2,440.00 2,439.98 1.26 0.00 Start DLS 5.00 TFO 82.11 3,005.40 2,981.45 42.73 135.39 Start 4148.24 hold at 3005.40 MD 7,153.64 6,620.41 465.18 2,081.51 Start DLS 3.00 TFO 138.28 7,187.09 6,649.86 467.04 2,090.37 Start 1643.31 hold at 7187.09 MD 7,868.73 7,252.00 468.36 2,097.05 TPH at 7874'MD,7252'TVD 8,830.40 8,101.51 528.34 2,410.84 Start DLS 3.00 TFO-179.77 9,595.37 8,830.19 611.82 2,847.50 Start hold at 9595.37 MD I 10,500.00 9,731.37 612.97 2,853.53 TD at 10500.00 4/29/2014 2:13:28PM Page 6 COMPASS 5000.1 Build 70 in Zw m '" L ''um N m c ,J 0 L L m I a N co El rrML 0UID iii 0. 2 3 M d Q V y O r O a O o C (11) d = W O rZ U N x d m R O p O a ti t• n + ■ • Z w o E A [D c w ❑ N T▪ :t...n -• .12 3 OIII MS (13 0NM O Y O N orrrrl oc fn Y cV v u a II MI i� _ " W ❑ 3 d Y n m u °°U CO M HLL —Q 0 Cm n R CW co c o . M W+ C `n y c u o m CO Y 2 O N CL a Q Cj C •� . : v a oo w LU r " /� E U n H D (4 V •■� x d r o Cn o ti co Q L O m `t ' `- of - m o 2 2 Y c. C 3 L co O `" H oN p m o - m 0 0000 < 6 < N p N • .. 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U) _>_ I I 0 a al o mD I _ N Q c N N O ^i C 0 Lf J _ -.5 n •a 0 CO (.1 o _ 2 (u /T4sn 09 ) uoi}eedes alua3 of a }ua3Q Y V a N I Q ) O C 0 > U 8 c a a 5- © a°.i O ✓ U Ci t o y ct N- = a) U W P1 m u 0 0 z m i•Li W r 0 D N w Y —I U < c rgca aa) U m m 4 0 I ! — - —o I ! - o ! o .. — v - <r - - o `0 ' Lo o <r i C . .-. - o 0 N I — co 3 - ° I '- ! I - L 9 Q LL I ! _ M9, o d i ! - L cV. II! • - o V • a ti O - o R N 2 R N D CL 4) CO - o O U y I L i - z m o i 43CC 2 = Q - H CD RS a a LL aco _ c u> ei a O '0 - N +0 C10 - .e I QNCO III iiii . o II 44 N -I Q O0 O ti N OLo (0 Lc) O (� C O co I. c0 0 CC N O I E.3 (u!/o ) Joioe. uo!}eJedes Q U Schwartz, Guy L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Thursday, May 08, 2014 9:41 AM To: Schwartz, Guy L(DOA) Subject: RE: BCU 7A(PTD 214-060) Good morning Guy! We are planning to have the annulus packed with cement 500' above the window. Also,we will have a swell packer in the well in case the cement doesn't come up high enough for some reason. After the drilling rig gets finished with the well and the completion rig moves on, we will test the annulus and run a CBL. Thanks! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday, May 08, 2014 9:36 AM To: Monty Myers Subject: FW: BCU 7A( PTD 214-060) Here it is. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Schwartz, Guy L(DOA) Sent: Wednesday, May 07, 2014 4:18 PM To: Schwartz, Guy L(DOA) Subject: RE: BCU 7A( PTD 214-060) Luke, Also noticed that there is no mention of running a packer and tubing. Is this supposed to be a cement packer annulus? This is much shallower than the other wells here. Will need CBL and a test of the IA if so. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Schwartz, Guy L(DOA) Sent: Wednesday, May 07, 2014 4:14 PM To: Luke Keller Subject: BCU 7A ( PTD 214-060) Luke, Can you recheck your cement calculations on page 24? They are close but not in agreement with the stated volumes. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first savingor forwardingit, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). 2 Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Friday, May 02, 2014 6:48 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: BCU 7A (Permit 214-060): Another Question Attachments: BCU-07A WP2.b Proposed Surveys.xlsm; Beaver Creek#7A Casing Design.pdf; Beaver Creek#7A MASP.pdf Okay, The Correct version or most up to date directional plan that needs to be attached to the permit is BCU 07A wp2b. Corresponding depths 10500'TMD, 9621 TVD The corrected MASP worksheet and Casing design worksheet is attached as well. Thanks for your patience! Have a wonderful weekend! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Thursday, May 01, 2014 8:08 PM To: Monty Myers Cc: Schwartz, Guy L (DOA) Subject: BCU 7A (Permit 214-060): Another Question Monty, Another question: On the revised MASP page (page 37) that you sent this morning, the Planned TD is listed as 10500' MD (equivalent to 10402'TVD), with an estimated pressure of 4400 psi. In the directional survey, the TD is given as 10500' MD with a corresponding ND of 9731'. The calculations presented on that revised MASP page are based on 10402'TVD. Could you please correct this page? 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@alaska.gov. 1 From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Thursday, May 01, 2014 8:35 AM To: Davies, Stephen F (DOA); Schwartz, Guy L (DOA) Subject: Nearest Open Pool - BCU 07A question from AOGCC Here you go! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Kevin Eastham Sent: Thursday, May 01, 2014 8:32 AM To: Monty Myers; Jeff Allen Subject: RE: BCU 07A question from AOGCC Monty, Distance to nearest well open in the Beluga Gas Pool is 1350' (Distance to BCU 01B) Distance to nearest well open in the Sterling Gas Pool is 4215' (Distance to BCU 09) From: Monty Myers Sent: Thursday, May 01, 2014 7:00 AM To: Kevin Eastham; Jeff Allen Subject: BCU 07A question from AOGCC Can you guys help with this? If you can provide for me the depth of the beluga/sterling perfs in the nearest wellbore, I can have Cary give us a distance. Or you guys might be able to do it in petra? Let me know, the AOGCC is waiting. Thanks! 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: Wednesday, April 30, 2014 5:03 PM To: Monty Myers Cc: Schwartz, Guy L (DOA) Subject: FW: BCU 07A directional surveys Monty, In addition to my questions below, Conservation Order No. 237 (CO 237)governs Sterling and Beluga reservoirs within the Beaver Creek Field. Rule 3 of CO 237 specifies: 2 Well spacing in the Sterling and Beluga Gas Pools shall be 160 acres. No wellbore may be opened nearer than 1320 feet from the nearest open wellbore in the same pool. No wellbores may be opened nearer than 1500 feet from the Unit boundary. As planned, BCU 7A conforms to the 1500-foot setback requirement for the Unit boundary. Could Hilcorp please provide the distances from the target Sterling and Beluga reservoirs in BCU 7A to the nearest wells open to those same formations. "Open to" means perforations in the Sterling and/or Beluga that have not been isolated by cement. Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Wednesday, April 30, 2014 4:11 PM To: 'Monty Myers' Subject: RE: BCU 07A directional surveys Monty, Yes, please update it. Also, could you check the TVD value for the Total Depth? 10,420' isn't correct according to the proposed directional survey. 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@alaska.gov. From: Monty Myers [mailto:mmyers(ahilcorD.com] Sent: Wednesday, April 30, 2014 4:02 PM To: Davies, Stephen F (DOA) Subject: RE: BCU 07A directional surveys That being said, I need to update this sheet. Thanks! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 3 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, April 30, 2014 3:57 PM To: Monty Myers Subject: RE: BCU 07A directional surveys Monty, Looking at the Geo-Prog on page 31: Is the estimated pressure at the kick-off point really 1900 to 2300 psi at 2400' ND? Obviously, that yields gradients that seem way too high! 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@alaska.gov. From: Monty Myers [mailto:mmvers©hilcorp.com] Sent: Wednesday, April 30, 2014 3:29 PM To: Davies, Stephen F (DOA); Schwartz, Guy L (DOA) Subject: BCU 07A directional surveys Good afternoon gents! You should see the Beaver Creek Unit#7A PTD come through your office in the next few days. Attached are the digital surveys for you guys to use. If you have any questions, please let me know! Thanks! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 4 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, May 01, 2014 5:37 PM To: Monty Myers (mmyers@hilcorp.com) Subject: FW: BCU 7A (Permit 214-060): Another Question By the way,Version 2B lists a TVD of 9620.5' for the TD at 10,500'.... Again,this is different from the Permit form and from the submitted, printed survey. So, let me know which version to include. 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@alaska.gov<mailto:steve.davies@alaska.gov>. Original Message From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Thursday, May 01, 2014 5:28 PM To: Davies, Stephen F (DOA) Subject: Fwd: Beaver Creek Geo Prog- BCU 07A(BCU 07 ST) just told you it was 2.a. It's really 2.b. Sheesh what a day! Monty M Myers Original Message From: Monty Myers [mailto:mmyers@hilcorp.com] Sent:Thursday, May 01, 2014 5:22 PM To: Davies,Stephen F(DOA) Subject: Re: BCU 7A(Permit 214-060):Another Question The latest version is 2.a. It actually changed the day we submitted the permit.The correct TVD is 9731'. Sorry for all the errors! Monty M Myers >On May 1, 2014, at 5:19 PM, "Davies, Stephen F (DOA)" <steve.davies@alaska.gov>wrote: >Thanks, 1 > I also noticed that the electronic directional data that you provided via email on 4/30/14 lists a TD of 10500' MD and a corresponding TVD of 9620'. This contrasts with the TD of 10500' MD and 9731'TVD listed in the print out of the planned directional survey that was attached to the Permit to Drill Application form (Form 10-401) and on the form itself. Could you please check this also? >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@alaska.gov<mailto:steve.davies@alaska.gov>. > Original Message > From: Monty Myers [mailto:mmyers@hilcorp.com] >Sent:Thursday, May 01, 2014 5:13 PM >To: Davies,Stephen F(DOA) >Cc: Schwartz, Guy L(DOA) >Subject: Re: BCU 7A(Permit 214-060):Another Question >Sorry about that. I will get that corrected > Monty M Myers >On May 1, 2014, at 5:08 PM, "Davies, Stephen F (DOA)" <steve.davies@alaska.gov<mailto:steve.davies@alaska.gov>> wrote: > Monty, >Another question: On the revised MASP page (page 37) that you sent this morning, the Planned TD is listed as 10500' MD(equivalent to 10402'TVD), with an estimated pressure of 4400 psi. In the directional survey,the TD is given as 10500' MD with a corresponding TVD of 9731'. The calculations presented on that revised MASP page are based on 10402'TVD. Could you please correct this page? >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@alaska.gov<mailto:steve.davies@alaska.gov>. > From: Monty Myers [mailto:mmyers@hilcorp.com] >Sent:Thursday, May 01, 2014 8:35 AM 2 >To: Davies, Stephen F(DOA); Schwartz, Guy L(DOA) >Subject: Nearest Open Pool - BCU 07A question from AOGCC > Here you go! > Monty M Myers > Drilling Engineer > Hilcorp Alaska >Office: 907.777.8431 >Cell: 907.538.1168 > From: Kevin Eastham >Sent:Thursday, May 01, 2014 8:32 AM >To: Monty Myers;Jeff Allen >Subject: RE: BCU 07A question from AOGCC > Monty, > Distance to nearest well open in the Beluga Gas Pool is 1350' (Distance to BCU 01B) Distance to nearest well open in the Sterling Gas Pool is 4215' (Distance to BCU 09) > From: Monty Myers >Sent:Thursday, May 01, 2014 7:00 AM >To: Kevin Eastham;Jeff Allen >Subject: BCU 07A question from AOGCC >Can you guys help with this? > If you can provide for me the depth of the beluga/sterling perfs in the nearest wellbore, I can have Cary give us a distance. >Or you guys might be able to do it in petra? > Let me know, the AOGCC is waiting. >Thanks! > 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: Wednesday,April 30, 2014 5:03 PM >To: Monty Myers >Cc: Schwartz, Guy L(DOA) >Subject: FW: BCU 07A directional surveys > Monty, > In addition to my questions below, Conservation Order No. 237 (CO 237)governs Sterling and Beluga reservoirs within the Beaver Creek Field. Rule 3 of CO 237 specifies: 3 >Well spacing in the Sterling and Beluga Gas Pools shall be 160 acres. No wellbore may be opened nearer than 1320 feet from the nearest open wellbore in the same pool. No wellbores may be opened nearer than 1500 feet from the Unit boundary. > >As planned, BCU 7A conforms to the 1500-foot setback requirement for the Unit boundary. Could Hilcorp please provide the distances from the target Sterling and Beluga reservoirs in BCU 7A to the nearest wells open to those same formations. "Open to" means perforations in the Sterling and/or Beluga that have not been isolated by cement. > >Thank you, >Steve Davies >AOGCC > >CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov<mailto:steve.davies@alaska.gov>. > > > From: Davies, Stephen F (DOA) >Sent: Wednesday,April 30, 2014 4:11 PM >To: 'Monty Myers' >Subject: RE: BCU 07A directional surveys > > Monty, > >Yes, please update it. Also, could you check the TVD value for the Total Depth? 10,420' isn't correct according to the proposed directional survey. > >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@alaska.gov<mailto:steve.davies@alaska.gov>. > > From: Monty Myers [mailto:mmyers@hilcorp.com] >Sent: Wednesday,April 30, 2014 4:02 PM >To: Davies, Stephen F(DOA) >Subject: RE: BCU 07A directional surveys > >That being said, I need to update this sheet. > >Thanks! > > Monty M Myers > Drilling Engineer 4 > Hilcorp Alaska >Office: 907.777.8431 >Cell: 907.538.1168 > From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] >Sent: Wednesday, April 30, 2014 3:57 PM >To: Monty Myers >Subject: RE: BCU 07A directional surveys > Monty, > Looking at the Geo-Prog on page 31: Is the estimated pressure at the kick-off point really 1900 to 2300 psi at 2400' TVD? Obviously, that yields gradients that seem way too high! >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@alaska.gov<mailto:steve.davies@alaska.gov>. > From: Monty Myers [mailto:mmyers@hilcorp.com] >Sent: Wednesday, April 30, 2014 3:29 PM >To: Davies, Stephen F(DOA); Schwartz, Guy L(DOA) >Subject: BCU 07A directional surveys >Good afternoon gents! >You should see the Beaver Creek Unit#7A PTD come through your office in the next few days. >Attached are the digital surveys for you guys to use. > If you have any questions, please let me know! >Thanks! > Monty M Myers > Drilling Engineer > Hilcorp Alaska >Office: 907.777.8431 >Cell: 907.538.1168 5 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: �- 7,'1- PTD: / Y — OCC,� /Development Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: POOL: =�LZ7Cz-44—'' )4"- Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well(name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Lo ,n also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 a N ZT 0 u) 0 O T 0 m Oo 'n O @ L G) C a) C O C Q 0 0 an .- c as 0 °) to E c c in - o) O 2 O Q O a in > a 2 Z 0 1- ': N OV 0a) C. E C9 o Q CD D c N N E E 0 aa) a N E O m 0 a) Cl) a a .... o a6 N C 3 0 a a a O a) 0-) O o N o a o o CL U o 0 E a 0 7 m - 0 1-- = O N 0 E 0 a a ° 3 L o E -o N a) 3 a) oN •-....,._ y 0 c N c L Q - = c0 a) c c 0 0 •- 7 X (O (6 Vs O > s ° 0C a W O C 0 0) O • as 3 < m O L c O O u) U) C .L.. 