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Home My WebLink About214-089Kyle 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: 11/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221128 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# SD-06 50133205820000 208160 9/12/2022 Yellowjacket PERF SRU 32A-33 50133101640100 191014 9/21/2022 Yellowjacket PERF KBU 42-06Y 50133206340000 214089 9/26/2022 Yellowjacket GPT-PERF CLU 05RD2 50133204740200 222092 9/29/2022 Yellowjacket PERF SCU 344-33 50133202930100 218054 10/8/2022 Yellowjacket PERF-GPT Please include current contact information if different from above. By Meredith Guhl at 9:48 am, Nov 29, 2022 T37313 T37314 T37315 T37316 T37317 KBU 42-06Y 50133206340000 214089 9/26/2022 Yellowjacket GPT-PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.29 09:55:33 -09'00' By Anne Prysunka at 4:18 pm, Oct 05, 2022 5HJJ-DPHV%2*& )URP.DUVRQ.R]XE&NNR]XE#KLOFRUSFRP! 6HQW7KXUVGD\6HSWHPEHU30 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*& &F-XDQLWD/RYHWW'RQQD$PEUX] 6XEMHFW)R[ $WWDFKPHQWV)R[[OV[ 'ŽŽĚĨƚĞƌŶŽŽŶ͕ ƚƚĂĐŚĞĚŝƐƚŚĞKWƚĞƐƚƌĞƉŽƌƚĨŽƌ&ŽǆϴdhϬϵͲϮϭͲϮϬϮϮ͘ <ĞŶĂŝĞůƵŐĂhŶŝƚ<hϰϮͲϬϲz;WdϮϭϰͲϬϴϵͿ;^ƵŶĚƌǇϯϮϮͲϰϴϮͿ͘ ZĞŐĂƌĚƐ͕ KarsonKozub ǣΪͳȋͻͲ͹Ȍͷ͹ͲǦͳͺͲͳ ̷Ǥ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ll BOPE reports are due to the agency within 5 days of testing* SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:8 DATE: 9/21/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2140890 Sundry #322-482 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:N/A Valves:250/3500 MASP:2704 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.NA Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 0NA Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75"P Trip Tank NA NA Annular Preventer 0NAPit Level Indicators NA NA #1 Rams 1 1.75" BS P Flow Indicator NA NA #2 Rams 1 1.75" PS P Meth Gas Detector NA NA #3 Rams 0NAH2S Gas Detector NA NA #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 2"P Time/Pressure Test Result HCR Valves 0NASystem Pressure (psi)2950 P Kill Line Valves 2 2"P Pressure After Closure (psi)2400 P Check Valve 0NA200 psi Attained (sec)3 P BOP Misc 0NAFull Pressure Attained (sec)10 P Blind Switch Covers: All stations YES CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): NA NA No. Valves 5P ACC Misc 0NA Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 0 NA #1 Rams 14 P Coiled Tubing Only:#2 Rams 11 P Inside Reel valves 1P #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:3.5 HCR Choke 0 NA Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice YES Date/Time 9/20/22 7:48hrs Waived By Test Start Date/Time:9/21/2022 13:30 (date) (time)Witness Test Finish Date/Time:9/21/2022 17:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Fox Second initial BOPE test for this sundry, the well watered up after perforating and needed a N2 lift. Accumulator system 4 bottles at 1400psi precharge. Terence Rais Hilcorp Alaska Karson Kozub KBU 42-06Y Test Pressure (psi): Trais@FoxEnergyAK.com Kkozub@hilcorp.com Form 10-424 (Revised 08/2022)2022-2921_BOP_Fox8_KBU_42-06Y 9 9 99 9 9 9 9 9 9 9 9 MEU -5HJJ From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Karson Kozub - (C); Donna Ambruz; Roby, David S (OGC); Boyer, David L (OGC) Subject:RE: [EXTERNAL] RE: KBU 42-06Y PTD# 214-089 (Sundry # 322-482) Date:Wednesday, September 14, 2022 5:09:00 PM Chad, Hilcorp has approval to add the perfs in your below email after pumping and verifying the cement plug. Include this email with your 10-404 for all the work. 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: McLellan, Bryan J (OGC) Sent: Monday, September 12, 2022 2:47 PM To: Chad Helgeson <chelgeson@hilcorp.com> Cc: Karson Kozub - (C) <kkozub@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Roby, David S (OGC) <dave.roby@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov> Subject: RE: [EXTERNAL] RE: KBU 42-06Y PTD# 214-089 (Sundry # 322-482) Chad, You are starting to get close to the minimum cement height required. You should plan to lay in your cement to 8550 or shallower then wash back down to +/-8575’ md. You won’t get the cement top exact when you lay it in with coil. If you aim for 8600, there’s good chance you’re cement top could be deeper by 50’ or so due to timing of where nozzle is when you displace the last of the cement out of the coil. As long as the TOC tag is no deeper than 8600’, it’s OK with me. 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: Chad Helgeson <chelgeson@hilcorp.com> CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Sent: Monday, September 12, 2022 12:43 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Karson Kozub - (C) <kkozub@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Roby, David S (OGC) <dave.roby@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov> Subject: RE: [EXTERNAL] RE: KBU 42-06Y PTD# 214-089 (Sundry # 322-482) Bryan, While reviewing the cement top with our Geo and RE this morning, there is a sand that we would like to add some sands that were not originally sundried. One of these sands is below the proposed top of cement we discussed this morning at 8500ft. Are you okay with moving the TOC to ~8,600ft, which will be 79ft above the top of the patch? I am assuming there will be some slump of the cement anyways, but was thinking of washing back down to 8,575 for the perfs and adding some volume of slump. The perfs that we would like to add to the sundry for approval are below and all within the same pool as other perfs, Kenai Gas Field Beluga/Upper Tyonek Pool. Sands Top MD Btm MD Top TVD Btm TVD FT'Pool Date Status TY_72_8 ±8,142’±8,172 ±7,297'±7,326'30 Beluga/Upr_Ty Proposed TBD TY_73_1 ±8,186’±8,195 ±7,340'±7,348'9 Beluga/Upr_Ty Proposed TBD TY_73_2 ±8,237’±8,243 ±7,389'±7,395'6 Beluga/Upr_Ty Proposed TBD UT_1D ±8,436’±8,443 ±7,582'±7,589'7 Beluga/Upr_Ty Proposed TBD TY_75_8_Upper ±8,466’±8,483 ±7,611'±7,628'17 Beluga/Upr_Ty Proposed TBD TY_75_8_Lower ±8,491’±8,498 ±7,636'±7,643'7 Beluga/Upr_Ty Proposed TBD UT_2B ±8,519’±8,527 ±7,663'±7,671'8 Beluga/Upr_Ty Proposed TBD TY_76_7 ±8,556’±8,574 ±7,700'±7,717'18 Beluga/Upr_Ty Proposed TBD See the attached revised proposed diagram. Please let me know if this change in TOC is approved. Chad From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, September 12, 2022 8:02 AM To: Chad Helgeson <chelgeson@hilcorp.com> Cc: Karson Kozub - (C) <kkozub@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Roby, David S (OGC) <dave.roby@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov> Subject: [EXTERNAL] RE: KBU 42-06Y PTD# 214-089 (Sundry # 322-482) Chad, Hilcorp has approval to modify the plan in the sundry 322-482 according to your plan in the email below. Conditions of approval on original sundry still apply. Bryan McLellan 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. Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Sunday, September 11, 2022 9:53 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Karson Kozub - (C) <kkozub@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com> Subject: KBU 42-06Y PTD# 214-089 (Sundry # 322-482) Bryan, Today we started the coil tubing cleanout on KBU 42-06Y and were unable to make it to the desired depth for the cement plug we were planning to set. The activities today were as follows: Tested BOPs RIH with 1.75” coil with slick nozzle. Dry tagged at 9,344’, brought on pump at 1.1BPM and washed to 9,396ft. Getting 1:1 returns Stop making progress at 9,396ft P/U to 9,317ft, unable to RIH, stacking out on something P/U to 9,283', 9,221', 9,156'. Each time easy PU, but unable to RIH, stacking out coil P/U to 9,049' and RIH to 9,057ft appeared to be pushing something P/U to 8,600ft (above tubing patch) with no problem RIH and tagged at 9057' PU to 8,000', couldn’t RIH. Worked pipe and pushed to 9,057' Brought on pump at 1.1BPM and attempted to wash down - no luck. 1:1 returns throughout Work pipe tagging 3x at 9,057' with no progress. SD pump and POOH. No indications on nozzle of any