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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 Unit BCU 7A FINAL WELL REPORT DML LOGGING DATA Provided by: Approved by: John Serbeck Compiled by: Seth Nolan Jim Foradas Distribution: 7/25/2014 TD Date: June 19, 2014 BCU 7A 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.............................................................................................................................7 3.1 Lithostratigraphy .............................................................................................................................7 3.2 Lithologic Details.............................................................................................................................8 3.3 Connection / Trip Gases...............................................................................................................22 3.4 Sampling Program / Sample Dispatch..........................................................................................23 4 DRILLING DATA..................................................................................................................................24 4.1 Directional Survey Data*...............................................................................................................24 4.2 Bit Record.....................................................................................................................................28 4.3 Mud Record ..................................................................................................................................29 5 DAILY REPORTS ................................................................................................................................30 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 7A 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 Larry Resch 13 22 Dickey Hudgins 5 17 Jim Foradas 8 22 Seth Nolan 2 22 *1 Years experience as Mudlogger. *2 Days at well site. BCU 7A 3 2 WELL DETAILS 2.1 Well Summary Well: BCU – 7A API Number: 50-133-20284-01-00 Field: Beaver Creek Surface Co-Ordinates: 1783’ FNL, 2033’ FEL, SEC 4, T6N, R10W, SM, AK Borough: Kenai Borough, AK Primary Target: Depth: Beluga B18, B20, B23, B27, B28B, B31 State: Alaska TD Depth: 9800’MD / 8929’TVD Rig Name / Type: Saxon 169/Double Suspension Date: n/a Primary Target: Beluga Permit to Drill: 214060 Spud Date: 06/02/2014 Ground Elevation: 133.00’ AMSL Completion Status: Run 5 1/2” Liner RKB Elevation: 151.60’ AMSL Classification: Development Gas Secondary Target: Depth: TD Formation: Beluga TD Date: 06/19/2014 Days Drilling: 17 Days Testing: n/a 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 7/8” 9800’ 8929’ Beluga 9.35 3.44 5 ½” 9766’ 8894’ 2.3 Well Synopsis: Beaver Creek #7A is a sidetrack to replace the original Beaver Creek #7 lower Beluga production hole section with a new well. The asset team believes that the Sterling and Lower Beluga has been underdeveloped on the southern part of the Beaver Creek structure. Our intent is to sidetrack the well to the NE and target the Sterling and Lower Beluga from the original Beaver Creek # 7. The new well will utilize the existing casing program down to 2400’ MD. The base plan is a deviated wellbore reaching a maximum inclination of 35 deg and a 3163’ vertical separation at TD. Drilling operations are expected to commence approximately June 1st, 2014 with the Saxon Rig #169. This rig will be used to sidetrack the existing Beaver Creek #7 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. BCU 7A 4 2.4 Daily Activity Summary June 2, 2014: Set whipstock at 2,359’MD. Began milling window F/ 2,336’ – T/ 2,343’. Pumped hi-vis sweep, 50% increase in metal shavings. Continued milling window T/ 2,347’. Torque decreased considerably and ROP decreased to nothing. Pumped 20 bbl hi-vis sweep, 10% increase in fine shavings. Decision made to POOH to inspect milling assembly. POOH and changed mill. RIH with same. Continued milling window T/ 2,376’. TOW @ 2,336’, BOW @ 2,343’. Perform FIT to 235 psi. POOH to surface, lay down milling assembly. Make up BHA. June 3, 2014: Continue to make up BHA, RIH T/ 2,302’ and R/U wireline. Drilled to 2,271’ and POOH with Gyro and laid down wireline. Picked up DP and drill ahead to 2,666’. June 4, 2014: Continue to drill ahead from 2,666’. To 2768’ and pumped a 20 bbl hi-vis sweep. Continued to drill ahead to 3388’ and circulated bottoms up before performing 1st wiper trip to the window. TIH back to bottom picking up DP. Pumped a hi-vis sweep once back on bottom and continued to drill ahead to 3635’. June 5, 2014: Continued to drill ahead from 3635’ to 4031’. Pumped a hi-vis sweep and continued to drill ahead to 4568’. Circulated bottoms up and made a wiper trip to 3388’. TIH back to bottom picking up DP. Pumped a 20 bbls hi-vis sweep and continued to drill ahead to 4815’. Pumped a 20 bbls hi-vis sweep. Continued to drill ahead. June 6, 2014: Continued to drill ahead from 4815’ to 5141’ and pumped a 20 bbls hi-vis sweep. Continued to drill ahead to 5810’ and pumped a 20 bbls hi-vis sweep. Continued to drill ahead to 5997’ and circulated 1 ½ bottoms up. Performed a wiper trip to 4568’. TIH back to bottom picking up DP. On bottom pumped a 20 bbls hi-vis sweep. Continued to drill ahead. June 7, 2014: Continued to drill ahead from 5997’ to 6428’ and pumped a 20 bbl hi-vis sweep. Continued to drill ahead to 6989’ and pumped a 20 bbl hi-vis sweep. Circulated bottoms up until hole was clean. Performed wiper trip to window. The rig performed a slip and cut before TIH back to bottom. TIH back to bottom picking up DP to 5166’. Began to wash down to bottom from 5166’. June 8, 2014: Continued TIH washing through 5371', 6359' and washing down the last 3 stands down; no fill; pumped a Hi-Vis sweep on bottom; observing 25% increase in cuttings; drilled ahead to 7300' and pumped another sweep observing 100% increase in cuttings; continued drilling ahead; currently drilling ahead. June 9, 2014: Drilled to 7622'; pumped a Hi-Vis sweep, observing a 150% increase in cuttings; drilled ahead to 7920'; pumped a Hi-Vis sweep, observing a 50% increase in cuttings; continued drilling; currently drilling ahead. June 10, 2014: Drilled to 8157'; pumped a Hi-Vis sweep, observing a 100%; CBU; TOOH to 7075'for a wiper trip, pumping at 6987'; RIH back to bottom. Pumped a Hi-Vis sweep at bottom, observing a 200% increase in cuttings; BCU 7A 5 drilled to 8418'; pumped a Hi-Vis sweep, observing a 25% increase in cuttings; continued drilling; currently drilling ahead June 11, 2014: Continued drilling ahead and ROP declined to <10 ft/hr; pumped a Hi-Vis walnut sweep at 8481', observing a 20% increase in cuttings; ROP increased to 20 ft/hr and torque dropped to 10,400, but ROP soon dropped off again; pumped two more Low-vis sweeps at 8528' and 8577' but ROP increased and then dropped off again; decision made to pump dry job and TOOH to change bit; POOH to 6965'; BROOH through tight spots to 6450’; continued POOH without problems, presently POOH at 4296’ June 12, 2014: Finished POOH, L/D BHA and P/U BHA#5; RIH to 5980' and encountered tight spot; RIH; washed and reamed from 6140' to 6500' (11 units wiper gas); RIH on the elevators; no fill observed; on bottom pumped a Hi-Vis sweep, observing a 10% increase in cuttings and (22u gas); drilled ahead; currently drilling ahead. June 13, 2014: Continued drilling ahead to 8980'; pumped a Hi-Vis sweep, observing a 10% increase in cuttings; drilled ahead; currently drilling ahead. June 14, 2014: Continued drilling ahead to 9286'; pumped a 20 bbl Hi-Vis sweep with walnut to help gauge the hole; sweep indicated gauged hole, but with minimal cuttings (only 10% increase); continued drilling ahead to 9349'; CBU; decision to POOH due to mud motor problems; logged out of hole from 9349' to 9050'; TOOH; L/D motor/bit; R/U to test BOP; currently testing BOP's. June 15, 2014: Finished testing BOP's (note: 12bbls mud lost down hole during testing); P/U milling assembly; RIH to window; S/C drill line; continue RIH, reaming and pumping to bottom due to full gauge mill; currently RIH at 8283’ June 16, 2014: Continued reaming and pumping to 9300'; pumped 20 bbl Hi-Vis walnut sweep, observing a 10% increase in cuttings (70u max gas); washed to bottom at 9349' and began milling junk; milled to 9352’; pull four stands on elevators to catch metal in junk baskets; RIH to bottom and continued to mill ahead; pumped five multiple Hi-Vis sweeps, some with walnut mixed in while milling, observing no increase in cuttings or metal at shakers; milled to 9355’ decision to TOOH to examine and if necessary replace bit; currently TOOH at 5497’. Total of 06’ of incidental hole drilled during milling process. June 17, 2014: Finished TOOH; inspected mill, was worn out and out of gauge; P/U new mill; RIH to bottom; continue milling; pumped Hi-Vis sweep with walnut at 9,358', observing 10% increase in cuttings; continue milling; pumped Hi-Vis sweep with walnut at 9,360’, observing 10% increase in cuttings; milled to 9,361'; flow check, no flow; TOOH, flow slightly falling looking down backside; continue TOOH slowly to 7,536'; currently TOOH at 7421’ (note: drilling parameters reflect entire milling process from 9349' to 9361'). June 18, 2014: Finished TOOH; L/D milling assembly (BHA 7); clean out boot baskets, recover metal cuttings and weigh metal recovered (1.0lb ); R/D milling tools; M/U drilling BHA 8 with PDC bit; TIH to window; S/C drill line; service rig; continue TIH at moderate speed watching for tight spots; currently at 9359’ preparing to drill ahead. BCU 7A 6 June 19, 2014: Drilled ahead from 9360'; pumped sweep at 9596' and observed 10% increase in cuttings; drilled to TD at 9800’; pumped sweep and observed a 50% increase in cuttings, and 313 units gas at bottoms up; TOOH to 9000'; began MAD pass aimed at logging to 5000'; currently logging at 6,539'. June 20, 2014: Finished MAD pass to 5000'; RIH; took weight at 9686; decision to wash and ream to bottom getting 2458 units of gas at BU with mud cut 8.6ppg from 9.3ppg; pumped 25 bbl Hi-Vis sweep with walnut, observing 20% increase in cuttings; shakers cleaned up; pumped dry job 2.5 lbs over mud weight; POOH, L/D DP during trip, currently at 2675’. June 21, 2014: Finished POOH, L/D DP; L/D BHA; C/O rams; tested rams for running 5.5" casing; waited on Weatherford for tools; started RIH with 5.5" casing circulating every 2000’; currently circulating at 4024.9’ (39u gas) during casing run. June 22, 2014: Finished running casing, landed casing at 9765'; C&C mud and building 10.5 mud push (maximum 2187 units of gas at bottoms up); R/U Schlumberger to pump cement job; Pumped 35 bbls Mud-Push; pumped 345 bbls cement and chased with 266.6 bbls fresh water; monitored gas until cementing completed; did not bump plug, floats held; R/D cementers; rig started hauling mud to KGF; Canrig started DML Mudlogging unit rigdown. BCU 7A 7 3 GEOLOGICAL DATA 3.1 Lithostratigraphy All tops were provided by Hilcorp geologist John Serbeck. OBSERVED FORMATION MD (ft) TVD (ft) BC_B1ST 5397 4942 BC_B2ST 5555 5070 BC_B3ST 5605 5111 BC_B3‐L_ST 5687 5178 BC_B4ST 5784 5257 UBC3 6772 6067 BC_B18UST 8090 7237 BC_B20ST 8246 7390 BC_B21ST 8328 7471 BC_B22ST 8445 7586 BC_B23ST 8559 7696 BC_B24ST 8667 7804 BC_B25ST 8705 7842 BC_B26ST 8745 7881 BC_B27ST 8782 7918 BC_B28ST 8833 7968 BC_B28_B_ST 9001 8135 BC_B29ST 9016 8150 BC_B30ST 9093 8226 BC_B31ST 9203 8319 BC_B32ST 9392 8521 TYONEK 9664 8792 BCU 7A 8 3.2 Lithologic Details Tuffaceous Claystone (2356' - 2400') = light to medium gray; soft to malleable; crumbly to pulverulent; irregular to flaky fracture; tabular to nodular cuttings habit; dull to earthy luster; smooth to gritty texture; thin to massive structure; intergrading to tuffaceous siltstone; interbedded with thin beds of coal and carbonaceous shale; sub-lithified plant matter observed; traces of cement still in sample. Tuffaceous Claystone (2400' - 2490') = medium to dark gray with light olive hues; mushy to curdy; malleable to crumbly; irregular to blocky fracture; tabular to nodular cuttings habit; waxy to dull, greasy luster; smooth to silty texture; massive to thin structure; interbedded with increasing amounts of lower very fine to medium, poorly sorted sand composed of volcanics and quartz with trace greenstone below 2430' MD. Tuffaceous Claystone (2490' - 2550') = medium to dark gray with olive brown hues; mushy to curdy; malleable to crumbly; irregular to blocky fracture; tabular to wedge like cuttings; dull to earthy luster; smooth to silty texture; thick to thin structure; interbedded with lower very fine to medium grained; poorly sorted sand composed of volcanic rock fragments; glasses, quartz; and trace greenstone occurring in thin beds, thin beds of coal, and light brownish gray tuffaceous siltstone containing traces of black carbonaceous fines. Tuffaceous Claystone (2580' - 2670') = light to medium gray to light brownish gray; mushy to curdy; crumbly to pulverulent; irregular blocky fracture; tabular to wedge like to butter curl-like cuttings habit; greasy to dull luster; smooth to gritty texture; thin to thick structure; intergrading to tuffaceous siltstone in places; interbedded with darker gray sand that contains more dark volcanic lithics than quartz and lighter materials; light brownish gray tuffaceous siltstone and thin beds of carbonaceous shale and coal are also present in this interval along with a few cuttings of very easily friable tuffaceous sandstone; the amount of sand varies in samples with the sample obtained at 2640' containing only traces of sand. Tuffaceous Claystone (2670' - 2730') = light to medium gray with light brownish gray hues; mushy to clumpy; crumbly to pulverulent; irregular blocky to planar fracture; tabular to wedge like cuttings habit with some butter curl-like cutting observed; greasy to dull earthy luster; smooth to silty texture; some thinly laminated specimens intergrading to tuffaceous siltstone; overall silt and sand are absent in this interval; some thin beds of coal, and carbonaceous shale are present. Tuffaceous Claystone (2730' - 2790') = light to medium gray with light brownish gray hues; mushy to clumpy; crumbly to pulverulent; irregular blocky to planar fracture; tabular to wedge like cuttings habit; greasy to dull earthy luster; smooth to silty texture; some thinly laminated specimens intergrading to tuffaceous siltstone; overall silt and sand increase slightly in this interval; thin beds of coal, and carbonaceous shale also occur but are rare. Tuffaceous Claystone (2790' - 2880') = light medium gray to light brownish gray with greenish hues; punky to stiff; crumbly to pulverulent; irregular blocky fracture; flaky to tabular cuttings habit; waxy to dull earthy luster; smooth to gritty texture; thin structure; some carbonaceous lamina; interbedded with sand. Tuffaceous Sand (2790'-2880') = medium to dark gray with lighter gray and greenish hues; lower very fine to upper medium; poor to fair sorted; subangular to rounded; low to moderate sphericity; common polish; composed of volcanic rock and glass fragments, and quartz; trace to common greenstone. NSOFC BCU 7A 9 Tuffaceous Claystone (2880' - 2940') = light medium gray to light brownish gray with greenish hues; punky to stiff; crumbly to pulverulent; irregular blocky fracture; flaky to tabular cuttings habit, some butter curl-like cuttings; waxy to earthy luster; smooth to gritty texture; thin to massive beds; some carbonaceous laminae and banding; intergrades to tuffaceous siltstone. Tuffaceous Claystone (2940' - 3030') = light medium grey to greenish grey with brownish grey hues; soft to friable crumbly to pulverulent; nodular to tabular cuttings habit; clayey to slightly silty; dull to earthy luster; punky to mushy texture; thin to massive with organic carbonaceous laminae interbedded; intergrades to tuffaceous siltstone. Conglomeritic Sand (3030' - 3060') = light grey to greenish grey; very fine to fine grained; low to moderate sphericity; sub rounded to sub angular; poor to moderate sorting; unconsolidated to friable; ashy matrix; matrix supported; 65% quartz sand, light greenish grey to yellowish green grey greenstone, volcanic clasts, feldspathic mineral grains, NSOFC. Tuffaceous Siltstone (3080' - 3140') = medium light grey to light greenish grey to brownish grey; soft to friable; crumbly to pulverulent tenacity; nodular to slightly tabular to massive cuttings habit; clayey to silty texture; dull to earthy; clumpy to mushy; thin to massive bedding; conglomeritic sand that is very fine to upper fine grained; low to moderate sphericity; sub angular to sub rounded; unconsolidated to friable; volcanic clasts, greenstone, feldspathic mineral grains, tuffaceous matrix Conglomeritic Sand (3140' - 3195') = medium light grey to greenish grey; very fine to fine grained; low to moderate sphericity; sub rounded to sub angular; poor to moderate sorting; unconsolidated to easily friable; ashy matrix; grain supported; 50% translucent quartz grains 35% volcanic clasts, light greenish grey to yellowish green grey grains, NSOFC. Conglomeritic Sand (3195' - 3240') = light greenish grey to medium greenish grey; very fine to fine grained; low to moderate sphericity; sub rounded to sub angular; moderate to moderately well