debris. I would like to propose pumping cement at 9057 per step 8 in the procedure bringing the cement up to 8500’. We recognize that this does not provide a plug isolating the Tyonek Pool and the Beluga/Upper Tyonek Pool and need a waiver from this requirement in this instance. We are unsure of what kept us from going downhole. With this unknown I am reluctant to pick up a mill to go through the patch and mill below it, potentially bringing debris above us and either getting coil stuck or losing more hole. I will give you a call 1st thing Monday morning and discuss options with you as we do have coil rigged up. Chad Helgeson KEN Operations Engineer Hilcorp Alaska LLC chelgeson@hilcorp.com 907-777-8405 (O) 907-229-4824 (C) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are 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. 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 5HJJ-DPHV%2*& )URP.DUVRQ.R]XE&NNR]XE#KLOFRUSFRP! 6HQW7XHVGD\6HSWHPEHU30 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*& &F-XDQLWD/RYHWW'RQQD$PEUX] 6XEMHFW)R[ $WWDFKPHQWV)R[[OV[ 'ŽŽĚǀĞŶŝŶŐ͕ ƚƚĂĐŚĞĚŝƐƚŚĞKWƚĞƐƚƌĞƉŽƌƚĨŽƌ&ŽǆϴdhϬϵͲϭϭͲϮϬϮϮ͘ <ĞŶĂŝĞůƵŐĂhŶŝƚ<hϰϮͲϬϲz;WdϮϭϰͲϬϴϵͿ;^ƵŶĚƌǇϯϮϮͲϰϴϮͿ͘ ZĞŐĂƌĚƐ͕ KarsonKozub ǣΪͳȋͻͲ͹Ȍͷ͹ͲǦͳͺͲͳ ̷Ǥ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ll BOPE reports are due to the agency within 5 days of testing* SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:8 DATE: 9/11/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2140890 Sundry #322-482 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:N/A Valves:250/3500 MASP:2704 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.NA Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 0NA Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75"P Trip Tank NA NA Annular Preventer 0NAPit Level Indicators NA NA #1 Rams 1 1.75" BS P Flow Indicator NA NA #2 Rams 1 1.75" PS P Meth Gas Detector NA NA #3 Rams 0NAH2S Gas Detector NA NA #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 2"P Time/Pressure Test Result HCR Valves 0NASystem Pressure (psi)3000 P Kill Line Valves 2 2"P Pressure After Closure (psi)2400 P Check Valve 0NA200 psi Attained (sec)4 P BOP Misc 0NAFull Pressure Attained (sec)10 P Blind Switch Covers: All stations YES CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): NA NA No. Valves 5P ACC Misc 0NA Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 0 NA #1 Rams 15 P Coiled Tubing Only:#2 Rams 11 P Inside Reel valves 1P #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:3.5 HCR Choke 0 NA Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice YES Date/Time 9/9/22 19:25hrs Waived By Test Start Date/Time:9/11/2022 8:00 (date) (time)Witness Test Finish Date/Time:9/11/2022 11:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Fox Accumulator system 4 bottles at 1400psi precharge. 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OEV VODFNRII ZHLJKW 3URYLGH KUV QRWLFH IRU $2*&& ZLWQHVV RI FHPHQW WDJ ; ; &7 %23 WHVW WR SVL %-0 '65 '/% GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.08.23 10:16:29 -08'00' RBDMS JSB 082422 tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗<hϰϮͲϬϲz ĂƚĞ͗ϴͬϭϮͬϮϬϮϮ tĞůůEĂŵĞ͗<hϰϮͲϬϲzW/EƵŵďĞƌ͗ϱϬͲϭϭϯͲϮϬϲϯϰͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗'ĂƐWƌŽĚƵĐĞƌ>ĞŐ͗Eͬ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌϳϳϳͲϴϯϬϱWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϭϰͲϬϴϵ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ;ϵϬϳͿϳϳϳͲϴϰϬϱ;ŽͿ;ϵϬϳͿϮϮϵͲϰϴϮϰ;ĐͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ZǇĂŶZƵƉĞƌƚ;ϵϬϳͿϳϳϳͲϴϱϬϯ;ŽͿ;ϵϬϳͿϯϬϭͲϭϳϯϲ;ĐͿ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗Ϯ͕ϬϴϲƉƐŝΛϱ͕ϴϰϯ͛dsĂƐĞĚŽŶϰϯͲϬϳzZ&dĚĂƚĂŽŶϯͬϮϬϭϰ DĂǆŝŵƵŵǆƉĞĐƚĞĚ,WϮ͕ϵϴϰƉƐŝΛϲ͕ϲϯϭ͛dsĂƐĞĚŽŶϬ͘ϰϱƉƐŝͬĨƚŐƌĂĚŝĞŶƚ DĂǆŝŵƵŵWŽƚĞŶƚŝĂů^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗ΕϮ͕ϳϬϰƉƐŝΛϲ͕ϲϯϭ͛dshƐŝŶŐϬ͘ϭƉƐŝͬĨƚŐƌĂĚŝĞŶƚϮϬ Ϯϱ͘ϮϴϬ;ďͿ;ϰͿ tĞůů^ƵŵŵĂƌǇ <hϰϮͲϬϲzǁĂƐĂƐƚĞĂĚǇdǇŽŶĞŬ'ĂƐWŽŽůηϭƉƌŽĚƵĐĞƌ͘ĚĚŝƚŝŽŶĂůƉĞƌĨƐǁĞƌĞĂĚĚĞĚŝŶϮϬϮϭĂŶĚƚŚĞǁĞůůďƌŽƵŐŚƚ ŝŶǁĂƚĞƌĂŶĚĚŝĞĚ͘dŚĞǁĞƚǌŽŶĞǁĂƐƉĂƚĐŚĞĚ͕ďƵƚƚŚĞǁĞůůǁĂƐŶŽƚĂďůĞƚŽƉƌŽĚƵĐĞĂŐĂŝŶ͘ dŚĞŐŽĂůŽĨƚŚŝƐƉƌŽũĞĐƚŝƐƚŽƉůƵŐďĂĐŬƚŚĞůŽǁĞƌƐĞĐƚŝŽŶŽĨƚ ŚĞǁĞůů͕;ĂďĂŶĚŽŶŝŶŐƚŚĞdǇŽŶĞŬWŽŽůͿĂŶĚƉĞƌĨŽƌĂƚĞ ĂĚĚŝƚŝŽŶĂůƐĂŶĚƐŝŶƚŚĞĞůƵŐĂͬhƉƉĞƌdǇŽŶĞŬWŽŽů͕ƉĞƌKϱϭϬ͕ƚŽĂĚĚƉƌŽĚƵĐƚŝŽŶƚŽƚŚĞǁĞůů͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ xWĞƌŵĂŶĞŶƚƉĂƚĐŚƐĞƚĂƚϴ͕ϲϳϵǁŝƚŚĂϯ͘ϱ͟/͘ xDŝŶ/ĂďŽǀĞƉĂƚĐŚŝƐϰ͘Ϯϳϲ͟;ϱ͟ƚƵďŝŶŐͬůŝŶĞƌ/Ϳ xDĂǆ/ŶĐůŝŶĂƚŝŽŶсϯϯĚĞŐƌĞĞƐĂƚϯϭϱϮ͛D xdǇŽŶĞŬWŽŽůƚŽƉƉĞƌĨΛϵ͕ϴϯϬ͛ x^>ƚĂŐŐĞĚŚĂƌĚĨŝůů;ƵŶĂďůĞƚŽďĂŝůͿΛϵ͕ϬϮϲ͛ŽŶϴͬϲͬϮϮ EŝƚƌŽŐĞŶZŝƐŬ xŝƐĐƵƐƐŶŝƚƌŽŐĞŶĂƐƉŚǇǆŝĂƚŝŽŶĐŽŶĐĞƌŶƐĂŶĚŝĚĞŶƚŝĨǇĂŶǇĂƌĞĂƐǁŚĞƌĞŶŝƚƌŽŐĞŶĐŽƵůĚĐŽůůĞĐƚĂŶĚƉĞŽƉůĞ ĐŽƵůĚĞŶƚĞƌ͘ xŽŶƐŝĚĞƌƚĂŶŬƉůĂĐĞŵĞŶƚďĂƐĞĚŽŶǁŝŶĚĚŝƌĞĐƚŝŽŶĂŶĚĐƵƌƌĞŶƚǁĞĂƚŚĞƌĨŽƌĞĐĂƐƚ;ǀĞŶƚŝŶŐEŝƚƌŽŐĞŶ ĚƵƌŝŶŐƚŚŝƐũŽďͿ xŶƐƵƌĞĂůůĐƌĞǁƐĂƌĞĂǁĂƌĞŽĨƐƚŽƉǁŽƌŬĂƵƚŚŽƌŝƚǇ Ͳ>ŝŶĞWĞƌĨ ϭ͘D/ZhŽŝůƚƵďŝŶŐ͕ϮϰŚƌŶŽƚŝĐĞƚŽK'ĨŽƌKWƚĞƐƚ Ϯ͘ŽŶĚƵĐƚKWƚĞƐƚƚŽϮϱϬƉƐŝ>ŽǁͬϯϱϬϬƉƐŝŚŝŐŚ ϯ͘Z/,ǁͬǁĂƐŚŶŽǌǌůĞĂŶĚĐůĞĂŶǁĞůůŽƵƚƚŽϵϵϬϬĨƚ;ŵĂǇŚĂǀĞƚŽƵƐĞEϮͬĨŽĂŵƚŽůŝĨƚƐŽůŝĚƐĨƌŽŵǁĞůůͿ sZ/EZĞƋƵĞƐƚ͗/ĨƵŶĂďůĞƚŽĐůĞĂŶŽƵƚƚŽϵ͕ϵϬϬ͛ĂǀĂƌŝĂŶĐĞŝƐƌĞƋƵĞƐƚĞĚƚŽƐĞƚƚŚĞ dǇŽŶĞŬWŽŽůŝƐŽůĂƚŝŽŶƉůƵŐƐŚĂůůŽǁĞƌ;хϱϬĨƚͿĨƌŽŵƚŽƉŽĨƉĞƌĨƐŝŶdǇŽŶĞŬWŽŽů;фϵ͕ϴϳϬĨƚͿ͘/Ĩ ĐůĞĂŶŽƵƚĐĂŶŶŽƚďĞĐŽŵƉůĞƚĞĚƚŽĚĞĞƉĞƌƚŚĂŶϵ͕ϯϳϲĨƚ;ĞĞƉĞƐƚƉĞƌĨŽƌĂƚŝŽŶŝŶ ĞůƵŐĂͬhƉƉĞƌdǇŽŶĞŬWŽŽůͿ,ŝůĐŽƌƉǁŝůůŶŽƚŝĨǇK'ĂŶĚƌĞƋƵĞƐƚĂƉƉƌŽǀĂůƚŽƐĞƚƉůƵŐ ĂďŽǀĞƚŽƉŽĨƉŽŽů͘ ϰ͘ZhĐĞŵĞŶƚĞƌƐ͕ƉƌĞƐƐƵƌĞƚĞƐƚůŝŶĞƐ ϱ͘DŝǆϵďďůƐŽĨϭϱ͘ϯƚŽϭϱ͘ϴƉƉŐĐĞŵĞŶƚ '/% 9DULDQFH DQG FRQGLWLRQV RI YDULDQFH ZLOO EH FRQVLGHUHG ODWHU EDVHG RQ WKH GHSWK DFKLHYHG GXULQJ )&2 EMP dŚĞŐŽĂůŽĨƚŚŝƐƉƌŽũĞĐƚŝƐƚŽƉůƵŐďĂĐŬƚŚĞůŽǁĞƌƐĞĐƚŝŽŶŽĨƚŚĞǁĞůů͕;ĂďĂŶĚŽŶŝŶŐƚŚĞdǇŽŶĞŬWŽŽůͿĂŶĚƉĞƌĨŽƌĂƚĞ ĂĚĚŝƚŝŽŶĂůƐĂŶĚƐŝŶƚŚĞĞůƵŐĂͬhƉƉĞƌdǇŽŶĞŬWŽŽů͕ƉĞƌKϱϭϬ͕ƚŽĂĚĚƉƌŽĚƵĐƚŝŽŶƚŽƚŚĞǁĞůů͘ tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗<hϰϮͲϬϲz ĂƚĞ͗ϴͬϭϮͬϮϬϮϮ ϲ͘WƵŵƉĚŽǁŶĐŽŝůůĂǇŝŶŐŝŶϭƚŽϭĨƌŽŵϵϵϬϬĨƚƚŽϵϰϬϬĨƚƵƐŝŶŐĚŝƐƉůĂĐĞŵĞŶƚŵĞƚŚŽĚ͕WhĂŶĚĂƚƚĞŵƉƚ ƚŽĐŝƌĐƵůĂƚĞĂďŽǀĞĐĞŵĞŶƚƚŽƉ͕ǁĂŝƚŽŶĐĞŵĞŶƚŵŝŶŝŵƵŵϯͲϰŚƌƐĂĨƚĞƌƉƵŵƉŝŶŐ͕ƚĂŐƚŽƉŽĨĐĞŵĞŶƚ ǁŝƚŚŶŽǌǌůĞ ϳ͘DŝǆϭϲďďůƐŽĨϭϱ͘ϯƚŽϭϱ͘ϴƉƉŐĐĞŵĞŶƚ ϴ͘WƵŵƉĚŽǁŶĐŽŝůůĂǇŝŶŐŝŶĐĞŵĞŶƚƚŽϴϱϬϬĨƚƵƐŝŶŐĚŝƐƉůĂĐĞŵĞŶƚŵĞƚŚŽĚ͕WhĂŶĚĂƚƚĞŵƉƚƚŽ ĐŝƌĐƵůĂƚĞĂďŽǀĞĐĞŵĞŶƚƚŽƉ ϵ͘WKK,͕tK ϭϬ͘Z/,ĂŶĚũĞƚǁĞůůĚƌǇ͕ƵƐŝŶŐEϮ ϭϭ͘WKK,ĂŶĚƌŝŐĚŽǁŶdh ϭϮ͘D/ZhͲůŝŶĞĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ ϭϯ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϯ͕ϬϬϬƉƐŝ,ŝŐŚ ϭϰ͘ZŝŐƵƉƉĞƌĨŐƵŶŚŽůůŽǁĐĂƌƌŝĞƌǁŝƚŚϱͲϲƐƉĨ ϭϱ͘Z/,ĂŶĚƉĞƌĨŽƌĂƚĞƚŚĞƐĂŶĚƐůŝƐƚĞĚŝŶƚŚĞƚĂďůĞďĞůŽǁ͕ƉĞƌ'ĞŽͬZ͘ ^ĂŶĚƐdŽƉDƚŵDdŽƉdsƚŵds&dΖ >ϭцϲ͕ϴϲϯ͛цϲ͕ϴϳϵ͛цϲ͕ϭϮϳ͛цϲ͕ϭϰϭ͛ϭϲ͛ >ϭцϲ͕ϵϯϮ͛цϲ͕ϵϰϬ͛цϲ͕ϭϴϲ͛цϲ͕ϭϵϯ͛ϴ͛ >ϭцϲ͕ϵϱϭ͛цϲ͕ϵϲϭ͛цϲ͕ϮϬϮ͛цϲ͕Ϯϭϭ͛ϭϬ͛ >ϭцϳ͕Ϭϯϰ͛цϳ͕ϬϰϮ͛цϲ͕Ϯϳϯ͛цϲ͕ϮϴϬ͛ϴ͛ >ϭцϳ͕Ϭϵϴ͛цϳ͕ϭϬϲ͛цϲ͕ϯϮϴ͛цϲ͕ϯϯϲ͛ϴ͛ >ϭ&цϳ͕ϭϯϮ͛цϳ͕ϭϱϮ͛цϲ͕ϯϱϴ͛цϲ͕ϯϳϱ͛ϮϬ͛ >ϭ&цϳ͕ϮϮϴ͛цϳ͕Ϯϯϰ͛цϲ͕ϰϰϭ͛цϲ͕ϰϰϲ͛ϲ͛ >Ϯцϳ͕Ϯϲϭ͛цϳ͕ϮϳϬ͛цϲ͕ϰϳϬ͛цϲ͕ϰϳϴ͛ϵ͛ >Ϯцϳ͕Ϯϴϰ͛цϳ͕Ϯϵϲ͛цϲ͕ϰϵϭ͛цϲ͕ϱϬϮ͛ϭϮ͛ >Ϯцϳ͕ϯϮϱ͛цϳ͕ϯϰϱ͛цϲ͕ϱϮϴ͛цϲ͕ϱϰϲ͛ϮϬ͛ >Ϯцϳ͕ϯϲϱ͛цϳ͕ϯϳϯ͛цϲ͕ϱϲϰ͛цϲ͕ϱϳϭ͛ϴ͛ >Ϯцϳ͕ϯϵϰ͛цϳ͕ϰϬϵ͛цϲ͕ϱϵϬ͛цϲ͕ϲϬϰ͛ϭϱ͛ >Ϯцϳ͕ϰϱϵ͛цϳ͕ϰϲϴ͛цϲ͕ϲϱϬ͛цϲ͕ϲϱϴ͛ϵ͛ >Ϯцϳ͕ϰϳϰ͛цϳ͕ϰϳϵ͛цϲ͕ϲϲϯ͛цϲ͕ϲϲϴ͛ϱ͛ >ϯцϳ͕ϰϵϲ͛цϳ͕ϱϭϲ͛цϲ͕ϲϴϰ͛цϲ͕ϳϬϮ͛ϮϬ͛ >ϯцϳ͕ϱϯϱ͛цϳ͕ϱϰϵ͛цϲ͕ϳϮϬ͛цϲ͕ϳϯϯ͛ϭϰ͛ >ϯцϳ͕ϱϳϯ͛цϳ͕ϱϴϰ͛цϲ͕ϳϱϱ͛цϲ͕ϳϲϱ͛ϭϭ͛ >ϯцϳ͕ϱϵϵ͛цϳ͕ϲϭϮ͛цϲ͕ϳϳϵ͛цϲ͕ϳϵϭ͛ϭϯ͛ >ϰцϳ͕ϲϳϰ͛цϳ͕ϲϴϬ͛цϲ͕ϴϰϵ͛цϲ͕ϴϱϱ͛ϲ͛ >ϰцϳ͕ϳϱϲ͛цϳ͕ϳϳϲ͛цϲ͕ϵϮϳ͛цϲ͕Ϭϰϲ͛ϮϬ͛ >ϰцϳ͕ϴϭϵ͛цϳ͕ϴϮϱ͛цϲ͕ϵϴϳ͛цϲ͕ϵϵϮ͛ϲ͛ >ϰцϳ͕ϴϯϮ͛цϳ͕ϴϰϭ͛цϲ͕ϵϵϵ͛цϳ͕ϬϬϴ͛ϵ͛ >ϱцϳ͕ϵϲϴ͛цϳ͕ϵϳϯ͛цϳ͕ϭϯϬ͛цϳ͕ϭϯϰ͛ϱΖ Ă͘tĞůůǁŝůůďĞƐŚŽƚǁŝƚŚƚŚĞǁĞůůĨůŽǁŝŶŐ ď͘WƌŽƉŽƐĞĚƉĞƌĨƐƐŚŽǁŶŽŶƚŚĞƉƌŽƉŽƐĞĚƐĐŚĞŵĂƚŝĐŝŶƌĞĚĨŽŶƚ͘ Đ͘&ŝŶĂůƉĞƌĨƐƚŝĞͲŝŶƐƐŚĞĞƚǁŝůůďĞƉƌŽǀŝĚĞĚŝŶƚŚĞĨŝĞůĚĨŽƌĞǆĂ ĐƚƉĞƌĨŝŶƚĞƌǀĂůƐ͘ Ě͘^ƉĂĐŝŶŐĂůůŽǁĂŶĐĞŝƐďĂƐĞĚŽŶŽŶƐĞƌǀĂƚŝŽŶKƌĚĞƌϱϭϬŝŶƚŚĞĞůƵŐĂͬhƉƉĞƌdǇŽŶĞŬ'ĂƐWŽŽů͘ Ğ͘ZĞĐŽƌĚƚƵďŝŶŐƉƌĞƐƐƵƌĞƐďĞĨŽƌĞĂŶĚĂĨƚĞƌĞĂĐŚƉĞƌĨŽƌĂƚŝŶŐƌƵŶ͘ Ĩ͘ZĞĐŽƌĚϱ͕ϭϬĂŶĚϭϱŵŝŶƵƚĞƉƌĞƐƐƵƌĞƐĂĨƚĞƌĨŝƌŝŶŐŐƵŶƐ͘ 6ODFN RII VXIILFLHQW ZHLJKW WR FRQILUP WRS RI KDUG FHPHQW ! OEV 3URYLGH KUV QRWLFH IRU $2*&& ZLWQHVV EMP tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗<hϰϮͲϬϲz ĂƚĞ͗ϴͬϭϮͬϮϬϮϮ ϭϲ͘WKK,ĂŶĚZͲ>ŝŶĞ͘ ϭϳ͘dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ ŽŶƚŝŶŐĞŶĐǇ>WůƵŐŽƌWĂƚĐŚ ϭ͘D/ZhͲůŝŶĞ͕WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϯ͕ϬϬϬƉƐŝŚŝŐŚ Ϯ͘Z/,tͬ'WdƚŽŽůĂŶĚĨŝŶĚĨůƵŝĚůĞǀĞů ϯ͘ZhEŝƚƌŽŐĞŶdƌƵĐŬ Ă͘WƵƐŚǁĂƚĞƌďĂĐŬŝŶƚŽĨŽƌŵĂƚŝŽŶ ď͘hƐĞ'WdƚŽŽůƚŽĐŽŶĨŝƌŵǁĂƚĞƌůĞǀĞůŝƐďĞůŽǁŝŶƚĞƌǀĂůƚŽƉĂƚĐŚŽƌƉůƵŐ ϰ͘KŶĐĞĨůƵŝĚůĞǀĞůŝƐďĞůŽǁŝŶƚĞƌǀĂůƚŽŝƐŽůĂƚĞ͕Dhϱ͟ƉĂƚĐŚŽƌƉůƵŐ ϱ͘ZͲ>ŝŶĞhŶŝƚĂŶĚƚƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ƵƌƌĞŶƚƐĐŚĞŵĂƚŝĐ Ϯ͘WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘dKW^ĐŚĞŵĂƚŝĐ ϰ͘^ƚĂŶĚĂƌĚtĞůůƉƌŽĐĞĚƵƌĞʹEϮKƉĞƌĂƚŝŽŶƐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ,ϬϴͲϭϮͲϮϮ ^,Dd/ <ĞŶĂŝ'ĂƐ&ŝĞůĚ tĞůů͗<hϰϮͲϬϲz Wd͗ϮϭϰͲϬϴϵ W/͗ϱϬͲϭϯϯͲϮϬϲϯϰͲϬϬͲϬϬ ^/E'd/> ^ŝǌĞdǇƉĞtƚͬ'ƌĂĚĞͬŽŶŶ/dŽƉƚŵ ϭϲΗŽŶĚƵĐƚŽƌϭϬϵͬyͲϱϲͬtĞůĚ^ƵƌĨϭϯϱΖ ϭϬͲϯͬϰ͟^ƵƌĨĂĐĞϰϱ͘ϱͬ>ͲϴϬͬdϵ͘ϵϱϬ^ƵƌĨϭ͕ϱϵϱΖ ϳͲϱͬϴΗ/ŶƚĞƌŵĞĚŝĂƚĞϮϵ͘ϳͬ>ͲϴϬͬdϲ͘ϴϳϱ^ƵƌĨϲ͕ϰϴϯΖ ϱΗWƌŽĚƵĐƚŝŽŶϭϴͬ>ͲϴϬͬtͬͲ,dϰ͘Ϯϳϲ^ƵƌĨϭϬ͕ϴϵϮ͛ :t>Zzd/> EŽĞƉƚŚ/ƚĞŵ ϭϲ͕ϬϬϲ͛ϱ͟^ǁĞůůWĂĐŬĞƌ Ϯϴ͕ϲϳϵ͛KǁĞŶyͲ^ƉĂŶWĂƚĐŚϯ͘ϱ͟/͕ϭϬ͛ƉĂƚĐŚ ;ϭϭͬϭϳͬϮϭͿϴ͕ϲϳϵ͛Ͳϴ͕ϲϵϭ͛ ϯϵ͕ϰϮϱ͛ZWƵƉϵ͕ϰϮϱΘϵ͕ϲϯϭ ϰϭϬ͕ϭϳϱ͛/WĐĂƉƉĞĚǁͬϱ͛Đŵƚ;ϭϭͬϭϯͬϭϰͿ ϱϭϬ͕ϭϵϵ͛ZWƵƉ ϲϭϬ͕ϮϳϬ͛/WĐĂƉƉĞĚǁͬĐŵƚ;ϭϭͬϰͬϭϰͿ ϳϭϬ͕ϯϲϬ͛/WĐĂƉƉĞĚǁͬĐŵƚ;ϵͬϲͬϭϰͿ KWE,K>ͬDEdd/> ϭϬͲϯͬϰ͟ϭϲϱ>͛ƐŽĨĐĞŵĞŶƚŝŶϭϯ͘ϱ͟,ŽůĞ͘ZĞƚƵƌŶƐƚŽ^ƵƌĨĂĐĞ ϳͲϱͬϴΗϭϵϳ>͛ƐŽĨĐĞŵĞŶƚŝŶϵͲϳͬϴ͟,ŽůĞ͘dKϭ͕ϱϳϱ͛ĂůĐƵůĂƚĞĚ ϱ͟ϭϰϱ>͛ƐŽĨĐĞŵĞŶƚŝŶϲͲϯͬϰ͟,ŽůĞ͘dKϰ͕ϭϱϬ͛ĂůĐƵůĂƚĞĚ͘WĞƌϴͬϭϰͬϭϰ ^Dd͗&ƌĞĞƉŝƉĞĂďŽǀĞϯϲϬϬ͛͘dŽƉƐŽůŝĚĐĞŵĞŶƚĂƚϱϯϵϬ͛D WZ&KZd/KEd/> ^ĂŶĚƐdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ&dWŽŽů ĂƚĞ^ƚĂƚƵƐ DͲϲ ϲ͕ϱϮϱ͛ϲ͕ϱϰϭ͛ϱ͕ϴϯϳ͛ϱ͕ϴϱϯ͛ϭϲ͛ĞůƵŐĂͬhƉƌͺdǇϭͬϭϰͬϮϮKƉĞŶ DͲϵ>ǁƌϲ͕ϴϯϬ͛ϲ͕ϴϰϬ͛ϲ͕Ϭϵϵ͛ϲ͕ϭϬϳ͛ϭϬ͛ĞůƵŐĂͬhƉƌͺdǇϭͬϭϰͬϮϮKƉĞŶ >Ͳϭϲ͕ϵϭϮ͛ϲ͕ϵϭϴ͛ϲ͕͕ϭϲϵ͛ϲ͕ϭϳϰ͛ϲ͛ĞůƵŐĂͬhƉƌͺdǇϭϮͬϯϬͬϮϭKƉĞŶ >Ͳϭϲ͕ϵϭϰ͛ϲ͕ϵϭϴ͛ϲϭϳϭ͛ϲ͕ϭϳϰ͛ϰ͛ĞůƵŐĂͬhƉƌͺdǇϭϮͬϯϬͬϮϭKƉĞŶ >ϭϳ͕ϬϵϴΖϳ͕ϭϬϲΖϲ͕ϯϮϴΖϲ͕ϯϯϲΖϴΖĞůƵŐĂͬhƉƌͺdǇϭϮͬϯϬͬϮϭKƉĞŶ >Ͳϭ&ϳ͕ϭϯϵ͛ϳ͕ϭϱϮ͛ϲ͕ϯϲϰ͛ϲ͕ϯϳϱ͛ϭϯ͛ĞůƵŐĂͬhƉƌͺdǇϭϮͬϯϬͬϮϭKƉĞŶ >ͲϮ ϳ͕Ϯϱϯ͛ϳ͕Ϯϱϴ͛ϲ͕ϰϲϯ͛ϲ͕ϰϲϴ͛ϱ͛ĞůƵŐĂͬhƉƌͺdǇϭϮͬϯϬͬϮϭKƉĞŶ hdϯϴ͕ϲϴϮΖϴ͕ϲϴϴΖϳ͕ϴϮϰΖϳ͕ϴϯϬΖϲΖĞůƵŐĂͬhƉƌͺdǇϳͬϮϲͬϮϭ/ƐŽůĂƚĞĚ ;ƉĂƚĐŚͿ hdϰϵ͕ϬϮϱΖϵ͕ϬϰϱΖϴ͕ϭϲϱ͛ϴ͕ϭϴϱ͛ϮϬΖĞůƵŐĂͬhƉƌͺdǇϳͬϮϲͬϮϭKƉĞŶ dzͺϴϰͺϲϵ͕ϯϱϳΖϵ͕ϯϳϲΖϴ͕ϰϵϴΖϴ͕ϱϭϳΖϭϵΖĞůƵŐĂͬhƉƌͺdǇϳͬϮϲͬϮϭKƉĞŶ ͲϮ ϵ͕ϴϯϬ͛ϵ͕ϴϰϱ͛ϴ͕ϵϲϳ͛ϴ͕ϵϴϮ͛ϭϱ͛dǇ'ĂƐWŽŽůηϭϬϳͬϬϴͬϮϭKƉĞŶ ͲϯϭϬ͕Ϭϴϯ͛ϭϬ͕ϭϬϭ͛ϵ͕ϭϯϰ͛ϵ͕ϭϱϮ͛ϭϴ͛dǇ'ĂƐWŽŽůηϭϬϮͬϬϳͬϭϳKƉĞŶ ͲϯϭϬ͕ϭϯϮ͛ϭϬ͕ϭϲϵ͛ϵ͕Ϯϲϴ͛ϵ͕ϯϬϱ͛ϯϳ͛dǇ'ĂƐWŽŽůηϭϭϮͬϬϱͬϭϰKƉĞŶ ͲϯϭϬ͕ϭϳϴ͛ϭϬ͕ϭϵϴ͛ϵ͕ϯϭϰ͛ϵ͕ϯϯϰ͛ϮϬ͛dǇ'ĂƐWŽŽůηϭϭϭͬϬϰͬϭϰ/ƐŽůĂƚĞĚʹǁĞƚ ;ϭϭͬϭϯͬϮϬϭϰͿ Ͳϰ;ϰͿϭϬ͕Ϯϵϲ͛ϭϬ͕ϯϭϯ͛ϵ͕ϰϯϭ͛ϵ͕ϰϰϴ͛ϭϳ͛dǇ'ĂƐWŽŽůηϭϬϵͬϬϳͬϭϰ/ƐŽůĂƚĞĚ ;ϭϭͬϰͬϮϬϭϰͿϭϬ͕ϯϭϯ͛ϭϬ͕ϯϯϯ͛ϵ͕ϰϰϴ͛ϵ͕ϰϲϴ͛ϮϬ͛dǇ'ĂƐWŽŽůηϭϬϵͬϬϳͬϭϰ Ͳϱ ;ϰͿ ϭϬ͕ϯϳϮ͛ϭϬ͕ϯϴϬ͛ϵ͕ϱϬϳ͛ϵ͕ϱϭϱ͛ϴ͛dǇ'ĂƐWŽŽůηϭϬϵͬϬϮͬϭϰ/ƐŽůĂƚĞĚ ;ϵͬϲͬϮϬϭϰͿ ƚĞƐƚĞĚƚŝŐŚƚ͕ ƉŽƐƐŝďůǇǁĞƚ ϭϬ͕ϯϴϬ͛ϭϬ͕ϯϵϰ͛ϵ͕ϱϭϱ͛ϵ͕ϱϮϵ͛ϭϰ͛dǇ'ĂƐWŽŽůηϭϬϵͬϬϮͬϭϰ )LVK&,%3PLOOHGDQGSXVKHGWRERWWRPZ:25LJ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ,ϬϴͲϭϮͲϮϮ WZKWK^ <ĞŶĂŝ'ĂƐ&ŝĞůĚ tĞůů͗<hϰϮͲϬϲz Wd͗ϮϭϰͲϬϴϵ W/͗ϱϬͲϭϯϯͲϮϬϲϯϰͲϬϬͲϬϬ ^/E'd/> ^ŝǌĞdǇƉĞtƚͬ'ƌĂĚĞͬŽŶŶ/dŽƉƚŵ ϭϲΗŽŶĚƵĐƚŽƌϭϬϵͬyͲϱϲͬtĞůĚ^ƵƌĨϭϯϱΖ ϭϬͲϯͬϰ͟^ƵƌĨĂĐĞϰϱ͘ϱͬ>ͲϴϬͬdϵ͘ϵϱϬ^ƵƌĨϭ͕ϱϵϱΖ ϳͲϱͬϴΗ/ŶƚĞƌŵĞĚŝĂƚĞϮϵ͘ϳͬ>ͲϴϬͬdϲ͘ϴϳϱ^ƵƌĨϲ͕ϰϴϯΖ ϱΗWƌŽĚƵĐƚŝŽŶϭϴͬ>ͲϴϬͬtͬͲ,dϰ͘Ϯϳϲ^ƵƌĨϭϬ͕ϴϵϮ͛ :t>Zzd/> EŽĞƉƚŚ/ƚĞŵ ϭϲ͕ϬϬϲ͛ϱ͟^ǁĞůůWĂĐŬĞƌ Ϯϴ͕ϲϳϵ͛KǁĞŶyͲ^ƉĂŶWĂƚĐŚϯ͘ϱ͟/͕ϭϬ͛ƉĂƚĐŚ ;ϭϭͬϭϳͬϮϭͿϴ͕ϲϳϵ͛Ͳϴ͕ϲϵϭ͛ ϯϵ͕ϰϮϱ͛ZWƵƉϵ͕ϰϮϱΘϵ͕ϲϯϭ ϰϭϬ͕ϭϳϱ͛/WĐĂƉƉĞĚǁͬϱ͛Đŵƚ;ϭϭͬϭϯͬϭϰͿ ϱϭϬ͕ϭϵϵ͛ZWƵƉ ϲϭϬ͕ϮϳϬ͛/WĐĂƉƉĞĚǁͬĐŵƚ;ϭϭͬϰͬϭϰͿ ϳϭϬ͕ϯϲϬ͛/WĐĂƉƉĞĚǁͬĐŵƚ;ϵͬϲͬϭϰͿ KWE,K>ͬDEdd/> ϭϬͲϯͬϰ͟ϭϲϱ>͛ƐŽĨĐĞŵĞŶƚŝŶϭϯ͘ϱ͟,ŽůĞ͘ZĞƚƵƌŶƐƚŽ^ƵƌĨĂĐĞ ϳͲϱͬϴΗϭϵϳ>͛ƐŽĨĐĞŵĞŶƚŝŶϵͲϳͬϴ͟,ŽůĞ͘dKϭ͕ϱϳϱ͛ĂůĐƵůĂƚĞĚ ϱ͟ϭϰϱ>͛ƐŽĨĐĞŵĞŶƚŝŶϲͲϯͬϰ͟,ŽůĞ͘dKϰ͕ϭϱϬ͛ĂůĐƵůĂƚĞĚ͘WĞƌϴͬϭϰͬϭϰ ^Dd͗&ƌĞĞƉŝƉĞĂďŽǀĞϯϲϬϬ͛͘dŽƉƐŽůŝĚĐĞŵĞŶƚĂƚϱϯϵϬ͛D WZ&KZd/KEd/> ^ĂŶĚƐdŽƉ DƚŵDdŽƉdsƚŵds&dΖWŽŽů ĂƚĞ ^ƚĂƚƵƐ DͲϲϲ͕ϱϮϱ͛ϲ͕ϱϰϭ͛ϱ͕ϴϯϳ͛ϱ͕ϴϱϯ͛ϭϲ͛ĞůƵŐĂͬhƉƌͺdǇϭͬϭϰͬϮϮKƉĞŶ DͲϵ>ǁƌϲ͕ϴϯϬ͛ϲ͕ϴϰϬ͛ϲ͕Ϭϵϵ͛ϲ͕ϭϬϳ͛ϭϬ͛ĞůƵŐĂͬhƉƌͺdǇϭͬϭϰͬϮϮKƉĞŶ >ϭцϲ͕ϴϲϯ͛цϲ͕ϴϳϵ͛цϲ͕ϭϮϳ͛цϲ͕ϭϰϭ͛цϭϲ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >ϭцϲ͕ϵϯϮ͛цϲ͕ϵϰϬ͛цϲ͕ϭϴϲ͛цϲ͕ϭϵϯ͛цϴ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >Ͳϭϲ͕ϵϭϮ͛ϲ͕ϵϭϴ͛ϲ͕ϭϲϵ͛ϲ͕ϭϳϰ͛ϲ͛ĞůƵŐĂͬhƉƌͺdǇϭϮͬϯϬͬϮϭKƉĞŶ >Ͳϭϲ͕ϵϭϰ͛ϲ͕ϵϭϴ͛ϲϭϳϭ͛ϲ͕ϭϳϰ͛ϰ͛ĞůƵŐĂͬhƉƌͺdǇϭϮͬϯϬͬϮϭKƉĞŶ >ϭцϲ͕ϵϱϭ͛цϲ͕ϵϲϭ͛цϲ͕ϮϬϮ͛цϲ͕Ϯϭϭ͛цϭϬ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >ϭцϳ͕Ϭϯϰ͛цϳ͕ϬϰϮ͛цϲ͕Ϯϳϯ͛цϲ͕ϮϴϬ͛цϴ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >ϭϳ͕ϬϵϴΖϳ͕ϭϬϲΖϲ͕ϯϮϴΖϲ͕ϯϯϲΖϴΖĞůƵŐĂͬhƉƌͺdǇϭϮͬϯϬͬϮϭKƉĞŶ >ϭцϳ͕Ϭϵϴ͛цϳ͕ϭϬϲ͛цϲ͕ϯϮϴ͛цϲ͕ϯϯϲ͛цϴ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >ϭ&цϳ͕ϭϯϮ͛цϳ͕ϭϱϮ͛цϲ͕ϯϱϴ͛цϲ͕ϯϳϱ͛цϮϬ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >Ͳϭ&ϳ͕ϭϯϵ͛ϳ͕ϭϱϮ͛ϲ͕ϯϲϰ͛ϲ͕ϯϳϱ͛ϭϯ͛ĞůƵŐĂͬhƉƌͺdǇϭϮͬϯϬͬϮϭKƉĞŶ >ϭ&цϳ͕ϮϮϴ͛цϳ͕Ϯϯϰ͛цϲ͕ϰϰϭ͛цϲ͕ϰϰϲ͛цϲ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >ͲϮϳ͕Ϯϱϯ͛ϳ͕Ϯϱϴ͛ϲ͕ϰϲϯ͛ϲ͕ϰϲϴ͛ϱ͛ĞůƵŐĂͬhƉƌͺdǇϭϮͬϯϬͬϮϭKƉĞŶ >Ϯцϳ͕Ϯϲϭ͛цϳ͕ϮϳϬ͛цϲ͕ϰϳϬ͛цϲ͕ϰϳϴ͛цϵ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >Ϯцϳ͕Ϯϴϰ͛цϳ͕Ϯϵϲ͛цϲ͕ϰϵϭ͛цϲ͕ϱϬϮ͛цϭϮ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >Ϯцϳ͕ϯϮϱ͛цϳ͕ϯϰϱ͛цϲ͕ϱϮϴ͛цϲ͕ϱϰϲ͛цϮϬ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >Ϯцϳ͕ϯϲϱ͛цϳ͕ϯϳϯ͛цϲ͕ϱϲϰ͛цϲ͕ϱϳϭ͛цϴ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >Ϯцϳ͕ϯϵϰ͛цϳ͕ϰϬϵ͛цϲ͕ϱϵϬ͛цϲ͕ϲϬϰ͛цϭϱ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >Ϯцϳ͕ϰϱϵ͛цϳ͕ϰϲϴ͛цϲ͕ϲϱϬ͛цϲ͕ϲϱϴ͛цϵ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >Ϯцϳ͕ϰϳϰ͛цϳ͕ϰϳϵ͛цϲ͕ϲϲϯ͛цϲ͕ϲϲϴ͛цϱ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >ϯцϳ͕ϰϵϲ͛цϳ͕ϱϭϲ͛цϲ͕ϲϴϰ͛цϲ͕ϳϬϮ͛цϮϬ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >ϯцϳ͕ϱϯϱ͛цϳ͕ϱϰϵ͛цϲ͕ϳϮϬ͛цϲ͕ϳϯϯ͛цϭϰ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >ϯцϳ͕ϱϳϯ͛цϳ͕ϱϴϰ͛цϲ͕ϳϱϱ͛цϲ͕ϳϲϱ͛цϭϭ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >ϯцϳ͕ϱϵϵ͛цϳ͕ϲϭϮ͛цϲ͕ϳϳϵ͛цϲ͕ϳϵϭ͛цϭϯ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >ϰцϳ͕ϲϳϰ͛цϳ͕ϲϴϬ͛цϲ͕ϴϰϵ͛цϲ͕ϴϱϱ͛цϲ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >ϰцϳ͕ϳϱϲ͛цϳ͕ϳϳϲ͛цϲ͕ϵϮϳ͛цϲ͕Ϭϰϲ͛цϮϬ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >ϰцϳ͕ϴϭϵ͛цϳ͕ϴϮϱ͛цϲ͕ϵϴϳ͛цϲ͕ϵϵϮ͛цϲ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >ϰцϳ͕ϴϯϮ͛цϳ͕ϴϰϭ͛цϲ͕ϵϵϵ͛цϳ͕ϬϬϴ͛цϵ͛ĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd >ϱцϳ͕ϵϲϴ͛цϳ͕ϵϳϯ͛цϳ͕ϭϯϬ͛цϳ͕ϭϯϰ͛цϱΖĞůƵŐĂͬhƉƌͺdǇWƌŽƉŽƐĞĚd WZ&KZd/KEd/>ͲĐŽŶƚŝŶƵĞĚŽŶĨŽůůŽǁŝŶŐƉĂŐĞ )LVK&,%3PLOOHGDQGSXVKHGWRERWWRPZ:25LJ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ,ϬϴͲϬϯͲϮϮ WZKWK^ŽŶƚŝŶŐĞŶĐǇ <ĞŶĂŝ'ĂƐ&ŝĞůĚ tĞůů͗<hϰϮͲϬϲz Wd͗ϮϭϰͲϬϴϵ W/͗ϱϬͲϭϯϯͲϮϬϲϯϰͲϬϬͲϬϬ WZ&KZd/KEd/>ʹĐŽŶƚŝŶƵĞĚĨƌŽŵƉƌĞǀŝŽƵƐƉĂŐĞ ^ĂŶĚƐdŽƉDƚŵDdŽƉdsƚŵds&dΖWŽŽůĂƚĞ^ƚĂƚƵƐ hdϯϴ͕ϲϴϮΖϴ͕ϲϴϴΖϳ͕ϴϮϰΖϳ͕ϴϯϬΖϲΖĞůƵŐĂͬhƉƌͺdǇϳͬϮϲͬϮϭ/ƐŽůĂƚĞĚ;ƉĂƚĐŚͿ hdϰϵ͕ϬϮϱΖϵ͕ϬϰϱΖϴ͕ϭϲϱ͛ϴ͕ϭϴϱ͛ϮϬΖĞůƵŐĂͬhƉƌͺdǇϳͬϮϲͬϮϭKƉĞŶ dzͺϴϰͺϲϵ͕ϯϱϳΖϵ͕ϯϳϲΖϴ͕ϰϵϴΖϴ͕ϱϭϳΖϭϵΖĞůƵŐĂͬhƉƌͺdǇϳͬϮϲͬϮϭKƉĞŶ ͲϮϵ͕ϴϯϬ͛ϵ͕ϴϰϱ͛ϴ͕ϵϲϳ͛ϴ͕ϵϴϮ͛ϭϱ͛dǇ'ĂƐWŽŽůηϭϬϳͬϬϴͬϮϭKƉĞŶ ͲϯϭϬ͕Ϭϴϯ͛ϭϬ͕ϭϬϭ͛ϵ͕ϭϯϰ͛ϵ͕ϭϱϮ͛ϭϴ͛dǇ'ĂƐWŽŽůηϭϬϮͬϬϳͬϭϳKƉĞŶ ͲϯϭϬ͕ϭϯϮ͛ϭϬ͕ϭϲϵ͛ϵ͕Ϯϲϴ͛ϵ͕ϯϬϱ͛ϯϳ͛dǇ'ĂƐWŽŽůηϭϭϮͬϬϱͬϭϰKƉĞŶ ͲϯϭϬ͕ϭϳϴ͛ϭϬ͕ϭϵϴ͛ϵ͕ϯϭϰ͛ϵ͕ϯϯϰ͛ϮϬ͛dǇ'ĂƐWŽŽůηϭϭϭͬϬϰͬϭϰ/ƐŽůĂƚĞĚʹǁĞƚ ;ϭϭͬϭϯͬϮϬϭϰͿ Ͳϰ;ϰͿϭϬ͕Ϯϵϲ͛ϭϬ͕ϯϭϯ͛ϵ͕ϰϯϭ͛ϵ͕ϰϰϴ͛ϭϳ͛dǇ'ĂƐWŽŽůηϭϬϵͬϬϳͬϭϰ/ƐŽůĂƚĞĚ ;ϭϭͬϰͬϮϬϭϰͿϭϬ͕ϯϭϯ͛ϭϬ͕ϯϯϯ͛ϵ͕ϰϰϴ͛ϵ͕ϰϲϴ͛ϮϬ͛dǇ'ĂƐWŽŽůηϭϬϵͬϬϳͬϭϰ Ͳϱ ;ϰͿ 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KŶĐĞǇŽƵŚĂǀĞĐŽŶĨŝƌŵĞĚůŝŶĞƐĂƌĞďůĞĚĚŽǁŶ͕ŶŽƚƌĂƉƉĞĚƉƌĞƐƐƵƌĞĞǆŝƐƚƐ͕ĂŶĚŶŽŶŝƚƌŽŐĞŶŚĂƐ ĂĐĐƵŵƵůĂƚĞĚďĞŐŝŶƌŝŐĚŽǁŶŽĨůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϳ͘Ϳ &ŝŶĂůŝǌĞũŽďůŽŐĂŶĚĚŝƐĐƵƐƐŽƉĞƌĂƚŝŽŶƐǁŝƚŚtĞůůƐŝƚĞDĂŶĂŐĞƌ͘ŽĐƵŵĞŶƚĂŶǇůĞƐƐŽŶƐůĞĂƌŶĞĚ ĂŶĚĐŽŶĨŝƌŵĨŝŶĂůƌĂƚĞƐͬƉƌĞƐƐƵƌĞͬǀŽůƵŵĞƐŽĨƚŚĞũŽďĂŶĚƌĞŵĂŝŶŝŶŐŶŝƚƌŽŐĞŶŝŶƚŚĞƚƌĂŶƐƉŽƌƚ͘ ϭϴ͘Ϳ ZDKEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 1/31/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 42-06Y (PTD 214-089) Perf 01/14/2022 Please include current contact information if different from above. 37' (6HW Received By: 02/07/2022 By Abby Bell at 3:01 pm, Feb 04, 2022 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 1/12/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 4-06Y (PTD 214-089) PERF 12/30/2021 Please include current contact information if different from above. 37' (6HW Received By: 01/12/2022 By Abby Bell at 10:51 am, Jan 12, 2022 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 12/28/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 42-06Y (PTD 214-089) Patch 11/17/2021 Please include current contact information if different from above. 37' (6HW Received By: 12/29/2021 By Abby Bell at 8:57 am, Dec 29, 2021 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:Chad Helgeson Cc:Roby, David S (OGC); Boyer, David L (OGC) Subject:RE: KBU 42-06Y (PTD #214-089) Sundry # 321-456 & 321-499 Date:Thursday, December 16, 2021 8:46:00 AM Jake, You have approval to add the perf intervals listed below. Since these additional perfs are in the middle of already approved perf intervals, and in the same pool, we will approve this work by email. No need for an additional Sundry. Please include this email approval with your 10-404. 