sorted; unconsolidated; no visible cement; no visible matrix; grain supported; 55% translucent quartz grains 25% volcanic clasts, feldspathic minerals, light greenish grey to greenish grey grains, NSOFC. Conglomeritic Sand (3240' - 3290') = light greenish grey to medium greenish grey to medium light grey; upper very fine to upper fine grains; sub rounded to sub angular; poorly sorted; unconsolidated; no visible cement; no visible matrix; grain supported; 45% translucent quartz grains, 35% greenish grey grains, volcanic clasts, feldspathic minerals; NSOFC. Conglomeritic Sand (3290' - 3360') = light grey to greenish grey; upper fine to upper medium grained; low to moderately spherical; sub rounded to sub angular; poorly sorted; unconsolidated to very easily friable; no visual cement; ashy matrix; grain supported; 35% translucent quartz grains, 35% greenish grey grains, 20% volcanic clasts, feldspathic minerals; NSOFC. Tuffaceous Siltstone (3360' - 3420') = light grey to greenish grey to brownish grey; unconsolidated to friable; crumbly to pulverulent tenacity; nodular to massive; clayey to silty to gritty; dull to earthy and resinous in part; lumpy to mushy; thin to massive bedding; volcanic clasts loose conglomeratic sand poorly sorted with feldspathic minerals, and greenish gray gravels. BCU 7A 10 Tuffaceous Siltstone (3420' - 3480') = light gray to light greenish gray; stiff; crumbly to pulverulent tenacity; irregular blocky fracture; tabular to wedge like nodular cuttings habit; waxy to dull earthy luster; smooth clayey to gritty textures; thin to massive structure; intergrading to tuffaceous claystone and conglomeratic tuffaceous sandstone with silty matrix; composition of tuffaceous sandstone similar to the conglomeritic sands siltstone is interbedded with: lower very fine to very coarse grained, poorly sorted, angular to surround; very low to moderate sphericity, composed of feldspathic and other volcanics and greenstone. Tuffaceous Sandstone (3450' - 3570') = light gray to light brownish gray with greenish hue; lower very fine to very coarse grading to fine gravel; very poor to moderately sorted; angular to subrounded; low to high sphericity; some frosting, polish, etching, pitting seen on grain surfaces; unconsolidated to easily friable with some harder; silty tuff matrix present, but grain supported overall; composed of feldspathic and other volcanics; common greenstone; fining down to tuffaceous siltstone thin to massive structure, conglomeratic in part; interbedded with thin lignitic coal and carbonaceous shale in places. Tuffaceous Siltstone (3570' - 3630') = light gray to greenish gray; crumbly to pulverulent; irregular blocky fracture; tabular to nodular cuttings habit; waxy to dull luster; smooth to gritty texture; thin to thick structure; traces yellow-white ash; intergrading to tuffaceous sandstone. Tuffaceous Sandstone (3630' - 3690') = light brownish gray with white hues; lower very fine to upper medium grains; fair to well sorted; angular to round; low to high sphericity; some polish on grain surfaces; easily friable to unconsolidated; grain supported with common silty tuff and some ash matrix; composed of volcanic glass, feldspathic and other volcanics; trace greenstone; intergrading with tuffaceous siltstone. Tuffaceous Sandstone (3690' - 3750') = light brownish gray with greenish hues; lower very fine to lower coarse grains; fair to well sorted; angular to round; low to high sphericity; some polish on grain surfaces; easily friable, soft, to unconsolidated; grain supported with common silty tuff matrix; trace ash; composed of volcanic glass, feldspathic and other volcanics; trace greenstone; intergrading to tuffaceous siltstone. Tuffaceous Siltstone (3750' - 3810') = medium to light brownish gray with black and green hues; adhesive; crumbly to pulverulent; irregular blocky fracture; tabular to butter curl-like cuttings habit; dull earthy luster; clayey to gritty texture; carbonaceous fines; thin to fissile structure; inter- grades to tuffaceous sandstone; occurs with thin carbonaceous shale, coal, and ash beds; mostly volcanic composition. Tuffaceous Sandstone (3810' - 3900') = light brownish gray with greenish hues; lower very fine to lower coarse grains; fair to well sorted; angular to round; low to high sphericity; easily friable; common silty tuff matrix; trace ash; conglomeratic in part; composed of volcanic glass, feldspathic minerals, volcanic rock fragments; common greenstone; intergrades to brownish gray siltstone with greenish hues that occurs in smooth to clayey, and gritty varieties and can have thin to fissile structure, with some dark lamina. Tuffaceous Siltstone (3900' - 3990') = medium to light brownish gray with greenish hues; adhesive; crumbly to pulverulent; irregular blocky fracture; tabular to wedge like cuttings habit; waxy to earthy luster; clayey to gritty texture; carbonaceous fines; thin to fissile structure; intergrades to tuffaceous sandstone. Tuffaceous Sandstone (3900' - 3990') = light brownish gray with greenish hues; lower very fine to lower coarse grains; fair to well sorted; angular BCU 7A 11 to round; low to high sphericity; unconsolidated; grain supported; tuff matrix; trace ash; conglomeratic in part; composed of volcanic glass, feldspathic minerals, volcanic rock fragments; common greenstone; intergrades to brownish gray tuffaceous siltstone. Tuffaceous Sandstone (3990' - 4080') = light brownish gray with greenish hues; lower fine to upper very coarse grains; fair to well sorted; subangular to round mod to high sphericity; unconsolidated; grain supported; tuff matrix; trace ash; conglomeratic in part; composed of volcanic glass, feldspathic minerals, igneous rock fragments; common greenstone; intergrades to greenish gray tuffaceous siltstone; coarsens downward and becomes easily friable to firm friable and more conglomeratic within this interval. Tuffaceous Sandstone (4080' - 4140') = light brownish gray with greenish hues; upper fine to upper very coarse grains; poor to well sorted; subangular to round mod to high sphericity; easily friable; grain supported; tuff matrix; trace ash; conglomeratic in part; still coarsening down; intergrading with tuffaceous siltstones to 4130'; interbedded with brown black lignitic coal at 4130'-4140' that is crunchy to crumbly with planar fracture, has tabular to wedge like cuttings habit, earthy to resinous luster, matte texture, thin structure; brownish black carbonaceous shale also occurs in thin beds with the coal. Tuffaceous Sandstone (4140' - 4220') = light grey to brownish grey to light greenish grey; upper very fine to lower very coarse; low to moderate sphericity; subangular to rounded; poor to moderately well sorted; unconsolidated to friable; no visible cement; ash and tuff matrix; grain supported; interbedded with tuffaceous siltstone and coal that is crumbly, blocky to planar, platy to wedge like, resinous to earthy, matte, thin structure. Tuffaceous Sandstone (4220' - 4260') = light medium grey to light brownish grey with greenish hues; lower fine to upper very coarse grained; low to moderate sphericity; subangular to rounded; poor to moderately sorted; unconsolidated to friable; tuff/ash matrix; grain supported; conglomeritic in parts, volcanic glass, feldspathic grains. Tuffaceous Sandstone (4260' - 4320') = light grey to light brownish grey with greenish hues; lower very fine to upper medium grains; low to moderate sphericity; subangular to rounded; poor to moderately well sorted; unconsolidated to friable; tuff matrix; grain supported; volcanic mineral clasts feldspathic grains; greenstone, trace coal. Tuffaceous Sandstone (4320' - 4380') = light grey to brownish grey with greenish hues; lower fine to upper medium grained; low to moderate sphericity; subangular to subrounded; poor to moderately sorted; unconsolidated to easily friable; tuff matrix; grain supported; volcanic clasts Conglomeritic Sand (4380' - 4440') = light medium grey to greenish grey; lower fine to upper medium grained; moderate sphericity; moderate to moderately well sorted; unconsolidated; no visible cement; no visible matrix; grain supported; volcanic clasts, biotite, feldspathic mineral clasts, greenstone, interbedded tuffaceous siltstone that is light grey, soft, crumbly to pulverulent; nodular; silty; dull to earthy. Tuffaceous Sandstone (4440' - 4500') = light medium grey to brownish grey with greenish grey hues; lower fine to upper medium grains; low to moderate sphericity; subangular to subrounded; moderate to moderately well sorted; unconsolidated to easily friable; tuff matrix; grain supported; conglomeritic in parts; volcanic clasts, feldspathic mineral clasts, greenstone, trace coal. Tuffaceous Sandstone (4500' - 4560') = light medium grey with greenish and brownish hues; upper very fine to lower medium grains; low to BCU 7A 12 moderately spherical; subangular to subrounded; moderately well to well sorted; unconsolidated; tuff matrix; grain supported; volcanic clasts, feldspathic mineral clasts, greenstone, conglomeritic in parts. Tuffaceous Siltstone (4560' - 4620') = light greenish grey to light brownish grey; soft to friable; crumbly to pulverulent; massive to nodular; silty to granular; waxy to resinous to earthy; lumpy to mushy; thin to massive; intergrading tuffaceous sandstone, light grey to green grey, tuff matrix, volcanic clasts greenstone; intergrading lignitic coal, brown to black, blocky to platy fracture resinous, easily to firm friable. Tuffaceous Sandstone (4620' - 4680') = light greenish gray to light brownish gray; lower very fine to lower fine grained with some coarser grains; fair to well sorted; angular to round; low to very high sphericity; some polish and grinding seen on grain surfaces; firm to easily friable; some firm grain supported; mostly soft matrix supported varieties; some carbonaceous laminae; composed of volcanic glass and rock fragments; some quartz and greenstone; intergrading to similarly colored gritty tuffaceous siltstone; interbedded with thin lignitic coal, carbonaceous shale, and ash in places; all rocks exhibit thin structure in this interval. Tuffaceous Siltstone (4680' - 4740') = light greenish gray to light brownish gray; crumbly to pulverulent; irregular blocky fracture; tabular to wedge like cuttings habit; dull earthy luster; fine colloidal to gritty texture; some thin carbonaceous laminae; thin to thick structure; less arenaceous downward; interbedded with coal, carbonaceous shale and traces of ash. Tuffaceous Sandstone (4740' - 4830') = light brownish gray with gray and white hues; lower very fine to lower coarse; fair sorted; angular to rounded; low to high sphericity; common mechanical abrasion features on grain surfaces; easily friable to unconsolidated; mostly grain supported; some white matrix supported with floating grain fabric; composed of volcanic glasses and felsic rock fragments; common greenstone; intergrading to gritty tuffaceous siltstone; thin to thick structure. Tuffaceous Sandstone (4830' - 4920') = light brownish gray with yellow white hues; lower very fine to very coarse; fair sorted; angular to rounded; low to mod sphericity; common mechanical abrasion features on grain surfaces; easily friable to unconsolidated; mostly grain supported; less matrix supported; composed of volcanic glasses and felsic rocks; common greenstone; intergrades to smooth to gritty tuffaceous siltstone in places; thick to massive structure; conglomeratic in part; interbedded with thin beds of coal, carbonaceous shale, and ash in laces; coarsening down; cuttings slightly firmer with depth, in this interval. Tuffaceous Sandstone (4920' - 4990') = light brownish gray with gray and white hues; lower fine to upper coarse with some fine gravel fragments; poor to fair sorted; angular to rounded; low to high sphericity; common signs of mechanical abrasion on grain surfaces; firm friable to unconsolidated; grain supported with some to abundant tuff and ash matrix; composed of volcanic glasses and felsic rocks; common greenstone; intergrades to smooth to gritty tuffaceous siltstone in places; thick to massive structure; conglomeratic in part; interbedded with thin brownish black lignitic coal, ash, and carbonaceous shale beds in places; generally coarser and slightly firmer with depth above coal at 4990' MD. Tuffaceous Siltstone (4990' - 5070)' = light brownish gray to greenish gray with brown hues; adhesive; crumbly to pulverulent; irregular blocky fracture; tabular to wedge like and butter curl-like cuttings habit; waxy to earthy luster; clayey to gritty texture; thin laminar structure; interbedded with coal, ash and carbonaceous shale in places. Tuffaceous Sandstone (5070' - 5130') = light brownish gray with greenish gray hues; lower fine to upper medium; fair sorted; angular to rounded; BCU 7A 13 mod to high sphericity; some polish and grinding; firm friable to soft; grain supported with common silty ash and tuff matrix; composed of volcanic glasses and felsic rocks; common greenstone; intergrades to smooth to gritty tuffaceous siltstone with depth and generally fines down; interbedded with brownish black coal and carbonaceous shale and ash. Tuffaceous Siltstone (5130' - 5190)' = light brownish gray to greenish gray; pale brown hues; adhesive; crumbly to pulverulent; irregular blocky fracture; tabular to wedge like cuttings habit; waxy to earthy luster; arenaceous with moderately gritty texture; thin to thick structure; interbedded with thin beds of coal, ash, and carbonaceous shale; intergrading to tuffaceous sandstone. Tuffaceous Sandstone (5190' - 5280') = light brownish gray with greenish hues; lower very fine to upper medium grained with some coarser grains; fair to well sorted; subangular to rounded; low to high sphericity; common signs of mechanical abrasion; easily friable to unconsolidated; grain supported with some silty ash and tuff matrix; thin to thick beds intergrading with tuffaceous siltstone; coarsening down; interbedded with thin coal and carbonaceous shale; composed of volcanic glasses and felsic rocks; common greenstone, dark fines. Tuffaceous Siltstone (5260' - 5310') = light brownish gray to greenish gray; adhesive; crumbly to pulverulent; irregular blocky fracture; flaky to tabular cuttings habit; waxy to dull earthy luster; colloidal to gritty texture; thin to massive structure, with some fissile and laminated; intergrading with tuffaceous sandstone, carbonaceous shale, and interbedded with thin coal. Tuffaceous Siltstone (5310' - 5370') = brownish gray to greenish gray; crumbly to pulverulent; irregular blocky fracture; wedge like, flaky and tabular cuttings habit; dull to earthy luster; smooth colloidal to fine gritty texture; thin to thick structure, some fissile; common lamina and dark fines; intergrading with carbonaceous shale, and tuffaceous sandstone; interbedded with thin ash and coal beds. Tuffaceous Siltstone (5370' - 5430') = light medium grey to greenish grey with brownish grey hues; soft to easily friable; crumbly to pulverulent tenacity; wedge like to nodular to amorphous cuttings habit; silty to gritty texture; waxy to earthy luster; mushy to clumpy; massive to thin bedding; intergrading to lignitic coal, dark brown to black, friable, brittle to crumbly, blocky to wedge like; intergrading to tuffaceous sandstone, greenish grey to light brownish grey, upper very fine to lower coarse grain, volcanic clasts, greenstone, coal Tuffaceous Siltstone (5430' - 5490') = light greenish grey to light brownish grey; soft to friable; crumbly to pulverulent tenacity; nodular to lenticular to amorphous cuttings habit; silty to gritty texture; waxy to dull earthy luster; mushy to clumpy; massive to thin bedding; intergrades to tuffaceous sand Tuffaceous Siltstone (5490' - 5550') = light medium grey to greenish grey to brownish grey; soft to friable; silty to gritty texture; waxy to resinous to earthy luster; mushy to clumpy habit; massive to thin bedding; intergrades with lignitic coal, dark brown to black, friable, brittle to firm, blocky to platy to wedge like; intergrades with tuffaceous sandstone, lower fine to lower medium grain, unconsolidated to friable, grain supported, volcanic clasts, greenstone Tuffaceous Siltstone (5550' - 5610') = light medium grey to greenish grey with brownish hues; soft to easily friable; crumbly to pulverulent tenacity; nodular to amorphous habit; silty to granular texture; massive to lenticular bedding; intergrades to conglomeritic sand, lower fine to upper very coarse, subangular to subrounded, unconsolidated, grain supported, volcanic clasts, greenstone BCU 7A 14 Tuffaceous Sandstone (5610' - 5670') = light medium grey to brownish grey to greenish grey hues; lower fine to lower medium grain; low to moderate sphericity; subangular to subrounded; moderately well to well sorted; unconsolidated; no visible matrix; grain supported; volcanic clasts, greenstone; intergrades to lignitic coal, dark brown to black, friable to firm, blocky; intergrades to tuffaceous siltstone, light grey to greenish Tuffaceous Sandstone (5670' - 5730') = light medium grey to greenish grey to brownish grey; lower very fine to upper fine grain; moderately low to moderate sphericity; subangular to subrounded; moderate to moderately well sorted; friable to very poorly consolidated; tuff matrix; grain supported; volcanic clasts , greenstone, trace coal; intergraded to tuffaceous siltstone Tuffaceous Siltstone (5730' - 5790') = light medium grey to light brownish grey to greenish grey; soft to friable; crumbly to crunchy tenacity; massive to nodular habit; clayey to gritty texture; mushy to pasty consistency; massive to thin bedded; intergrades with tuffaceous sandstone, lower very fine to upper fine grain, unconsolidated, grain supported, volcanic clasts, greenstone; trace lignitic coal Tuffaceous Sandstone (5790' - 5850') = light medium grey to light greenish grey with brownish hues; upper fine to lower coarse grain; low to moderate sphericity; subangular to subrounded; moderately to moderately well sorted; no visual matrix; grain supported; volcanic clasts greenstone, feldspathic mineral clasts; interbedded tuffaceous siltstone, light grey to greenish grey, soft, massive to nodular, silty to gritty, mushy Tuffaceous Sandstone (5850' - 5910') = light medium grey to light green grey to brownish grey; lower medium to upper coarse grain; low to moderate sphericity ; subangular to subrounded; moderately well sorted; tuff matrix; grain supported; volcanic clasts, greenstone, feldspathic clasts; intergrading with tuffaceous siltstone, greenish grey to light grey, soft, massive to nodular, mushy, massive to thin bedding Tuffaceous Sandstone (5910' - 5970') = light medium grey to greenish grey to brownish grey; lower medium to lower very coarse grain; low to moderately spherical; subangular to subrounded; moderately sorted; tuff matrix; grain supported; volcanic clasts, greenstone, feldspathic clasts; intergrading with tuffaceous siltstone, soft, crumbly to crunchy, nodular, dull to waxy to earthy; massive bedding. Tuffaceous Sandstone (5970' - 6060') = light to medium gray with pale brown and greenish hues; lower very fine to coarse grained; poor to fair sorted; subangular to round; moderate to high sphericity; common mechanical abrasion features on grain surfaces; soft to unconsolidated; grain supported; composed of volcanic clasts, felsic mineral and rock grains, and greenstone; intergrading with tuffaceous siltstone that is crumbly to crunchy, nodular to tabular, waxy to earthy, with gritty texture, and some lamina; conglomeratic in part; occurs in thin to massive beds. Tuffaceous Sandstone (6060' - 6180') = light to medium gray with pale brown and white hues; lower very fine to coarse grained; fair to well sorted; angular to round; very low to high sphericity; common mechanical abrasion features on grain surfaces; friable to unconsolidated; grain supported with common silty white tuffaceous matrix; composed of volcanic clasts, felsic mineral and rock grains; carbonaceous fines and coarser greenstone and quartz that can grade to gravel are common, particularly lower in this interval; intergrading to tuffaceous siltstone that is crumbly to crunchy, nodular to tabular, dull to earthy, smooth to gritty and very thinly bedded; interbedded with thin carbonaceous shale and tuff in places; sandstones in this interval are conglomeratic in part and exhibit thin to thick bedding structure; some laminae and banding were observed in firmer tuffaceous sandstone cuttings. BCU 7A 15 Tuffaceous Sandstone (6180' - 6300') = light to medium gray with pale brown lower very fine to very coarse grading to fine gravel; poor to fair sorted; angular to round; very low to high sphericity; common mechanical abrasion features on grain surfaces; friable to unconsolidated; grain supported with common silty white tuffaceous matrix; composed of volcanic clasts, felsic mineral and rock grains; carbonaceous fines and coarser greenstone and quartz intergrading to tuffaceous siltstone that is crumbly to crunchy, nodular to tabular, dull to earthy, smooth to gritty and very thinly bedded; interbedded with thin carbonaceous shale and tuff in places; sandstones in this interval also grade to conglomerate and exhibit thin to thick bedding structure; some laminae and banding were observed in firmer tuffaceous sandstone cuttings Tuffaceous Sandstone (6300' - 6390') = light brownish gray with green hues; lower very fine to very coarse grading to fine gravel; moderately sorted; angular to round; very low to high sphericity; common mechanical abrasion features on grain surfaces; firm to easily friable; grain supported with common silty white tuffaceous matrix; composed of volcanic clasts, felsic mineral and rock grains; carbonaceous fines and coarser greenstone and quartz gravel; intergrades to conglomerate and tuffaceous siltstone in places and can be laminated and banded, but generally exhibits massive structure; some very thin beds of carbonaceous shale and coal also occur in this interval. Tuffaceous Sandstone (6390' - 6510') = light brownish gray with green hues; lower very fine to lower coarse grained; fair sorted; angular to round; low mod sphericity; common mechanical abrasion features on grain surfaces; firm to easily friable; grain supported with common silty white tuffaceous matrix; composed of volcanic clasts, felsic mineral and rock grains; carbonaceous fines, coarser greenstone and quartz; intergrading to tuffaceous siltstone that is crumbly to pulverulent, nodular to wedge like in cuttings habit, dull to earthy in luster; with gritty texture; tuffaceous rocks are often laminated banded and occur in thin to thick beds; interbedded in places with thin beds of coal and carbonaceous shale. Tuffaceous Siltstone (6480' - 6570') = light to medium brownish gray with greenish hues; slightly adhesive; crumbly to pulverulent; irregular to planar fracture; nodular to wedge like cuttings habit; waxy to earthy luster; clayey to gritty texture; fissile with dark black laminae in browner specimens; intergrading to carbonaceous shale and tuffaceous sandstone; thin structure, fissile in places. Tuffaceous Sandstone (6540' - 6600') = light brownish gray with pale brown and light green hue; lower very fine to upper coarse grading to fine gravel; very poor to fair sorted; angular to round; low to high sphericity; common mechanical abrasion surface features; soft to unconsolidated; grain supported with ample tuff ash matrix; composed of volcanics and feldspathic minerals and rock fragments, greenstone; trace quartz; intergrading to tuffaceous siltstone. Tuffaceous Sandstone (6600' - 6660') = light medium grey with pale greenish grey hues; upper very fine to lower coarse; low to moderate sphericity; subangular to subrounded; poor to moderate sorting; unconsolidated to friable; tuff matrix; grain supported; volcanic clasts, greenstone, feldspathic clasts; intergrades with carbonaceous shale/lignitic coal Tuffaceous Siltstone (6660' - 6720') = light medium grey to green grey; soft to friable; crumbly to crunchy to pulverulent tenacity; massive to nodular habit; clayey to gritty texture; waxy to earthy luster; mushy to clumpy consistency; massive to thin bedded; intergrades with tuffaceous sandstone, upper very fine to upper coarse grain; sub angular to subrounded, poor to moderately well sorted, volcanic clasts, greenstone, feldspathic clasts; intergrades with lignitic coal. BCU 7A 16 Tuffaceous Sandstone (6720' - 6780') = light medium grey with greenish grey hues; upper very fine to upper medium grain; low to moderate sphericity; subangular to subrounded; moderate to moderately well sorted; unconsolidated to easily friable; tuff matrix; grain supported volcanic clasts, greenstone, rock fragments; intergrading with tuffaceous siltstone Tuffaceous Sandstone (6780' - 6840') = light medium grey to greenish grey with brownish hues; upper very fine to upper medium grain; subangular to subrounded; moderately sorted; easily friable to friable; tuff matrix; grain supported; volcanic clasts, greenstone, feldspathic and rock clasts; intergrades to carbonaceous claystone, light brown to black, friable to firm friable; crumbly to brittle; massive to blocky, massive to thin bedding Tuffaceous Sandstone (6840' - 6900') = light medium grey to greenish grey with brownish hues; lower very fine to lower medium grain; low to moderate sphericity; subangular to subrounded; poor to moderate sorting; unconsolidated to easily friable; tuff matrix; grain supported; volcanic and greenstone clasts; intergrades to tuffaceous siltstone, medium grey to brownish grey, friable, crumbly to crunchy, massive to thin beds Tuffaceous Sandstone (6900-6960') = light medium grey to greenish grey; lower fine to lower coarse grain; low to moderate sphericity; subangular to subrounded; poor to moderately sorted; unconsolidated to easily friable; tuff matrix; grain supported; volcanic, greenstone clasts; intergrading to tuffaceous siltstone, greenish grey to brownish grey, easily friable, crumbly to pulverulent, waxy to earthy, massive to thin beds Tuffaceous Sandstone (6990' - 7050') = light brownish gray with greenish hues; lower very fine to lower coarse; fair to well sorted; angular to round; low to high sphericity; common signs of mechanical abrasion; unconsolidated to soft; tuff matrix; grain supported but grading to matrix supported with depth; thin bedded; intergrades with tuffaceous siltstone; fining downward to arenaceous matrix supported tuffaceous sandstone, and greenish brown tuffaceous siltstone. Tuffaceous Siltstone (7030' - 7110') = light greenish gray with pale brown and brownish hues; adhesive, cohesive, and slimy where clayey; pulverulent to crunchy; irregular blocky fracture; nodular to wedge like cuttings habit; greasy to dull earthy luster; clayey to gritty texture; banded to laminar structure; occurring in thin beds; intergrading to lower very fine to very coarse grained, silty clay tuff matrix supported tuffaceous sandstone of similar color composed of volcanic and greenstone clasts and some quartz. Tuffaceous Sandstone (7110' - 7170') = light medium grey to greenish grey with brownish hues; upper very fine to lower coarse grain; low to moderate sphericity; subangular to subrounded; moderately to moderately well sorted; unconsolidated to easily friable; silty tuff matrix; grain supported; volcanic, greenstone, and quartz clasts; interbedded with tuffaceous siltstone, soft, pulverulent to crunchy, clayey to silty, cohesive to adhesive, massive to thin bedded Tuffaceous Sandstone (7170' - 7230') = light medium grey to greenish grey; upper very fine to lower very coarse; low to moderate sphericity; subangular to subrounded; poor to moderately sorted ; unconsolidated to friable; silty tuff matrix; grain supported, matrix supported in parts; volcanic, greenstone and quartz clasts; interbedded with tuffaceous siltstone, soft, crumbly to crunchy, blocky to nodular, clayey to silty, massive to thin bedded Tuffaceous Siltstone (7230' - 7290') = light medium grey to greenish grey with brownish grey hues; soft to easily friable; pulverulent to malleable BCU 7A 17 tenacity; blocky to amorphous habit; clayey to gritty texture; cohesive to adhesive to pliable; massive to thin beds; interbedded carbonaceous claystone, tuffaceous Tuffaceous Sandstone (7230' - 7250') = medium grey to dark grey to brownish grey; upper fine to lower coarse grain with occasional very coarse grains; low to moderate sphericity; subangular to subrounded; poor to moderate sorting; unconsolidated to easily friable; silty tuff matrix; grain supported; volcanic, quartz, greenstone and carbonaceous material Tuffaceous Sandstone (7350' - 7410') = medium grey to dark grey; upper fine to upper very coarse grained; low to moderate sphericity; subangular to subrounded; poor to moderately sorted; unconsolidated to firm; silty tuff matrix; grain supported; volcanic, quartz and greenstone clasts; interbedded conglomeritic sandstone, lower coarse to very coarse, firm to moderately hard, Tuffaceous Sandstone (7410' - 7470') = medium gray to greenish gray; soft to unconsolidated; lower very fine to very coarse grading to fine gravel; poor to fair sorted; angular to subrounded; low to moderate sphericity; common grinding; grain supported; composed of light and dark volcanic glass and rock fragments, greenstone, quartz and carbonaceous clasts; intergrading to gritty tuffaceous siltstone, and conglomeratic in part; fining down. Tuffaceous Siltstone (7440' - 7530') = medium gray to greenish gray with light to dark greenish brown hues; crunchy to pulverulent; irregular blocky fracture; tabular to wedge like cuttings; dull to earthy luster; colloidal to gritty texture; nodular to wedge like cuttings habit; common brownish black laminae and some banding; generally thin fissile structure; occurring in thin beds with tuffaceous sandstone intergrades and thin carbonaceous shale and coal lenses. Tuffaceous Sandstone (7530' - 7650') = medium gray to greenish gray; soft to unconsolidated; lower very fine to very coarse grading to fine gravel; poor to fair sorted; angular to subrounded; low to moderate sphericity; common grinding; grain supported; composed of light and dark volcanic glass and rock fragments, greenstone, quartz and carbonaceous clasts and fines; fining down and becoming clayey and increasing in silty tuff matrix with depth; interbedded with carbonaceous shale in places. Tuffaceous Siltstone (7590' - 7650') = greenish and brownish gray; adhesive; crumbly to pulverulent; irregular fracture; nodular butter curl-like cuttings; waxy to earthy luster; clayey to colloidal and gritty texture; laminar to thin structure; intergrading with green tuffaceous claystone and brown carbonaceous shale in places. Tuffaceous Siltstone (7650' - 7710') = medium light grey to greenish grey with brownish hues; soft to easily friable; crumbly to pulverulent to crunchy tenacity; amorphous to nodular to blocky; clayey to gritty texture; waxy to dull to earthy luster; cohesive to pliable; mushy to clumpy; massive to thin bedded; intergrades with tuffaceous sandstone, light to medium grey, upper very fine to upper fine, tuff matrix, volcanic greenstone and quartz clasts Tuffaceous Siltstone (7710' - 7770') = greenish grey to blueish greenish grey to medium grey with brownish hues; crumbly to crunchy to pulverulent tenacity; amorphous to blocky habit; clayey to gritty texture; waxy to earthy luster; cohesive to adhesive; mushy to stiff; intergraded with carbonaceous claystone and tuffaceous sandstone Tuffaceous Siltstone (7770' - 7830') = light medium grey to blue-greenish grey with olive green hues; crumbly to crunchy tenacity; amorphous to blocky habit; clayey to silty with gritty interspersed texture; dull to waxy to earthy luster; mushy to stiff to BCU 7A 18 clumpy; intergraded with tuffaceous sandstone, upper very fine to upper medium, interspersed coarse and very coarse grains; moderate to poor sorting, unconsolidated to easily friable, grain supported. Tuffaceous Sandstone (7830' - 7890') = light greenish gray to light gray with white and brownish hues; lower fine to upper very coarse; fair to well sorted; angular to subrounded; low to moderate sphericity; common signs of mechanical abrasion; grain supported; common silty clay ash and tuff matrix; composed of clear to dark volcanic rock and glass fragments, quartz and carbonaceous fines; intergrading to tuffaceous silt- stone and claystone as described above; conglomeratic in part; interbedded with dark brown banded carbonaceous shale. Tuffaceous Claystone (7900' - 7960') = light gray to medium gray; cohesive to adhesive; malleable; irregular fracture; nodular cuttings habit; dull to greasy luster; colloidal to silty texture; thin laminar structure; intergrading with tuffaceous siltstone and sandstone as described above. Tuffaceous Siltstone (7960' - 8040') = light gray to medium with greenish and brownish hues; crumbly to pulverulent; irregular blocky fracture; wedge like to nodular cuttings habit; dull to earthy and sometimes greasy luster; clayey to gritty texture; thin structure with some laminae; sometimes fissile; intergrading to tuffaceous claystone and very fine to medium grained tuffaceous sandstone; interbedded with thin lignitic to sub- bituminous coal and carbonaceous shale toward bottom of this interval. Tuffaceous Siltstone (8040' - 8100') = light gray to light greenish gray; some adhesive and curdy; pulverulent to malleable with irregular blocky fracture; nodular cuttings habit; dull to earthy and greasy luster; clayey to granular colloidal texture; thin structure; some laminae; often fissile; intergrading to tuffaceous claystone and very fine to fine grained tuffaceous sandstone; interbedded with thin lignitic to sub- bituminous coal and carbonaceous shale in places; more arenaceous with depth. Tuffaceous Siltstone (8100' - 8160') = light gray to light greenish gray; some adhesive and curdy; pulverulent to malleable with irregular blocky fracture; nodular cuttings habit; dull to earthy and greasy luster; gritty granular to colloidal texture; thin structure; some laminae and banding; intergrading with lower fine grain tuffaceous sandstone that is matrix supported and clayey in places and can contain some coarser volcanic and greenstone grains. Tuffaceous Siltstone (8160' - 8220) = light medium grey to light brownish grey; malleable to pulverulent tenacity; amorphous to nodular habit; clayey to gritty texture; waxy to earthy to resinous luster; mushy to pasty to clumpy; intergraded with tuffaceous sand, light medium grey to greenish, lower very fine to lower fine grain; unconsolidated Tuffaceous Siltstone (8220' - 8280') = light medium grey with brownish grey; crumbly to crunchy tenacity; amorphous to nodular to blocky habit; clayey to gritty texture; dull to earthy luster; mushy to clumpy; intergrades with tuffaceous sandstone, upper very fine to lower coarse grain, poorly sorted, unconsolidated to easily friable, grain supported; quartz, volcanics, greenstone Tuffaceous Sandstone (8280' - 8340') = light medium grey to brownish grey with greenish grey hues; upper very fine to upper medium grained; low to moderate sphericity; subangular to subrounded; moderate to moderately well sorted; unconsolidated to friable; tuff/ash matrix; grain supported; quartz, volcanics, interspersed greenstone; intergraded with tuffaceous siltstone, light grey to medium grey with brownish hues, crumbly to crunchy tenacity, clayey to gritty texture, mushy to clumpy. BCU 7A 19 Tuffaceous Siltstone (8340' - 8430') = light to medium gray with white and greenish hues; adhesive; curdy to mushy; crumbly to malleable; irregular blocky to planar fracture; nodular to wedge like cuttings habit; greasy waxy to dull earthy luster; colloidal gritty texture; thin structure; laminated and fissile in places; intergrading with very fine and fine grained sandstone that is grain supported in part and matrix supported elsewhere, and composed of fair to well sorted subangular to subrounded, low to moderate sphericity volcanic, greenstone, and quartz grains, some in floating fabrics; these rocks also grade to tuffaceous claystone. Tuffaceous Siltstone (8430' - 8490') = light medium grey to blueish greenish grey to medium grey; soft to easily friable; malleable to pulverulent tenacity; massive to nodular to wedge like; clayey to silty texture; waxy to earthy luster; cohesive to colloidal; clumpy to punky; massive to thin bedded; intergrades with tuffaceous claystone and carbonaceous claystone, dark brown to black, firm Tuffaceous Siltstone (8490' - 8550') = light medium grey to medium grey with brownish and blueish greenish grey; soft to easily friable; malleable to pulverulent tenacity; massive to nodular to tabular habit; clayey to silty with interspersed gritty texture; waxy to earthy luster; cohesive to colloidal; clumpy to tacky; massive to thin bedded; intergraded with tuffaceous sandstone, unconsolidated, lower very fine to upper medium grained, quartz grains, volcanic grains Tuffaceous Siltstone (8550' - 8610') = light to medium gray with greenish and brownish hues; malleable crumbly to pulverulent; irregular blocky fracture; nodular to wedge like cuttings habit; greasy to dull earthy luster; colloidal to granular with common lower fine sand grains; thin to thick structure; inter- grading to fine grained, friable, matrix supported tuffaceous sandstone; interbedded with thin coal that is slightly off gassing, and carbonaceous shale; increasingly arenaceous with depth. Tuffaceous Siltstone (8610' - 8700') = light gray to medium brownish gray with greenish hues; malleable crumbly to pulverulent; irregular blocky fracture; nodular to wedge like cuttings habit; greasy to dull earthy luster; colloidal to granular with common fine to medium grains; thin to thick structure; inter- grading to fine grained, friable, matrix supported and some grain supported tuffaceous sandstone; interbedded with thin coal and carbonaceous shale in places; slight coarsening down. Tuffaceous Sandstone (8700' - 8790') = light gray to medium brownish gray with light greenish gray hues; lower very fine grained to lower medium grained with some coarser grains; poor to fair sorted; subangular to subrounded; mod to high sphericity; common polish; soft to easily friable; matrix supported with silty clay tuff matrix, some floating fabric; composed of light and dark volcanics, some quartz, trace greenstone; intergrading to tuffaceous siltstone and claystone; interbedded with thin coal of sub bituminous grade and carbonaceous shale; matrix becoming more clayey and slightly more adhesive with depth. Tuffaceous Sandstone (8790' - 8850') = light medium grey with brownish hues, upper very fine to upper medium grained; low sphericity; subangular to subrounded; moderately low to moderately sorted; unconsolidated to easily friable; tuff/ ash matrix; grain supported; quartz and volcanic clasts; intergraded with tuffaceous siltstone and tuffaceous claystone, light medium grey with brown to black carbonaceous claystone, easily friable, crumbly to malleable, blocky to amorphous, colloidal to cohesive, massive to thin bedded Tuffaceous Sandstone (8850' - 8910') = light medium grey with brownish to blackish hues;, lower very fine to upper fine grain; low sphericity; subangular to subrounded; low moderate to moderate sorting; unconsolidated to easily friable; tuff matrix; BCU 7A 20 grain supported, matrix supported in part; quartz, volcanic and rock fragment clasts; intergraded with tuffaceous siltstone and tuffaceous, claystone, light medium grey, easily friable, crumbly to pulverulent, blocky to amorphous, colloidal to cohesive Tuffaceous Sandstone (8910' - 8970') = light medium grey with brownish and greenish hues; upper very fine to upper medium grain; low to moderate sphericity; subangular to subrounded; low moderate to moderate sorting; unconsolidated to easily friable; tuff matrix, grain supported; quartz and volcanic clasts with occasional greenstone; interbedded with tuffaceous siltstone Tuffaceous Siltstone (8970' - 9030') = light medium grey to light brownish grey; soft to easily friable; crumbly to crunchy tenacity; blocky to amorphous habit; silty to gritty texture; dull to greasy luster; colloidal to cohesive; massive to thin bedding; interbedded with carbonaceous claystone/coal, black, brittle to firm, blocky to platy Tuffaceous Siltstone (9030' - 9090') = light medium grey to light brownish grey to brownish grey; soft to easily friable; crumbly to crunchy to pulverulent tenacity; amorphous to blocky habit; clayey to gritty texture; dull to earthy luster; colloidal to cohesive; massive to thin bedded; intergrades with tuffaceous sandstone, upper very fine to upper fine grain, unconsolidated, grain supported and matrix supported varieties. Tuffaceous Siltstone (9090' - 9180') = light grey to light brownish grey; curdy and slightly adhesive; crumbly to pulverulent; amorphous to nodular cuttings habit; irregular to blocky fracture; greasy to dull earthy luster; clayey to gritty texture; thin to thick structure; intergrading to matrix supported and some grain supported lower very fine to fine grained tuffaceous sandstone; also to tuffaceous claystone; interbedded with thin carbonaceous shale and coal beds; cuttings of coal in spot samples taken in high gas zones were only 10 percent of the sample, but were observed lightly to vigorously off gassing; coal grades from lignitic to low grade bituminous. Tuffaceous Claystone (9180' - 9210') = light brownish gray to medium gray; pasty to curdy; adhesive; malleable to crumbly; massive to nodular cuttings habit; greasy to dull luster; smooth to silty texture; thin structure; intergrading with tuffaceous siltstone. Tuffaceous Siltstone (9210' - 9300') = light brownish grey; curdy, clumpy, and slightly adhesive; crumbly to pulverulent; amorphous to nodular cuttings habit; irregular to blocky fracture; greasy to dull earthy luster; clayey to gritty texture; thin to thick structure; intergrading to matrix supported tuffaceous very fine grained tuffaceous sandstone and more commonly tuffaceous claystone that is interbedded with thin gassy coal and thin carbonaceous shale beds; there is 2-10% nut plug additive in samples. Tuffaceous Siltstone (9300' - 9350') = light brownish grey to medium gray; curdy and adhesive; crumbly to pulverulent; amorphous to nodular cuttings habit; irregular to blocky fracture; greasy to dull earthy luster; clayey to gritty texture; thin structure; intergrading to tuffaceous claystone and some dark gray, fine, grain supported sandstone. Coal (9360' - 9390') = black to brownish black; brittle to crunchy; sub- conchoidal to splintery fracture; elongated tabular cuttings habit; resinous luster; matte to mottled texture; thin beds with some banded structure; lignitic to low grade bituminous; cuttings off gassing; interbedded with tuffaceous siltstone and sandstone, and carbonaceous shale. Tuffaceous siltstone (9360' - 9450') = light to medium gray to brownish gray; curdy; slightly adhesive; crumbly to pulverulent; irregular blocky fracture; wedge like cuttings habit; dull earthy to waxy luster; clayey to gritty; few black laminae; BCU 7A 21 intergrading with tuffaceous claystone and sandstone; interbedded with thin carbonaceous shale and coal in places. Tuffaceous siltstone (9450' - 9510') = light to medium gray to brownish gray; curdy; slightly adhesive; crumbly to pulverulent; irregular blocky fracture; wedge like cuttings habit; dull earthy to waxy luster; clayey to gritty; common banding with dark fines; some laminae; trace greenstone; grittier with depth. Tuffaceous siltstone (9510' - 9570') = light brownish grey to light medium grey; soft to easily friable; soft to crunchy tenacity; blocky to tabular habit; clayey to slightly gritty texture; dull to dull earthy luster; slightly adhesive; mushy to punky; laminae to thin beds with carbonaceous material that decreases with depth; intergrades with upper very fine to lower fine grain sand Tuffaceous siltstone (9570' - 9630') = light medium brownish grey to light brownish grey to light grey; soft to easily friable; soft to crunchy tenacity blocky to wedge like habit; clayey to gritty texture; earthy luster; mushy to clumpy to stiff; laminate to thin beds with carbonaceous material; intergrading with tuffaceous sandstone; downward coarsening to upper very fine to upper fine grain, unconsolidated, tuff matrix, quartz grain Tuffaceous siltstone (9630' - 9690') = light medium grey to light medium brown grey; soft to easily friable; soft to crunchy tenacity; blocky to amorphous habit; clayey to gritty texture; earthy luster; mushy to clumpy; laminated to thin beds with carbonaceous material; intergrades with carbonaceous claystone black, brittle to crunchy, low grade lignitic coal; intergrades with tuffaceous sandstone, upper very fine to upper fine grain Tuffaceous siltstone (9690' - 9750') = medium grey to brownish grey with blackish brown hues; soft to friable; brittle to crumbly to crunchy tenacity; blocky to nodular habit; clayey to gritty texture; earthy to resinous luster; mushy to tacky consistency; laminate to thin to massive bedding; intergrading with poorly consolidated and poorly sorted tuffaceous sandstone, upper very fine to upper fine grain Coal (9755' - 9775') = black with brownish black hues; firm to moderately hard; blocky to wedge like to platy fracture Tuffaceous siltstone (9750' - 9800') = light medium grey to brownish grey; soft to friable; crumbly to crunchy tenacity; blocky to nodular habit; clayey to gritty texture; earthy to resinous luster; mushy to tacky consistency; laminated to thin bedding; intergrades with tuffaceous sandstone, upper very fine to lower medium grain, poor to moderate sorting, unconsolidated to easily friable BCU 7A 22 3.3 Connection / Trip Gases 50 units = 1% Methane Equivalent Date Type Trip From (feet) Trip To (feet) Maximum Gas (Units) 06-04-2014 WIPER 3388 2356’ 3 06-04-2014 WIPER 4568 3310 4 06-06-2014 WIPER 5997 4568 20 06-07-2014 WIPER 6989 2356 2 06-08-2014 RIH / WD 2356 6989 48 06-10-2014 WIPER 8157 7075 8 06-11-2014 POOH 8604 SURFACE 8 06-12-2014 RIH SURFACE 8604 22 06-14-2014 POOH 9349 SURFACE 7 06-15-2014 RIH SURFACE 8283 12 06-16-2014 RIH cntd 8283 9349 70 06-17-2014 RIH SURFACE 9361 46 06-18-2014 RIH SURFACE 9359 9 06-19-2014 MAD 9800 6539 132 06-20-2014 MAD 6539 5000 19 06-20-2014 RIH 5000 9800 2358 06-21-2014 POOH 9800 SURFACE 39 06-22-2014 CASING SURFACE 9765 2187 BCU 7A 23 3.4 Sampling Program / Sample Dispatch Set Type / Purpose Frequency* Interval Dispatched to A, B Washed and dried reference samples 30 ft 10 ft 9380 ft – 10410 ft 10410 ft – 11525 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. BCU 7A 24 4 DRILLING DATA 4.1 Directional Survey Data* Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 0 0 0 0 0.00 N 0.00 E 0 TIE-IN 2336 0.03 108.26 2335.98 3.41 S 2.66 E 1.88 0.08 2417.19 3.9 52.31 2417.11 1.73 S 4.86 E 4.39 4.78 2479.72 5.72 53.45 2479.42 1.43 N 9.05 E 9.15 2.91 2542.72 7.56 54.05 2541.99 5.73 N 14.93 E 15.8 2.92 2603.91 9.35 54.41 2602.51 10.99 N 22.23 E 24.04 2.93 2666.84 11.02 58.81 2664.45 17.08 N 31.53 E 34.41 2.93 2729.38 13.2 63.48 2725.6 23.36 N 43.04 E 46.98 3.82 2790.12 17.26 70.05 2784.19 29.53 N 57.72 E 62.63 7.25 2853.31 17.73 75.5 2844.47 35.14 N 75.85 E 81.53 2.7 2915.38 21.69 79.03 2902.89 39.69 N 96.27 E 102.45 6.66 2976.47 23.3 81.6 2959.33 43.61 N 119.30 E 125.8 3.09 3039.61 25.65 80.21 3016.79 47.76 N 145.13 E 151.92 3.84 3102.57 30.87 78.08 3072.23 53.42 N 174.38 E 181.71 8.44 3162.99 31.72 78.14 3123.86 59.88 N 205.09 E 213.09 1.41 3226.93 33.31 78.16 3177.78 66.94 N 238.73 E 247.46 2.49 3288.27 36.57 78.97 3228.05 73.89 N 273.16 E 282.58 5.37 3350.03 39.85 80.33 3276.58 80.74 N 310.73 E 320.75 5.47 3410.47 38.97 80.58 3323.28 87.11 N 348.57 E 359.08 1.48 3472.8 39.47 81.05 3371.57 93.40 N 387.47 E 