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: Chad Helgeson <chelgeson@hilcorp.com> Sent: Thursday, December 16, 2021 7:27 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: KBU 42-06Y (PTD #214-089) Sundry # 321-456 & 321-499 Bryan, We have two open Sundries at Kenai Gas Field on well KBU 42-06Y, (the first is a coil blowdown and perf and the second one is a patch install.) We have completed the patch install and the coil cleanout and blowdown and have returned the well to some production (currently flowing approximately 300 mcf). We have not perforated any of the approved sands yet and our geologist would like to add a couple zones in the middle of the approved sands in lower beluga. Would you prefer these in a change approved sundry request, and if so, I assume Sundry # 321-456? The perf request is in the lower Beluga in the middle of what was already approved and requested in the Beluga/Upper Tyonek Gas Pool. The sands we would like to add are: Sands Top (MD)Btm (MD)FT LB 1A ±6,912’±6,918'6' LB 1F ±7,139'±7,152'13' LB1 ±7,253'±7,258'5' Thanks and please let me know what additional paperwork you need for these perf changes. Let me know if you have any questions on this as well. Chad Helgeson ASC Operations Engineer Hilcorp Alaska LLC chelgeson@hilcorp.com 907-777-8405 (O) 907-229-4824 (C) 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 herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___patch_____ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,895'See schematic Casing Collapse Structural Conductor Surface 2,470psi Intermediate 4,790psi Production 10,490psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Jake Flora Operations Manager Contact Email: Contact Phone: 777-8442 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 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 30, 2021 N/A 10,892' Perforation Depth MD (ft): 6,483' See Attached Schematic 10,892' 10,026'5" 16" 10-3/4" 135' 7-5/8"6,483' 1,595'5,210psi 135' 1,570' 5,801' 135' 1,595' N/A TVD Burst N/A 10,140psi MD 6,890psi Length Size CO 510B Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE A028142 214-089 50-133-20634-00-00 KBU 42-06Y Kenai Gas Field - Tyonek Gas Pool 1 / Added Beluga-Upper Tyonek Gas Poo COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic jake.flora@hilcorp.com 10,029'10,175'9,311'~1200psi See schematic Swell Pkr; N/A 6,006' MD / 5,387' TVD; 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 10:07 am, Sep 23, 2021 321-499 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.22 16:36:55 -08'00' Taylor Wellman (2143) X 10-404 DLB 09/23/2021 DSR-9/23/21BJM 9/27/21 dts 9/28/2021 JLC 9/28/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.28 11:21:03 -08'00' RBDMS HEW 9/28/2021 Well Prognosis Well: KBU 42-06Y Date: 09/22/2021 Well Name: KBU 42-06Y API Number: 50-133-20634-00-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: 9/30/21 Rig: E-line Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-089 First Call Engineer: Jake Flora (907) 777-8442 (O)(720)988-5375 (C) Second Call Engineer: Todd Sidoti (907) 777-8443 (O)(985)632-4113 (C) AFE Number: Current Bottom Hole Pressure: ~600 psi @ 7,824’ TVD (8,682’ MD) Max. Expected BHP: ~ 1200 psi @ 7,700’ TVD (Based on offset well max observed pressure) Max. Potential Surface Pressure ~ 1200 psi (Based on max BHP to surface) Well Status KBU 42-06Y is currently shut-in due to fill covering the perfs. Brief Well Summary KBU 42-06Y is a grassroots well drilled and completed in the Tyonek D in 2014 by Hilcorp. It was perf’d and produced in the D4B – which didn’t do great. It was then plugged back and the D3A was perforated coming online just over 11 MMCFD. In Feb. 2017, the well had decline off to about 4 MMCFD when the Tyonek D3B was added, doubling the rate – bringing it to over 8 MMCFD. The well declined off to about 605 MCFD @ 42 psi until 7/8/2021, when the Tyonek D2 was perforated adding about 60 MCFD. A couple of weeks later, a few upper Tyonek sands were added which sanded up the well. 42-06Y has cum’d 10.8 BCF TD – with a current expected EUR of 11 BCF. A recent sundry has been approved to use coil tubing to clean out the wellbore (Sundry 321- 456). It was discovered after this sundry’s approval that the main contributing factor to the sand production is the top set of perforations. The objective of this procedure is to isolate the top perforations with a patch prior to doing the coil tubing fill cleanout per approved sundry 321-456. tbg. x Minimum ID is 4.276”. Last tag @ 8,873 ’ KB w/ 2.5” x 10’ DD Bailer on 8/25/2021. Full of clay/mud. Procedure: 1. MIRU E-line, PT lubricator to 2500 psi. 2. Set permanent patch across the open perf interval at 8682’ – 8688’. 