398.44 0.94 3536.12 38.41 80.97 3420.82 99.61 N 426.78 E 438.18 1.68 3598.13 38.11 81.51 3469.51 105.46 N 464.73 E 476.51 0.72 3659.54 36.87 80.3 3518.23 111.37 N 501.63 E 513.83 2.35 3721.94 35.76 80.36 3568.51 117.57 N 538.06 E 550.75 1.78 3784.05 35.02 79.89 3619.15 123.74 N 573.50 E 586.7 1.27 3846.37 33.92 79.23 3670.52 130.13 N 608.19 E 621.95 1.86 3908.5 34.4 78.92 3721.93 136.74 N 642.44 E 656.83 0.82 3970.71 33.71 78.87 3773.47 143.45 N 676.62 E 691.66 1.11 4032.7 33.87 77.75 3824.99 150.44 N 710.38 E 726.14 1.04 4094.1 35.27 77.6 3875.55 157.87 N 744.42 E 760.97 2.28 4156.51 35.33 76.7 3926.49 165.89 N 779.58 E 797.03 0.84 4219.31 35.47 77.36 3977.68 174.06 N 815.03 E 833.41 0.65 4280.48 34.71 76.57 4027.73 181.99 N 849.29 E 868.57 1.45 4343.12 34.89 77.01 4079.17 190.16 N 884.09 E 904.3 0.49 4405.32 35.03 78.24 4130.15 197.79 N 918.89 E 939.94 1.15 4467.68 34.67 78.56 4181.33 204.96 N 953.80 E 975.57 0.65 4528.89 34.2 78.05 4231.81 211.97 N 987.69 E 1010.18 0.9 Measured Depth Inc. (o) Azi. (o) True Vertical Northing (ft) Easting (ft) Vertical Section Dogleg Rate BCU 7A 25 (ft) Depth (ft) (ft) (o/100ft) 4590.1 35.47 79.33 4282.05 218.82 N 1021.98 E 1045.14 2.39 4652.43 36.31 79.85 4332.55 225.43 N 1057.91 E 1081.66 1.44 4715.58 35.65 80.27 4383.65 231.83 N 1094.46 E 1118.74 1.12 4777.82 34.7 79.43 4434.52 238.15 N 1129.75 E 1154.57 1.71 4840.19 35.13 80.34 4485.67 244.41 N 1164.89 E 1190.24 1.08 4902.35 34.19 80.1 4536.8 250.42 N 1199.73 E 1225.57 1.53 4964.51 35.58 78.71 4587.79 256.96 N 1234.67 E 1261.1 2.58 5026.95 35.12 78.58 4638.71 264.07 N 1270.09 E 1297.22 0.75 5089.06 34.5 78.74 4689.71 271.05 N 1304.85 E 1332.68 1.01 5151.32 34.78 78.78 4740.93 277.94 N 1339.56 E 1368.06 0.45 5213.44 255.05 77.68 4791.87 285.20 N 1374.37 E 1403.62 1.10 5275.67 35.66 76.26 4842.63 293.32 N 1409.45 E 1439.62 1.64 5337.79 35.24 75.85 4893.23 302.00 N 1444.41 E 1475.63 0.78 5399.88 34.77 76.25 4944.09 310.59 N 1478.98 E 1511.23 0.84 5462.12 35.29 77.54 4995.05 318.69 N 1513.78 E 1546.95 1.45 5524.35 34.93 77.76 5045.96 326.34 N 1548.74 E 1582.74 0.62 5585.8 34.31 78.36 5096.53 333.57 N 1582.89 E 1617.65 1.15 5647.8 35.38 77.9 5147.42 340.85 N 1617.56 E 1653.07 1.77 5710.21 35.24 78.31 5198.34 348.29 N 1652.86 E 1689.14 0.43 5771.75 35.08 78.82 5248.65 355.31 N 1687.59 E 1724.58 0.54 5833.88 34.51 78.2 5299.68 362.37 N 1722.33 E 1760.03 1.08 5895.85 34.81 80.29 5350.65 368.95 N 1756.96 E 1795.26 1.98 5957.46 33.72 80.34 5401.56 374.79 N 1791.15 E 1829.92 1.77 6018.42 35.04 80.43 5451.87 380.54 N 1825.09 E 1864.31 2.16 6080.82 34.84 80.67 5503.03 386.40 N 1860.34 E 1900.01 0.39 6143.62 34.52 80.84 5554.67 392.15 N 1895.61 E 1935.69 0.53 6205.38 35.83 80.39 5605.15 397.95 N 1930.71 E 1971.23 2.16 6267.55 35.59 81.04 5655.63 403.80 N 1966.52 E 2007.47 0.72 6329.57 35.1 81.71 5706.22 409.19 N 2001.99 E 2043.29 1.01 6392.06 34.79 82.03 5757.44 414.25 N 2037.43 E 2078.99 0.58 6453.48 35.49 80.7 5807.67 419.56 N 2072.38 E 2114.28 1.69 6516.02 35.71 79.68 5858.52 425.76 N 2108.25 E 2150.65 1.01 6577.92 35.41 80.31 5908.88 432.02 N 2143.70 E 2186.63 0.76 6639.53 35.37 77.7 5959.11 438.82 N 2178.72 E 2222.29 2.45 6701.76 35.16 77.74 6009.92 446.46 N 2213.83 E 2258.22 0.33 6762.94 34.68 78.25 6060.08 453.75 N 2248.08 E 2293.25 0.93 6826.73 34.84 76.39 6112.49 461.73 N 2283.56 E 2329.61 1.68 6887.89 34.76 76.01 6162.71 470.06 N 2317.46 E 2364.5 0.39 6948.33 34.4 75.81 6212.47 478.41 N 2350.73 E 2398.78 0.62 7011.53 33.92 76.5 6264.77 486.90 N 2385.18 E 2434.25 0.97 7074.28 33.47 76.49 6316.98 495.03 N 2419.03 E 2469.05 0.72 7136.25 33.09 76.42 6368.78 503.00 N 2452.09 E 2503.05 0.62 Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) BCU 7A 26 7198.89 32.63 75.74 6421.4 511.17 N 2485.08 E 2537.02 0.94 7261.24 31.83 75.55 6474.14 519.41 N 2517.30 E 2570.24 1.29 7323.6 31.48 75.75 6527.23 527.53 N 2549.00 E 2602.94 0.59 7384.35 30.28 76.31 6579.37 535.06 N 2579.25 E 2634.1 2.03 7447.01 27.25 76.19 6634.29 542.22 N 2608.54 E 2664.24 4.83 7508.87 25.44 76.63 6689.72 548.67 N 2635.22 E 2691.68 2.95 7571.05 24.62 76.54 6746.06 554.78 N 2660.81 E 2717.98 1.32 7633.32 23.45 76.47 6802.93 560.70 N 2685.47 E 2743.34 1.88 7695.77 21.32 76.96 6860.67 566.17 N 2708.62 E 2767.12 3.42 7756.28 19.44 76.67 6917.39 570.97 N 2729.13 E 2788.19 3.11 7819.2 16.86 76.48 6977.17 575.52 N 2748.20 E 2807.78 4.11 7880.7 15.09 75.29 7036.3 579.64 N 2764.61 E 2824.69 2.93 7942.13 14.5 74.92 7095.69 583.67 N 2779.77 E 2840.36 0.97 8005.58 13.94 74.6 7157.19 587.77 N 2794.81 E 2855.93 0.89 8067.55 13.67 76.16 7217.37 591.50 N 2809.12 E 2870.7 0.74 8128.64 13.38 76.58 7276.77 594.87 N 2823.00 E 2884.98 0.5 8191.27 13.24 76.12 7337.72 598.27 N 2837.02 E 2899.39 0.27 8253.33 12.59 77.09 7398.21 601.49 N 2850.51 E 2913.26 1.11 8316.12 12.46 76.95 7459.5 604.54 N 2863.78 E 2926.88 0.22 8378.04 11.51 76.59 7520.07 607.48 N 2876.30 E 2939.73 1.53 8440.28 10.83 74.84 7581.13 610.45 N 2887.98 E 2951.78 1.22 8501.9 10.54 74.44 7641.69 613.48 N 2898.99 E 2963.18 0.49 8560.91 10.2 73.06 7699.73 616.45 N 2909.19 E 2973.77 0.71 8626.2 9.79 73.67 7764.03 619.69 N 2920.05 E 2985.07 0.65 8688.48 9.49 72.45 7825.43 622.73 N 2930.02 E 2995.46 0.58 8750.41 9.22 73.64 7886.54 625.67 N 2939.65 E 3005.49 0.54 8812.49 8.55 73.5 7947.87 628.38 N 2948.85 E 3015.05 1.08 8874.98 8.25 71.83 8009.69 631.10 N 2957.56 E 3024.14 0.62 8937.43 8.51 74.81 8071.48 633.71 N 2966.28 E 3033.22 0.81 8999.8 8.58 76.87 8133.15 635.97 N 2975.27 E 3042.48 0.5 9058.92 8.36 77.04 8191.63 637.94 N 2983.76 E 3051.19 0.38 9123.88 8.24 77.96 8255.91 639.97 N 2992.91 E 3060.57 0.28 9186.05 7.93 78.98 8317.46 641.72 N 3001.48 E 3069.31 0.55 9247.1 7.28 76.32 8377.97 643.44 N 3009.37 E 3077.39 1.21 9309.62 6.83 75.15 8440.02 645.33 N 3016.81 E 3085.06 0.76 9370.85 6.19 73.86 8500.85 647.18 N 3023.50 E 3091.99 1.07 9433.18 5.73 74.8 8562.85 648.93 N 3029.73 E 3098.45 0.75 9495.1 5.23 75.83 8624.48 650.43 N 3035.45 E 3104.36 0.82 9556.86 4.75 71.82 8686.01 651.92 N 3040.61 E 3109.71 0.96 9619.88 26.23 66.11 8748.84 653.67 N 3045.21 E 3114.58 1.09 9681.89 3.83 64.09 8810.69 655.50 N 3049.17 E 3118.83 0.68 9743.55 3.58 59.92 8872.22 657.37 N 3052.69 E 3122.66 0.60 Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 9761.85 3.44 60.02 8890.49 657.93 N 3053.66 E 3123.73 0.77 BCU 7A 27 9800 3.44 60.02 8928.57 659.07 N 3055.64 E 3125.91 0 *Survey / Directional Data provided by Hilcorp BC U 7 A 28 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 7 . 8 7 5 M M 6 4 D P D C 5X 1 2 0. 5 5 2 2 23 5 9 ’ 8 6 0 3 ’ 6 2 4 4 ’ 1 1 3 . 2 9 5 5 . 1 2 1 0 . 0 5 6 . 4 2 0 0 7 2 - 5 - R O - F - X - 1 - B P - R O P 2 7 . 8 7 5 E Q H 2 0 R I N S E R T 3X 1 5 0. 5 1 7 7 86 0 3 ’ 9 3 4 9 ’ 7 4 6 ’ 2 7 . 1 8 2 7 . 4 5 1 8 . 4 6 3 . 6 2 3 3 0 8 - 8 - L C - A - F - 3 - S D - D T F 3 7 . 8 7 5 H D B S M M 5 5 P D C 5X 1 2 0. 5 5 2 2 93 6 1 ’ 9 8 0 0 ’ 4 3 9 ’ 8 . 4 6 7 5 1 . 8 5 3 . 8 6 3 . 0 2 2 3 7 1 - 2 - J D - G - X - 1 - C T - T D BC U 7 A 29 4. 3 Mu d R e c o r d Co n t r a c t o r : B a r o i d Mu d T y p e : E Z - M u d 6 % K C l 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 / 0 2 / 2 0 1 4 2 3 7 6 ’ 9 . 0 5 6 3 1 4 2 0 6 / 8 / 1 1 4 . 8 2 . 8 0 . 0 / 9 4 . 7 0 2 . 5 9 . 8 0 . 1 5 3 0 0 0 0 1 6 0 06 / 0 3 / 2 0 1 4 2 6 6 6 ’ 9 . 1 0 6 1 1 4 1 9 5 / 7 / 9 5 . 0 3 . 0 0 . 0 / 9 4 . 4 0 . 1 0 2 . 5 9 . 6 0 . 2 5 3 1 0 0 0 1 6 0 06 / 0 4 / 2 0 1 4 3 8 2 3 ’ 9 . 1 0 7 1 1 9 2 4 5 / 7 / 1 0 4 . 0 3 . 2 0 . 0 / 9 4 . 3 0 . 1 0 2 . 5 1 0 . 0 0 . 6 5 3 1 0 0 0 1 2 0 06 / 0 5 / 2 0 1 4 5 0 7 4 ’ 9 . 1 0 6 9 2 2 2 5 6 / 8 / 1 0 4 . 2 3 . 2 0 . 0 / 9 4 . 3 0 . 1 5 2 . 5 1 0 . 3 0 . 7 0 3 0 0 0 0 1 0 0 06 / 0 6 / 2 0 1 4 6 2 9 2 ’ 9 . 1 0 6 8 2 0 2 3 5 / 7 / 9 4 . 0 3 . 2 0 . 0 / 9 4 . 3 0 . 1 5 3 . 0 9 . 4 0 . 3 0 3 1 0 0 0 2 8 0 06 / 0 7 / 2 0 1 4 6 9 8 9 ’ 9 . 1 5 5 6 1 7 2 1 5 / 7 / 9 3 . 8 3 . 4 0 . 0 / 9 4 . 0 0 . 1 0 4 . 0 8 . 5 0 . 2 0 3 2 0 0 0 2 0 0 06 / 0 8 / 2 0 1 4 7 5 8 4 ’ 9 . 2 5 6 1 2 1 2 2 5 / 7 / 1 1 3 . 8 4 . 3 0 . 0 / 9 3 . 1 0 . 1 0 4 . 0 9 . 4 0 . 4 0 3 2 0 0 0 1 2 0 06 / 0 9 / 2 0 1 4 8 0 2 5 ’ 9 . 2 5 6 2 2 4 2 4 4 / 6 / 9 3 . 0 4 . 6 2 . 4 / 9 0 . 5 0 . 0 5 3 . 8 1 0 . 0 0 . 4 0 3 2 0 0 0 1 2 0 06 / 1 0 / 2 0 1 4 8 4 3 6 ’ 9 . 3 0 6 3 2 5 2 2 4 / 7 / 9 2 . 8 4 . 7 1 . 6 / 9 1 . 1 0 . 0 5 3 . 5 9 . 9 0 . 6 0 3 3 0 0 0 1 4 0 06 / 1 1 / 2 0 1 4 8 6 0 3 ’ 9 . 2 5 6 3 2 0 1 8 4 / 7 / 8 2 . 9 4 . 2 1 . 4 / 9 1 . 8 0 . 1 0 3 . 5 9 . 4 0 . 4 0 3 3 0 0 0 1 8 0 06 / 1 2 / 2 0 1 4 8 6 5 8 ’ 9 . 3 5 5 4 1 9 1 7 4 / 5 / 6 3 . 0 4 . 6 1 . 5 / 9 1 . 3 0 . 1 0 3 . 5 8 . 6 0 . 2 0 3 3 0 0 0 2 0 0 06 / 1 3 / 2 0 1 4 9 2 8 6 ’ 9 . 3 5 5 3 1 7 1 5 4 / 7 / 1 3 . 2 5 . 0 1 . 5 / 9 1 . 1 0 . 1 0 4 . 0 9 . 4 0 . 2 5 3 0 0 0 0 1 6 0 06 / 1 4 / 2 0 1 4 9 3 4 9 ’ 9 . 3 5 5 5 1 7 2 2 5 / 1 0 / 1 5 3 . 2 4 . 8 1 . 5 / 9 1 . 1 0 . 1 0 4 . 5 9 . 4 0 . 4 5 3 3 0 0 0 2 0 0 06 / 1 5 / 2 0 1 4 9 3 4 9 ’ 9 . 4 0 6 1 1 8 2 1 5 / 1 1 / 1 4 3 . 0 5 . 2 1 . 5 / 9 0 . 8 0 . 1 0 4 . 5 1 0 . 0 0 . 6 0 3 1 0 0 0 1 8 0 06 / 1 6 / 2 0 1 4 9 3 5 5 ’ 9 . 4 0 6 0 1 6 1 9 5 / 9 / 1 3 3 . 4 5 . 4 1 . 3 / 9 1 . 0 0 . 1 0 4 . 5 9 . 8 0 . 6 0 2 9 0 0 0 2 0 0 06 / 1 7 / 2 0 1 4 9 3 6 1 ’ 9 . 3 0 5 2 1 4 1 7 4 / 9 / 1 2 3 . 4 4 . 9 1 . 0 / 9 1 . 7 0 . 0 5 4 . 5 9 . 8 0 . 5 0 2 9 5 0 0 8 0 06 / 1 8 / 2 0 1 4 9 3 6 1 ’ 9 . 2 5 5 6 1 5 2 1 6 / 1 2 / 1 6 3 . 2 4 . 4 1 . 0 / 9 2 . 3 0 . 0 1 4 . 0 9 . 6 0 . 3 5 2 9 0 0 0 8 0 06 / 1 9 / 2 0 1 4 9 8 0 0 ' 9 . 4 0 5 4 1 6 2 0 6 / 1 4 / 1 9 3 . 6 5 . 5 0 . 0 / 9 2 . 1 0 . 1 0 5 . 0 9 . 4 0 . 3 5 2 9 5 0 0 2 0 0 06 / 2 0 / 2 0 1 4 9 8 0 0 ' 9 . 3 5 5 2 1 4 2 0 6 / 1 5 / 1 9 3 . 5 4 . 9 0 . 0 / 9 2 . 6 0 . 0 1 4 . 5 9 . 4 0 . 3 5 3 0 5 0 0 1 6 0 06 / 2 1 / 2 0 1 4 9 8 0 0 ' 9 . 4 0 5 5 1 4 2 0 6 / 1 4 / 1 9 3 . 8 5 . 3 0 . 0 / 9 2 . 3 0 . 0 1 5 . 0 9 . 0 0 . 2 5 2 9 5 0 0 8 0 06 / 2 1 / 2 0 1 4 9 8 0 0 ' 9 . 4 0 5 5 1 4 2 1 6 / 1 6 / 1 9 4 . 0 5 . 2 0 . 0 / 9 2 . 4 0 . 0 1 5 . 0 9 . 1 0 . 2 0 3 0 0 0 0 1 2 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 7A 30 5 DAILY REPORTS Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Joe Grubb, Jim Greco DATE: June 2, 2014 DEPTH 2376' PRESENT OPERATION: M/U BHA TIME: 23:59:47 YESTERDAY 2359' 24 HOUR FOOTAGE 20' CASING INFORMATION 9.625" @ 2336' 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 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 2,376'/2,376' MW 9.05 VIS 63 PV 13 YP 20 Gels 6/8/11 FL 4.8 FC 1/2 SOL 2.8 NAF/W 0.0/94.7 SD - MBT 2.5 pH 9.8 ALK 0.15 Cl- 30000 Ca+ 160 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND PENTANE (C-5) @ @ HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling formation PRESENT LITHOLOGY Tuffaceous claystone (80%); coal (20%) DAILY ACTIVITY SUMMARY Set whipstock at 2,359'; began milling window from 2,336' to 2,343'; pumped hi-vis sweep detecting 50% increase in metal shavings; milled window to 2347'; observed significant decrease torque and ROP; pumped 20bbl Hi-Vis sweep, detecting 10% increase in fine shavings; decision made to POOH to inspect milling assembly; POOH; C/O mill, RIH; continue milling window to 2,376' (TOW at 2,336', BOW at 2,353'); Perform FIT to 235psi; POOH to surface, L/D milling assembly; presently M/U BHA. Recovered a total of 572lbs. of metal. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan __DAILY COST: $2783.50 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Joe Grubb, James Sweetsir DATE: Jun 03, 2014 DEPTH 2681' PRESENT OPERATION: Drilling TIME: 23:59:58 YESTERDAY 2376' 24 HOUR FOOTAGE 305' CASING INFORMATION 9.625" @ 2336' 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 4 7.875" HDBS MM64D 12460625 5x12/0.5522 2376' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 130.1 @ 2660' 1.1 @ 2617' 87.3 99.09359 FT/HR SURFACE TORQUE 3483 @ 2669' 2488 @ 2438' 1818.5 0.00000 FT-LBS WEIGHT ON BIT 1 @ 2675' 0 @ 2522' 0.2 0.00000 KLBS ROTARY RPM 66 @ 2524' 11 @ 2425' 32.4 0.00000 RPM PUMP PRESSURE 1942 @ 2408' 1548 @ 2650' 1630.6 1572.30005 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 2,666'/2,665' MW 9.1 VIS 61 PV 14 YP 19 Gels 5/7/9 FL 5.0 FC 1/2 SOL 3.0 NAF/W 0.0/94.4 SD 0.1 MBT 2.5 pH 9.6 ALK 0.25 Cl- 31000 Ca+ 160 MWD SUMMARY INTERVAL 2376' TO TOOLS Bit, directional, gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 10 @ 2439' 0 @ 2680' 1.0 TRIP GAS 0 CUTTING GAS 0 @ 2681' 0 @ 2681' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 4760 @ 2597' 12 @ 2452' 788.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 2681' 0 @ 2681' 0.0 CONNECTION GAS: AVG 0 PROPANE (C-3) 0 @ 2681' 0 @ 2681' 0.0 CONNECTION GAS: CURRENT 0 BUTANE (C-4) 0 @ 2681' 0 @ 2681' 0.0 CURRENT AVG BACKGROUND 1/1 PENTANE (C-5) 0 @ 2681' 0 @ 2681' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling formation PRESENT LITHOLOGY Tuffaceous claystone (70%), sand (30%) DAILY ACTIVITY SUMMARY Continue M/U BHA, RIH to 2302 and R/U Wireline; drilled to 2271 and POOH with Gyro and L/D Wireline; continued drilling ahead; currently at 2681'. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Joe Grubb, James Sweetsir DATE: Jun 04, 2014 DEPTH 3856' PRESENT OPERATION: Drilling TIME: 23:59:26 YESTERDAY 2681' 24 HOUR FOOTAGE 1175' CASING INFORMATION 9.625" @ 2336' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3536.12' 38.14 80.97 3420.82' 3598.13' 38.11 81.51 3469.51' 3659.54' 36.87 80.38 3518.23' 3721.94' 35.76 80.36 3568.51' 3784.05' 35.02 79.89 3619.15' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 7.875" HDBS MM64D 12460625 5x12/0.5522 2376' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 589.7 @ 3141' 2.0 @ 2725' 96.6 92.21034 FT/HR SURFACE TORQUE 9216 @ 2862' 378 @ 3362' 2242.1 4461.47998 FT-LBS WEIGHT ON BIT 16 @ 2863' 0 @ 3275' 1.6 3.15000 KLBS ROTARY RPM 74 @ 3442' 0 @ 3108' 39.1 69.56000 RPM PUMP PRESSURE 1900 @ 3603' 1460 @ 3361' 1665.4 1714.22998 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 3,823'/3,652' MW 9.10 VIS 71 PV 19 YP 24 Gels 5/7/10 FL 4.0 FC 1/2 SOL 3.2 NAF/W 0.0/94.3 SD 0.1 MBT 2.5 pH 10.0 ALK 0.65 Cl- 31000 Ca+ 120 MWD SUMMARY INTERVAL 2376' TO TOOLS Bit, directional, gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 54 @ 2970' 0 @ 2813' 5.0 TRIP GAS 0 CUTTING GAS 0 @ 3856' 0 @ 3856' 0.0 WIPER GAS 3 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 15053 @ 2970' 78 @ 2705' 1158.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 230 @ 2912' 0 @ 3011' 6.0 CONNECTION GAS: AVG 0 PROPANE (C-3) 0 @ 3856' 0 @ 3856' 0.0 CONNECTION GAS: CURRENT 0 BUTANE (C-4) 0 @ 3856' 0 @ 3856' 0.0 CURRENT AVG BACKGROUND 5/5 PENTANE (C-5) 0 @ 3856' 0 @ 3856' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling formation PRESENT LITHOLOGY Tuffaceous sandstone/sand (90%), tuffaceous siltstone (10%) DAILY ACTIVITY SUMMARY Continued drilling ahead from 2681’; pumped Hi-Vis sweep at 2768' and observed a 100% increase in cuttings; drilled to 3388'; CBU; short trip to window to wipe hole clean; RIH, singling in, pumped Hi-Vis sweep once on bottom observing 50% increase in cuttings; drilled to 3635'; pumped Hi-Vis sweep observing a 50% increase in cuttings; continued drilling; currently drilling at 3856’. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Joe Grubb, James Sweetsir DATE: Jun 05, 2014 DEPTH 5064' PRESENT OPERATION: Drilling TIME: 23:59:13 YESTERDAY 3856' 24 HOUR FOOTAGE 1208 CASING INFORMATION 9.625" @ 2336' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4777.82' 34.70 79.43 4434.52' 4840.19' 35.13 80.34 4485.67' 4902.35' 34.19 80.10 4536.80' 4964.51' 35.58 78.71 4587.79' 5026.95' 35.12 78.58 4638.71' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 7.875" HDBS MM64D 12460625 5x12/0.5522 2376' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 184.4 @ 4966' 0.7 @ 4570' 96.1 95.74468 FT/HR SURFACE TORQUE 7307 @ 4363' 2035 @ 4318' 4292.8 6184.31982 FT-LBS WEIGHT ON BIT 22 @ 4821' 0 @ 4509' 6.0 11.65000 KLBS ROTARY RPM 73 @ 3876' 4 @ 4580' 52.6 64.32000 RPM PUMP PRESSURE 2083 @ 4867' 1551 @ 4028' 1853.4 1971.73999 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 5,047'/4,655' MW 9.10 VIS 69 PV 22 YP 25 Gels 6/8/10 FL 4.2 FC 1/2 SOL 3.2 NAF/W 0.0/94.3 SD 0.15 MBT 2.5 pH 10.3 ALK 0.70 Cl- 30000 Ca+ 100 MWD SUMMARY INTERVAL 2376' TO TOOLS Bit, directional, gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 21 @ 4989' 0 @ 4443' 6.2 TRIP GAS 0u CUTTING GAS 0 @ 5064' 0 @ 5064' 0.0 WIPER GAS 4u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 4176 @ 4989' 76 @ 4443' 1055.2 CONNECTION GAS HIGH 0u ETHANE (C-2) 0 @ 5064' 0 @ 5064' 0.0 CONNECTION GAS: AVG 0u PROPANE (C-3) 0 @ 5064' 0 @ 5064' 0.0 CONNECTION GAS: CURRENT 0u BUTANE (C-4) 0 @ 5064' 0 @ 5064' 0.0 CURRENT AVG BACKGROUND 11/6u PENTANE (C-5) 0 @ 5064' 0 @ 5064' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling formation PRESENT LITHOLOGY Tuffaceous siltstone (90%), tuffaceous sandstone (10%) DAILY ACTIVITY SUMMARY Drilled to 4031' and pumped a Hi-Vis sweep observing 25% increase in cuttings; drilled to 4568' and circulated hole until clean, generating 4 units gas; wiper trip to 3310; RIH to bottom, picking up singles, pumping through tight spot at 4212'- 4220'; pumped Hi -Vis sweep observing 200% increase in cuttings and generating 5 units gas; drilled to 4815' and pumped Hi-Vis sweep observing 25% increase in cuttings; currently drilling at depth of 5064’. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Joe Grubb, James Sweetsir DATE: Jun 06, 2014 DEPTH 6305' PRESENT OPERATION: Drilling TIME: 23:59::41 YESTERDAY 5064' 24 HOUR FOOTAGE 1241' CASING INFORMATION 9.625" @ 2336' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5957.46' 33.72 80.34 5401.57' 6018.42' 35.04 80.43 5451.88' 6080.82' 34.84 80.67 5503.03' 6143.62' 34.52 80.84 5554.67' 6205.38' 35.83 80.39 5605.15' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 7.875" HDBS MM64D 12460625 5x12/0.5522 2376' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 139.6 @ 5997' 9.3 @ 6024' 97.7 86.80924 FT/HR SURFACE TORQUE 8349 @ 6269' 1902 @ 6186' 6169.5 8033.77979 FT-LBS WEIGHT ON BIT 44 @ 6192' 0 @ 5078' 12.4 25.53000 KLBS ROTARY RPM 71 @ 6201' 0 @ 5263' 59.5 66.02000 RPM PUMP PRESSURE 2238 @ 6031' 1633 @ 6021' 2035.5 2086.87988 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 6,292'/5,675' MW 9.1 VIS 68 PV 20 YP 23 Gels 5/7/9 FL 4.0 FC 1/2 SOL 3.2 NAF/W 0.0/94.3 SD 0.15 MBT 3.0 pH 9.4 ALK 0.30 Cl- 31000 Ca+ 280 MWD SUMMARY INTERVAL 2376' TO TOOLS Bit, directional, gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 185 @ 5694' 6 @ 5950' 32.5 TRIP GAS 4u CUTTING GAS 0 @ 6305' 0 @ 6305' 0.0 WIPER GAS 20u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 35631 @ 5694' 858 @ 5208' 5816.8 CONNECTION GAS HIGH 0u ETHANE (C-2) 32 @ 5694' 0 @ 5729' 0.9 CONNECTION GAS: AVG 0u PROPANE (C-3) 0 @ 6305' 0 @ 6305' 0.0 CONNECTION GAS: CURRENT 0u BUTANE (C-4) 0 @ 6305' 0 @ 6305' 0.0 CURRENT AVG BACKGROUND 32u/32u PENTANE (C-5) 0 @ 6305' 0 @ 6305' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling formation PRESENT LITHOLOGY Tuffaceous sandstone (100%); minor thin conglomerate, siltstone and carbonaceous shale beds DAILY ACTIVITY SUMMARY Drilled to 5141'; pumped Hi-Vis sweep, observing 50% increase in cuttings; drilled to 5465'; pumped Hi-Vis sweep, observing 100% increase in cuttings; drilled to 5810', pumped Hi-Vis sweep, observing 25% increase in cuttings; drilled to 5997'; CBU; wiper trip to last wiper trip point; RIH to bottom; pumped Hi-Vis sweep, observing 25% increase in cuttings; currently drilling ahead at 6305’. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 07, 2014 DEPTH 6989' PRESENT OPERATION: RIH at 5605' MD TIME: 23:59:36 YESTERDAY 6305' 24 HOUR FOOTAGE 684' CASING INFORMATION 9.625" @ 2336' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6701.76' 35.16 77.74 6009.92' 6762.94' 34.68 78.25 6060.08' 6826.73' 34.84 76.39 6112.49 6887.89' 34.76 76.01 6162.71' 6948.33' 34.40 75.81 6212.47' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 7.875" HDBS MM64D 12460625 5x12/0.5522 2376' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 143.7 @ 6760' 8.0 @ 6922' 91.0 67.03737 FT/HR SURFACE TORQUE 9729 @ 6984' 365 @ 6804' 7869.1 9263.08984 FT-LBS WEIGHT ON BIT 46 @ 6619' 0 @ 6754' 17.0 2.70000 KLBS ROTARY RPM 67 @ 6342' 2 @ 6804' 61.4 66.14000 RPM PUMP PRESSURE 2319 @ 6312' 1306 @ 6818' 2205.8 2237.56006 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 6,989'/6,246' MW 9.15 VIS 56 PV 17 YP 21 Gels 5/7/9 FL 3.8 FC 1/2 SOL 3.4 NAF/W 0.0/94.0 SD 0.10 MBT 4.0 pH 8.5 ALK 0.2 Cl- 32000 Ca+ 200 MWD SUMMARY INTERVAL 2376' TO TOOLS Bit, directional, gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 245 @ 6758' 8 @ 6819' 54.9 TRIP GAS 2u CUTTING GAS 0 @ 6989' 0 @ 6989' 0.0 WIPER GAS 2u CHROMATOGRAPHY (ppm) SURVEY 0u METHANE (C-1) 41572 @ 6759' 1547 @ 6819' 10413.3 CONNECTION GAS HIGH 0u ETHANE (C-2) 43 @ 6759' 0 @ 6802' 3.4 CONNECTION GAS: AVG 0u PROPANE (C-3) 0 @ 6989' 0 @ 6989' 0.0 CONNECTION GAS: CURRENT 0u BUTANE (C-4) 0 @ 6989' 0 @ 6989' 0.0 CURRENT AVG BACKGROUND 0u/55u PENTANE (C-5) 0 @ 6989' 0 @ 6989' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Sterling/Upper Beluga PRESENT LITHOLOGY Tuffaceous sandstone (60%), tuffaceous siltstone (40%) DAILY ACTIVITY SUMMARY Drilled to 6428’; pumped Hi-Vis sweep, observing 25% increase in cuttings; drilled to 6740’; pumped Hi-Vis sweep, observing 25% increase in cuttings; drilled to 6989', pumped Hi-Vis sweep, observing 25% increase in cuttings; CBU (generating 29u gas); wiper trip to window; service rig; cut and slip drill line; RIH on singles; presently picking up stands and washing down towards bottom. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 08, 2014 DEPTH 7590' PRESENT OPERATION: Drilling TIME: 23:59:55 YESTERDAY 6989' 24 HOUR FOOTAGE 601 CASING INFORMATION 9.625" @ 2336' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7261.24' 31.83 75.55 6474.14' 7323.60' 31.48 75.75 6527.23' 7384.35' 30.28 76.31 6579.37' 7447.01' 27.25 76.19 6634.29' 7508.87' 25.44 76.63 6689.72' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 7.875" HDBS MM64D 12460625 5x12/0.5522 2376' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 124.6 @ 7002' 2.7 @ 7400' 59.4 44.77552 FT/HR SURFACE TORQUE 12826 @ 7184' 16 @ 7460' 9410.0 10288.69043 FT-LBS WEIGHT ON BIT 48 @ 7204' 0 @ 7421' 16.8 28.14000 KLBS ROTARY RPM 160 @ 7238' 2 @ 7511' 68.2 80.40000 RPM PUMP PRESSURE 2540 @ 7322' 2033 @ 7037' 2322.8 2263.37988 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 7,584'/6,759' MW 9.25 VIS 61 PV 21 YP 22 Gels 5/7/11 FL 3.8 FC 1/2 SOL 4.3 NAF/W 0.0/93.1 SD 0.10 MBT 4.0 pH 9.4 ALK 0.4 Cl- 32000 Ca+ 120 MWD SUMMARY INTERVAL 2376' TO TOOLS Bit, directional, gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 154 @ 7133' 6 @ 7519' 35.8 TRIP GAS 2u CUTTING GAS 0 @ 7590' 0 @ 7590' 0.0 WIPER GAS 48u CHROMATOGRAPHY (ppm) SURVEY 0u METHANE (C-1) 26222 @ 7132' 360 @ 7519' 5843.6 CONNECTION GAS HIGH 0u ETHANE (C-2) 30 @ 7133' 0 @ 7110' 0.6 CONNECTION GAS: AVG 0u PROPANE (C-3) 0 @ 7590' 0 @ 7590' 0.0 CONNECTION GAS: CURRENT 0u BUTANE (C-4) 0 @ 7590' 0 @ 7590' 0.0 CURRENT AVG BACKGROUND 20u/36u PENTANE (C-5) 0 @ 7590' 0 @ 7590' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Sterling/Upper Beluga formation PRESENT LITHOLOGY Tuffaceous sandstone (70%), tuffaceous siltstone (20%), carbonaceous shale (10%) DAILY ACTIVITY SUMMARY Continued TIH washing through 5371', 6359' and washing down the last 3 stands down; no fill; pumped a Hi-Vis sweep on bottom; observing 25% increase in cuttings; drilled ahead to 7300' and pumped another sweep observing 100% increase in cuttings; continued drilling ahead; currently drilling ahead. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 9, 2014 DEPTH 8034' PRESENT OPERATION: Drilling TIME: 23:59:23 YESTERDAY 7590' 24 HOUR FOOTAGE 444' CASING INFORMATION 9.625" @ 2336' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7756.28' 19.44 76.67 6917.39' 7819.20' 16.86 76.48 6977.17' 7880.70' 15.09 75.29 7036.30' 7942.13' 14.50 74.92 7095.69' 8005.58' 13.94 74.60 7157.19' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 7.875" HDBS MM64D 12460625 5x12/0.5522 2376' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 72.8 @ 7810' 2.6 @ 7611' 38.7 46.56062 FT/HR SURFACE TORQUE 12595 @ 7799' 13 @ 7736' 9637.4 10808.16992 FT-LBS WEIGHT ON BIT 39 @ 7611' 0 @ 7915' 15.8 22.54000 KLBS ROTARY RPM 87 @ 7769' 1 @ 7859' 72.3 72.88000 RPM PUMP PRESSURE 2550 @ 7897' 2024 @ 7621' 2352.9 2347.82007 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 8,025'/7,176' MW 9.25 VIS 6.2 PV 24 YP 24 Gels 4/6/9 FL 3.0 FC 1/2 SOL 4.6 NAF/W 2.4/90.5 SD 0.05 MBT 3.8 pH 10.0 ALK 0.40 Cl- 32000 Ca+ 120 MWD SUMMARY INTERVAL 2376' TO TOOLS Bit, directional, gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 74 @ 8018' 3 @ 7847' 22.0 TRIP GAS N/A CUTTING GAS 0 @ 8034' 0 @ 8034' 0.0 WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY 0u METHANE (C-1) 16093 @ 8018' 309 @ 7674' 4020.0 CONNECTION GAS HIGH 0u ETHANE (C-2) 0 @ 8034' 0 @ 8034' 0.0 CONNECTION GAS: AVG 0u PROPANE (C-3) 0 @ 8034' 0 @ 8034' 0.0 CONNECTION GAS: CURRENT 0u BUTANE (C-4) 0 @ 8034' 0 @ 8034' 0.0 CURRENT AVG BACKGROUND 22u/22u PENTANE (C-5) 0 @ 8034' 0 @ 8034' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Upper Beluga formation PRESENT LITHOLOGY Tuffaceous siltstone (40%), tuffaceous sandstone (30%), tuffaceous claystone (20%), with thin coal and carbonaceous shale DAILY ACTIVITY SUMMARY Drilled to 7622'; pumped a Hi-Vis sweep, observing a 150% increase in cuttings; drilled ahead to 7920'; pumped a Hi-Vis sweep, observing a 50% increase in cuttings; continued drilling; currently drilling ahead. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 10, 2014 DEPTH 8436' PRESENT OPERATION: Drilling TIME: 23:59:46 YESTERDAY 8034' 24 HOUR FOOTAGE 402' CASING INFORMATION 9.625" @ 2336' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8128.64' 13.38 76.58 7276.77' 8191.27' 13.24 76.12 7337.72' 8253.33' 12.59 77.09 7398.21' 8316.12' 12.46 76.95 7459.50' 8378.04' 11.51 76.59 7520.07' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 7.875" HDBS MM64D 12460625 5x12/0.5522 2376' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 79.6 @ 8054' 2.6 @ 8362' 39.5 10.34748 FT/HR SURFACE TORQUE 12120 @ 8350' 10041 @ 8167' 11213.6 10884.45996 FT-LBS WEIGHT ON BIT 39 @ 8425' 1 @ 8294' 13.8 36.60000 KLBS ROTARY RPM 146 @ 8231' 43 @ 8167' 79.3 58.67000 RPM PUMP PRESSURE 2617 @ 8305' 1904 @ 8361' 2442.7 2429.73999 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 8,436/7,575 MW 9.3 VIS 63 PV 25 YP 22 Gels 4/7/9 FL 2.8 FC 1/2 SOL 4.7 NAF/W 1.6/91.1 SD 0.05 MBT 3.5 pH 9.9 ALK 0.6 Cl- 33000 Ca+ 140 MWD SUMMARY INTERVAL 2376' TO TOOLS Bit, directional, gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 136 @ 8168' 5 @ 8427' 36.9 TRIP GAS 0u CUTTING GAS 0 @ 8436' 0 @ 8436' 0.0 WIPER GAS 8u CHROMATOGRAPHY (ppm) SURVEY 0u METHANE (C-1) 23007 @ 8190' 790 @ 8395' 6648.0 CONNECTION GAS HIGH 0u ETHANE (C-2) 67 @ 8187' 2 @ 8175' 1.0 CONNECTION GAS: AVG 0u PROPANE (C-3) 0 @ 8436' 0 @ 8436' 0.0 CONNECTION GAS: CURRENT 0u BUTANE (C-4) 0 @ 8436' 0 @ 8436' 0.0 CURRENT AVG BACKGROUND 11u/36u PENTANE (C-5) 0 @ 8436' 0 @ 8436' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Middle Beluga formation PRESENT LITHOLOGY Tuffaceous siltstone (20%), tuffaceous sandstone (50%), tuffaceous claystone (30%), DAILY ACTIVITY SUMMARY Drilled to 8157'; pumped a Hi-Vis sweep, observing a 100%; CBU; TOOH to 7075'for a wiper trip, pumping at 6987'; RIH back to bottom. pumped a Hi-Vis sweep at bottom, observing a 200% increase in cuttings; drilled to 8418'; pumped a Hi-Vis sweep, observing a 25% increase in cuttings; continued drilling; currently drilling ahead CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 11, 2014 DEPTH 8604' PRESENT OPERATION: POOH TIME: 23:59:52 YESTERDAY 8436' 24 HOUR FOOTAGE 168' CASING INFORMATION 9.625" @ 2336' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8316.12' 12.46 76.95 7459.50' 8378.04' 11.51 76.59 7520.07' 8440.28' 10.83 74.84 7581.13' 8501.90' 10.54 74.44 7641.69' 8560.91' 10.20 73.06 7699.73' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 7.875" HDBS MM64D 12460625 5x12/0.5522 2376' 8604' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 41.1 @ 8542' 1.5 @ 8470' 15.7 20.20321 FT/HR SURFACE TORQUE 11817 @ 8465' 9495 @ 8595' 10696.7 10434.58008 FT-LBS WEIGHT ON BIT 36 @ 8441' 6 @ 8603' 22.6 9.15000 KLBS ROTARY RPM 181 @ 8481' 57 @ 8443' 73.5 67.61000 RPM PUMP PRESSURE 2572 @ 8558' 1888 @ 8447' 2380.0 2543.05005 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 8,603'/7,741' MW 9.25 VIS 63 PV 20 YP 18 Gels 4/7/8 FL 2.9 FC 1/2 SOL 4.2 NAF/W 1.4/91.8 SD 0.10 MBT 3.5 pH 9.4 ALK 0.4 Cl- 33000 Ca+ 180 MWD SUMMARY INTERVAL 2376' TO 8604' TOOLS Bit, directional, gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 80 @ 8601' 5 @ 8482' 20.0 TRIP GAS 0u CUTTING GAS 0 @ 8604' 0 @ 8604' 0.0 WIPER GAS 8u CHROMATOGRAPHY (ppm) SURVEY 0u METHANE (C-1) 17550 @ 8600' 394 @ 8544' 3110.9 CONNECTION GAS HIGH 0u ETHANE (C-2) 0 @ 8604' 0 @ 8604' 0.0 CONNECTION GAS: AVG 0u PROPANE (C-3) 0 @ 8604.00000 0 @ 8604' 0.0 CONNECTION GAS: CURRENT 0u BUTANE (C-4) 0 @ 8604' 0 @ 8604' 0.0 CURRENT AVG BACKGROUND 0u/20u PENTANE (C-5) 0 @ 8604' 0 @ 8604' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Middle/Lower Beluga formation PRESENT LITHOLOGY Tuffaceous siltstone (70%), tuffaceous sandstone (20%), tuffaceous claystone (10%) DAILY ACTIVITY SUMMARY Continued drilling ahead and ROP declined to <10 ft/hr; pumped a Hi-Vis walnut sweep at 8481', observing a 20% increase in cuttings; ROP increased to 20 ft/hr and torque dropped to 10,400, but ROP soon dropped off again; pumped two more Low-vis sweeps at 8528' and 8577' but ROP increased and then dropped off again; decision made to pump dry job and TOOH to change bit; POOH to 6965'; BROOH through tight spots to 6450’; continued POOH without problems, presently POOH at 4296’ CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 12, 2014 DEPTH 8663' PRESENT OPERATION: Drilling TIME: 23:59:05 YESTERDAY 8604' 24 HOUR FOOTAGE 59 CASING INFORMATION 9.625" @ 2336' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8626.20' 9.79 73.67 7764.03' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 7.875" HDBS MM64D 12460625 5x12/0.5522 2376' 8604' 6227' 113.74 2-5-RO-F-X-1-BP-ROP ROP 5 7.875" HDBS EQH20R 11562663 3X15/0.5177 8604' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 92.1 @ 8619' 3.1 @ 8612' 25.7 24.57986 FT/HR SURFACE TORQUE 12069 @ 8606' 10198 @ 8655' 10914.8 10322.90039 FT-LBS WEIGHT ON BIT 32 @ 8649' 9 @ 8604' 30.1 32.22000 KLBS ROTARY RPM 81 @ 8619' 63 @ 8659' 71.6 64.06000 RPM PUMP PRESSURE 2543 @ 8604' 2048 @ 8613' 2296.3 2099.40991 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 8,658'/7,775' MW 9.35 VIS 54 PV 19 YP 17 Gels 4/5/6 FL 3.0 FC 1/2 SOL 4.6 NAF/W 1.5/91.3 SD 0.10 MBT 3.5 pH 8.6 ALK 0.2 Cl- 33000 Ca+ 200 MWD SUMMARY INTERVAL 8604' TO TOOLS Bit, directional, gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 182 @ 8619' 2 @ 8607' 38.7 TRIP GAS 0u CUTTING GAS 0 @ 8663' 0 @ 8663' 0.0 WIPER GAS 22u CHROMATOGRAPHY (ppm) SURVEY 0u METHANE (C-1) 34635 @ 8618' 372 @ 8607' 7393.2 CONNECTION GAS HIGH 0u ETHANE (C-2) 33 @ 8619' 0 @ 8613' 2.5 CONNECTION GAS: AVG 0u PROPANE (C-3) 276 @ 8619' 2 @ 8613' 21.1 CONNECTION GAS: CURRENT 0u BUTANE (C-4) 13 @ 8619' 0 @ 8613' 1.0 CURRENT AVG BACKGROUND 8u/38u PENTANE (C-5) 0 @ 8663' 0 @ 8663' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Beluga formation PRESENT LITHOLOGY Tuffaceous siltstone (70%), tuffaceous sandstone (20%), tuffaceous claystone (10%) DAILY ACTIVITY SUMMARY Finished POOH, L/D BHA and P/U BHA#5; RIH to 5980' and encountered tight spot; RIH; washed and reamed from 6140' to 6500' (11 units wiper gas); RIH on the elevators; no fill observed; on bottom pumped a Hi-Vis sweep, observing a 10% increase in cuttings and (22u gas); drilled ahead; currently drilling ahead. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 13, 2014 DEPTH 9295' PRESENT OPERATION: Drilling TIME: 23:58:12 YESTERDAY 8663' 24 HOUR FOOTAGE 632' CASING INFORMATION 9.625" @ 2336' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8999.80' 8.58 76.87 8133.15' 9058.92' 8.36 77.04 8191.63' 9123.88' 8.24 77.96 8255.91' 9186.05' 7.93 78.98 8317.46' 9247.10' 7.28 76.32 8377.97' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 5 7.875" HDBS EQH20R 11562663 3X15/0.5177 8604' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 116.2 @ 9051' 4.4 @ 8983' 39.5 19.78850 FT/HR SURFACE TORQUE 12573 @ 9251' 14 @ 8924' 10304.1 12538.87988 FT-LBS WEIGHT ON BIT 39 @ 9163' 0 @ 9217' 17.7 14.39000 KLBS ROTARY RPM 198 @ 8852' 14 @ 8981' 63.1 59.64000 RPM PUMP PRESSURE 2757 @ 9185' 1552 @ 8976' 2320.3 2662.06006 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 9,286'/8,416' MW 9.35 VIS 53 PV 17 YP 15 Gels 4/7/10 FL 3.2 FC 1.2 SOL 5.0 NAF/W 1.5/91.1 SD 0.10 MBT 4.0 pH 9.4 ALK 0.25 Cl- 30000 Ca+ 160 MWD SUMMARY INTERVAL 8604' TO TOOLS Bit, directional, gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 304 @ 8718' 1 @ 9120' 42.8 TRIP GAS 0u CUTTING GAS 0 @ 9295' 0 @ 9295' 0.0 WIPER GAS 0u CHROMATOGRAPHY (ppm) SURVEY 0u METHANE (C-1) 252924 @ 9050' 247 @ 9101' 11133.7 CONNECTION GAS HIGH 0u ETHANE (C-2) 195 @ 9049' 0 @ 9029' 4.5 CONNECTION GAS: AVG 0u PROPANE (C-3) 110 @ 9049' 0 @ 9031' 1.6 CONNECTION GAS: CURRENT 0u BUTANE (C-4) 0 @ 9295' 0 @ 9295' 0.0 CURRENT AVG BACKGROUND 42u/10u PENTANE (C-5) 0 @ 9295' 0 @ 9295' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Beluga formation PRESENT LITHOLOGY Tuffaceous siltstone (50%), tuffaceous sandstone (10%), tuffaceous claystone (40%) DAILY ACTIVITY SUMMARY Continued drilling ahead to 8980'; pumped a Hi-Vis sweep, observing a 10% increase in cuttings; drilled ahead; currently drilling ahead. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas, Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 14, 2014 DEPTH 9349' PRESENT OPERATION: Testing BOP's TIME: 23:59:11 YESTERDAY 9294' 24 HOUR FOOTAGE 55' CASING INFORMATION 9.625" @ 2336' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9309.62' 6.83 75.18 8440.02' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 5 7.875" HDBS EQH20R 11562663 3X15/0.5177 8604' 9349' 745 24.95 8-8-LC-A-F-3-SD DTF DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 65.0 @ 9340' 6.1 @ 9307' 26.5 12.20516 FT/HR SURFACE TORQUE 12538 @ 9295' 10774 @ 9307' 11965.5 11803.09961 FT-LBS WEIGHT ON BIT 34 @ 9349' 10 @ 9320' 14.9 34.14000 KLBS ROTARY RPM 82 @ 9310' 59 @ 9299' 62.9 62.84000 RPM PUMP PRESSURE 2667 @ 9296' 2109 @ 9321' 2565.5 2289.28003 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 9,349'/8,479' MW 9.35 VIS 55 PV 17 YP 22 Gels 5/10/15 FL 3.2 FC 1/2 SOL 4.8 NAF/W 1.5/91.1 SD 0.10 MBT 4.5 pH 9.4 ALK 0.45 Cl- 33000 Ca+ 200 MWD SUMMARY INTERVAL 8604' TO 9349' TOOLS Bit, directional, gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 32 @ 9326' 6 @ 9308' 16.3 TRIP GAS 6u CUTTING GAS 0 @ 9349' 0 @ 9349' 0.0 WIPER GAS 7u CHROMATOGRAPHY (ppm) SURVEY 0u METHANE (C-1) 6466 @ 9341' 1163 @ 9308' 3137.6 CONNECTION GAS HIGH 0u ETHANE (C-2) 0 @ 9349' 0 @ 9349' 0.0 CONNECTION GAS: AVG 0u PROPANE (C-3) 0 @ 9349' 0 @ 9349' 0.0 CONNECTION GAS: CURRENT 0u BUTANE (C-4) 0 @ 9349' 0 @ 9349' 0.0 CURRENT AVG BACKGROUND 0u/16u PENTANE (C-5) 0 @ 9349' 0 @ 9349' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Beluga formation PRESENT LITHOLOGY Tuffaceous siltstone (60%), tuffaceous sandstone (10%), tuffaceous claystone (30%) DAILY ACTIVITY SUMMARY Continued drilling ahead to 9286'; pumped a 20 bbl Hi-Vis sweep with walnut to help gauge the hole; sweep indicated gauged hole, but with minimal cuttings (only 10% increase); continued drilling ahead to 9349'; CBU; decision to POOH due to mud motor problems; logged out of hole from 9349' to 9050'; TOOH; L/D motor/bit; R/U to test BOP; currently testing BOP's. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 15, 2014 DEPTH 9349' PRESENT OPERATION: RIH with Milling Assembly TIME: 23:59:18 YESTERDAY 9349' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 2336' 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 7.875" Mill Bit 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 9,349'/8,479' MW 9.40 VIS 61 PV 18 YP 21 Gels 5/11/14 FL 3.0 FC 1//2 SOL 5.2 NAF/W 1.5/90.8 SD 0.10 MBT 4.5 pH 10.0 ALK 0.6 Cl- 32000 Ca+ 180 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 12u CUTTING GAS @ @ WIPER GAS 0u CHROMATOGRAPHY (ppm) SURVEY 0u METHANE (C-1) @ @ CONNECTION GAS HIGH 0u ETHANE (C-2) @ @ CONNECTION GAS: AVG 0u PROPANE (C-3) @ @ CONNECTION GAS: CURRENT 0u BUTANE (C-4) @ @ CURRENT AVG BACKGROUND 5u/7u PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Beluga formation PRESENT LITHOLOGY Tuffaceous siltstone (60%), tuffaceous sandstone (10%), tuffaceous claystone (30%) DAILY ACTIVITY SUMMARY Finished testing BOP's (note: 12bbls mud lost down hole during testing); P/U milling assembly; RIH to window; S/C drill line; continue RIH, reaming and pumping to bottom due to full gauge mill; currently RIH at 8283’ CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 16, 2014 DEPTH 9355' PRESENT OPERATION: TOOH TIME: 23:59:04 YESTERDAY 9349' 24 HOUR FOOTAGE 6' CASING INFORMATION 9.625" @ 2336' 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 7.875" Mill Bit 9349' 9355' 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 9,355'/8,490' MW 9.40 VIS 60 PV 16 YP 19 Gels 5/9/13 FL 3.4 FC 1/2 SOL 5.4 NAF/W 1.3/91.0 SD 0.10 MBT 4.5 pH 9.8 ALK 0.60 Cl- 29000 Ca+ 200 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 70u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH 0u ETHANE (C-2) @ @ CONNECTION GAS: AVG 0u PROPANE (C-3) @ @ CONNECTION GAS: CURRENT 0u BUTANE (C-4) @ @ CURRENT AVG BACKGROUND 2u/2u PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Beluga formation PRESENT LITHOLOGY Tuffaceous siltstone (60%), tuffaceous sandstone (10%), tuffaceous claystone (30%) DAILY ACTIVITY SUMMARY Continued reaming and pumping to 9300'; pumped 20 bbl Hi-Vis walnut sweep, observing a 10% increase in cuttings (70u max gas); washed to bottom at 9349' and began milling junk; milled to 9352’; pull four stands on elevators to catch metal in junk baskets; RIH to bottom and continued to mill ahead; pumped five multiple Hi-Vis sweeps, some with walnut mixed in while milling, observing no increase in cuttings or metal at shakers; milled to 9355’ decision to TOOH to examine and if necessary replace bit; currently TOOH at 5497’. Total of 06’ of incidental hole drilled during milling process. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 17, 2014 DEPTH 9361' PRESENT OPERATION: TOOH TIME: 23:59:21 YESTERDAY 9355' 24 HOUR FOOTAGE 6' CASING INFORMATION 9.625" @ 2336' 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 6 7.875" Mill bit 9349' 9355' 6' 7 7 7.875" Mill bit 9355' 9361' 6' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 11.4 @ 9354' 0.7 @ 9353' 3.4 1.22431 FT/HR SURFACE TORQUE 11926 @ 9360' 10792 @ 9358' 12462.4 11926.58008 FT-LBS WEIGHT ON BIT 21 @ 9358' 0 @ 9359' 14.1 1.24000 KLBS ROTARY RPM 87 @ 9355' 59 @ 9350' 79.3 69.85000 RPM PUMP PRESSURE 873 @ 9352' 316 @ 9354' 709.4 606.53998 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 9,361'/8,491' MW 9.3 VIS 52 PV 14 YP 17 Gels 4/9/12 FL 3.4 FC 1/2 SOL 4.9 NAF/W 1.0/91.7 SD 0.05 MBT 4.5 pH 9.8 ALK 0.5 Cl- 29500 Ca+ 80 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 7 @ 9355' 1 @ 9350' 4.9 TRIP GAS 46u CUTTING GAS 0 @ 9360' 0 @ 9360' 0.0 WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 1245 @ 9355' 270 @ 9350' 774.9 CONNECTION GAS HIGH 0u ETHANE (C-2) 54 @ 9359' 2 @ 9350' 31.1 CONNECTION GAS: AVG 0u PROPANE (C-3) 0 @ 9360' 0 @ 9360' 0.0 CONNECTION GAS: CURRENT 0u BUTANE (C-4) 0 @ 9360' 0 @ 9360' 0.0 CURRENT AVG BACKGROUND 4u/5u PENTANE (C-5) 0 @ 9360' 0 @ 9360' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Beluga formation PRESENT LITHOLOGY Tuffaceous siltstone (60%), tuffaceous sandstone (10%), tuffaceous claystone (20%), carbonaceous shale (10%) DAILY ACTIVITY SUMMARY Finished TOOH; inspected mill, was worn out and out of gauge; P/U new mill; RIH to bottom; continue milling; pumped Hi-Vis sweep with walnut at 9,358', observing 10% increase in cuttings; continue milling; pumped Hi-Vis sweep with walnut at 9,360’, observing 10% increase in cuttings; milled to 9,361'; flow check, no flow; TOOH, flow slightly falling looking down backside; continue TOOH slowly to 7,536'; currently TOOH at 7421’ (note: drilling parameters reflect entire milling process from 9349' to 9361'). CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 18, 2014 DEPTH 9361' PRESENT OPERATION: RIH with BHA 8 TIME: 23:59:42 YESTERDAY 9361' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 2336' 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 8 7.875" HDBS MM55 12460624 5x12/ 0.5522 9361' 7 7.875" Mill bit 9355' 9361' 6' 7 No grade Milling completed 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 9,361'/8,491' MW 9.25 VIS 56 PV 15 YP 21 Gels 6/12/16 FL 3.2 FC 1/2 SOL 4.4 NAF/W 1.0/92.3 SD 0.01 MBT 4.0 pH 9.6 ALK 0.35 Cl- 29000 Ca+ 80 MWD SUMMARY INTERVAL 9361' TO TOOLS Bit, directional, gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 9u CUTTING GAS @ @ WIPER GAS 0u CHROMATOGRAPHY (ppm) SURVEY 0u METHANE (C-1) @ @ CONNECTION GAS HIGH 0u ETHANE (C-2) @ @ CONNECTION GAS: AVG 0u PROPANE (C-3) @ @ CONNECTION GAS: CURRENT 0u BUTANE (C-4) @ @ CURRENT AVG BACKGROUND 10u/3u PENTANE (C-5) @ @ HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Beluga formation PRESENT LITHOLOGY Tuffaceous siltstone (60%), tuffaceous sandstone (10%), tuffaceous claystone (20%), carbonaceous shale (10%) DAILY ACTIVITY SUMMARY Finished TOOH; L/D milling assembly (BHA 7); clean out boot baskets, recover metal cuttings and weigh metal recovered (1.0lb ); R/D milling tools; M/U drilling BHA 8 with PDC bit; TIH to window; S/C drill line; service rig; continue TIH at moderate speed watching for tight spots; currently at 9359’ preparing to drill ahead. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 19, 2014 DEPTH 9800' PRESENT OPERATION: Logging on MAD pass to 5000' TIME: 23:59:21 YESTERDAY 9361' 24 HOUR FOOTAGE 439' CASING INFORMATION 9.625" @ 2336' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9619.88' 4.23 66.11 8748.84' 9681.89' 3.83 64.09 8810.69' 9743.55' 3.58 59.92 8872.22' 9761.85' 3.44 60.02 8890.49' 9800.00' 3.44 60.02 8928.57' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 8 7.875" HDBS MM55 12460624 5x12/ 0.5522 9361' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 123.5 @ 9492' 1.5 @ 9362' 59.9 71.01635 FT/HR SURFACE TORQUE 14785 @ 9776' 11602 @ 9361' 13420.8 13260.49023 FT-LBS WEIGHT ON BIT 13 @ 9398' 1 @ 9514' 3.8 3.00000 KLBS ROTARY RPM 208 @ 9475' 33 @ 9408' 63.0 71.44000 RPM PUMP PRESSURE 2387 @ 9744' 1044 @ 9361' 2236.8 2253.46997 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 9,800'/8,929' MW 9.40 VIS 54 PV 16 YP 20 Gels 6/14/19 FL 3.6 FC 1/2 SOL 5.5 NAF/W 0.0/92.1 SD 0.10 MBT 5.0 pH 9.4 ALK 0.35 Cl- 29500 Ca+ 200 MWD SUMMARY INTERVAL 9361' TO 9800' TOOLS Bit, directional, gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 313 @ 9765' 6 @ 9361' 75.7 TRIP GAS 16u CUTTING GAS 0 @ 9800' 0 @ 9800' 0.0 WIPER GAS 132u CHROMATOGRAPHY (ppm) SURVEY 0u METHANE (C-1) 55447 @ 9762' 567 @ 9361' 13428.3 CONNECTION GAS HIGH 0u ETHANE (C-2) 49 @ 9762' 0 @ 9470' 3.9 CONNECTION GAS: AVG 0u PROPANE (C-3) 215 @ 9500' 0 @ 9736' 8.9 CONNECTION GAS: CURRENT 0u BUTANE (C-4) 0 @ 9800' 0 @ 9800' 0.0 CURRENT AVG BACKGROUND 0u/75u PENTANE (C-5) 0 @ 9800' 0 @ 9800' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Upper Tyonek PRESENT LITHOLOGY Tuffaceous siltstone (70%), tuffaceous sandstone (20%), coal (10%). DAILY ACTIVITY SUMMARY Drilled ahead from 9360'; pumped sweep at 9596' and observed 10% increase in cuttings; drilled to TD at 9800’; pumped sweep and observed a 50% increase in cuttings, and 313 units gas at bottoms up; TOOH to 9000'; began MAD pass aimed at logging to 5000'; currently logging at 6,539'. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 20, 2014 DEPTH 9800' PRESENT OPERATION: TOOH TIME: 23:59:30 YESTERDAY 9800' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 2336' 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 8 7.875" HDBS MM55 12460624 5x12/ 0.5522 9361' 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'/8,929' MW 9.35 VIS 52 PV 14 YP 20 Gels 6/15/19 FL 3.5 FC 1/2 SOL 4.9 NAF/W 0.0/92.6 SD 0.01 MBT 4.5 pH 9.4 ALK 0.35 Cl- 30500 Ca+ 160 MWD SUMMARY INTERVAL 9361' TO 9800' TOOLS Bit, directional, gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 19u CUTTING GAS @ @ WIPER GAS 2458u CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH 0u ETHANE (C-2) @ @ CONNECTION GAS: AVG 0u PROPANE (C-3) @ @ CONNECTION GAS: CURRENT 0u BUTANE (C-4) @ @ CURRENT AVG BACKGROUND 0u/3u PENTANE (C-5) @ @ HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Upper Tyonek PRESENT LITHOLOGY Tuffaceous siltstone (70%), tuffaceous sandstone (20%), coal (10%). DAILY ACTIVITY SUMMARY Finished MAD pass to 5000'; RIH; took weight at 9686; decision to wash and ream to bottom getting 2458 units of gas at BU with mud cut 8.6ppg from 9.3ppg; pumped 25 bbl Hi-Vis sweep with walnut, observing 20% increase in cuttings; shakers cleaned up; pumped dry job 2.5 lbs over mud weight; POOH, L/D DP during trip, currently at 2675’ CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, S. Nolan, D. Hudgins __DAILY COST: $3248.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 21, 2014 DEPTH 9800' PRESENT OPERATION: Running Casing TIME: 23:59:31 YESTERDAY 9800' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 2336' 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 8 7.875" HDBS MM55 12460624 5x12/ 0.5522 9361' 9800' 439' 8.72 1-2-JD-G-X-1-CT- 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'/8,929' MW 9.40 VIS 55 PV 14 YP 20 Gels FL 3.8 FC 1/2 SOL 5.3 NAF/W 0.0/92.3 SD 0.01 MBT 5.0 pH 9.0 ALK 0.25 Cl- 29500 Ca+ 80 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 39u CUTTING GAS @ @ WIPER GAS 0u CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH 0u ETHANE (C-2) @ @ CONNECTION GAS: AVG 0u PROPANE (C-3) @ @ CONNECTION GAS: CURRENT 0u BUTANE (C-4) @ @ CURRENT AVG BACKGROUND 3u/2u PENTANE (C-5) @ @ HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Upper Tyonek PRESENT LITHOLOGY Tuffaceous siltstone (70%), tuffaceous sandstone (20%), coal (10%). DAILY ACTIVITY SUMMARY Finished POOH, L/D DP; L/D BHA; C/O rams; tested rams for running 5.5" casing; waited on Weatherford for tools; started RIH with 5.5" casing circulating every 2000’; currently circulating at 4024.9’ (39u gas) during casing run. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch __DAILY COST: $2246.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT BCU-7A REPORT FOR: Jim Greco, James Sweetsir DATE: Jun 22, 2014 DEPTH 9800' PRESENT OPERATION: R/D cementers/Canrig Rigdown TIME: 23:37:21 YESTERDAY 9800' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 2336' 5.5" @ 9765' 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 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'/8,929' MW 9.40 VIS 55 PV 14 YP 21 Gels 6/16/19 FL 4.0 FC 1/2 SOL 5.2 NAF/W 0.0/92.4 SD 0.01 MBT 5.0 pH 9.1 ALK 0.20 Cl- 30000 Ca+ 120 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 2187u CUTTING GAS @ @ WIPER GAS 0u CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH 0u ETHANE (C-2) @ @ CONNECTION GAS: AVG 0u PROPANE (C-3) @ @ CONNECTION GAS: CURRENT 0u BUTANE (C-4) @ @ CURRENT AVG BACKGROUND 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Upper Tyonek PRESENT LITHOLOGY N/A (Cased hole and cement) DAILY ACTIVITY SUMMARY Finished running casing, landed casing at 9765'; C&C mud and building 10.5 mud push (maximum 2187 units of gas at bottoms up); R/U Schlumberger to pump cement job; Pumped 35 bbls Mud-Push; pumped 345 bbls cement and chased with 266.6 bbls fresh water; monitored gas until cementing completed; did not bump plug, floats held; R/D cementers; rig started hauling mud to KGF; Canrig started mudlogging unit rigdown. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch __DAILY COST: $2246.00 REPORT BY: J. Foradas