3. RD E-line. 4. MIRU coil tubing, perform fill cleanout per the approved sundry. Attachments Well Prognosis Well: KBU 42-06Y Date: 09/22/2021 1. Current Well Schematic 2. Proposed Well Schematic _____________________________________________________________________________________ Updated by CRR 9/8/2021 SCHEMATIC Kenai Gas Field Well: KBU 42-06Y PTD: 214-089 API: 50-133-20634-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor 109 / X-56 / Weld Surf 135' 10-3/4”Surface 45.5 /L-80 / BTC 9.950 Surf 1,595' 7-5/8"Intermediate 29.7 / L-80 / BTC 6.875 Surf 6,483' 5"Production 18 / L-80 / DWC/C-HT 4.276 Surf 10,892’ JEWELRY DETAIL No Depth Item 1 6,006’5” Swell Packer 2 9,425’RA Pup 3 9,631’RA Pup 4 10,175’CIBP capped w/ 5’ cmt (11/13/14) 5 10,199’RA Pup 6 10,270’CIBP capped w/cmt (11/4/14) 7 10,360’CIBP capped w/cmt (9/6/14) OPEN HOLE / CEMENT DETAIL 10-3/4”165BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"197BBL’s of cement in 9-7/8” Hole. TOC 1,575’ Calculated 5”145BBL’s of cement in 6-3/4” Hole. TOC 4,150’ Calculated. Per 8/14/14 SCMT: Free pipe above 3600’. Top solid cement at 5390’ MD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Pool Date Status UT 3B 8,682'8,688'7,824'7,830'6'Beluga/Upr_Ty 7/26/21 Open UT 4D 9,025'9,045'8,165’8,185’20'Beluga/Upr_Ty 7/26/21 Open TY_84_6C 9,357'9,376'8,498'8,517'19'Beluga/Upr_Ty 7/26/21 Open D-2 9,830’9,845’8,967’8,982’15’Ty Gas Pool #1 07/08/21 Open D-3A 10,083’10,101’9,134’9,152’18’Ty Gas Pool #1 02/07/17 Open D-3B 10,132’10,169’9,268’9,305’37’Ty Gas Pool #1 12/05/14 Open D-3C 10,178’10,198’9,314’9,334’20’Ty Gas Pool #1 11/04/14 Isolated – wet (11/13/2014) D-4 (D4B)10,296’10,313’9,431’9,448’17’Ty Gas Pool #1 09/07/14 Isolated (11/4/2014)10,313’10,333’9,448’9,468’20’Ty Gas Pool #1 09/07/14 D-5 (D4D) 10,372’10,380’9,507’9,515’8’Ty Gas Pool #1 09/02/14 Isolated (9/6/2014) tested tight , possibly wet 10,380’10,394’9,515’9,529’14’Ty Gas Pool #1 09/02/14 Fish: CIBP milled and pushed to bottom w/ WO Rig _____________________________________________________________________________________ Updated by JMF 9/22/2021 PROPOSED Kenai Gas Field Well: KBU 42-06Y PTD: 214-089 API: 50-133-20634-00-00 PBTD =10,175’ MD /9,311’ TVD 16”66 RKB: MSL =18.5’ 5” 3 4 10-00 3/4//”44 7-5/8”5 1 2 Bel/Upper Tyonek Pool D-4 & 5 TD =10,895’ MD /10,029’ TVD TOFTT @ 10,250’00 5 D-3C 6 7 D-3B D-3A D-2 Ty Gas Pool #1 UT 4D TY_84_6C UT 3B Top fill: 8868’ SLMD (8/25/21) 5” Perm. Patch ID: 3.500” ~8677’–8692’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor 109 / X-56 / Weld Surf 135' 10-3/4”Surface 45.5 /L-80 / BTC 9.950 Surf 1,595' 7-5/8"Intermediate 29.7 / L-80 / BTC 6.875 Surf 6,483' 5"Production 18 / L-80 / DWC/C-HT4.276 Surf 10,892’ JEWELRY DETAIL No Depth Item 1 6,006’5” Swell Packer 2 9,425’RA Pup 3 9,631’RA Pup 4 10,175’ CIBP capped w/ 5’ cmt (11/13/14) 5 10,199’RA Pup 6 10,270’ CIBP capped w/cmt (11/4/14) 7 10,360’CIBP capped w/cmt (9/6/14) OPEN HOLE / CEMENT DETAIL 10-3/4”165BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"197BBL’s of cement in 9-7/8” Hole. TOC 1,575’Calculated 5”145BBL’s of cement in 6-3/4” Hole. TOC 4,150’ Calculated. Per 8/14/14 SCMT: Free pipe above 3600’. Top solid cement at 5390’ MD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FTPool Date Status UT 3B 8,682' 8,688' 7,824' 7,830' 6'Beluga/Upr_Ty 7/26/21 Isolated (patch) UT 4D 9,025' 9,045' 8,165’ 8,185’ 20' Beluga/Upr_Ty 7/26/21 Open TY_84_6C 9,357' 9,376' 8,498' 8,517' 19'Beluga/Upr_Ty 7/26/21 Open D-2 9,830’ 9,845’ 8,967’ 8,982’ 15’ Ty Gas Pool #1 07/08/21 Open D-3A 10,083’10,101’9,134’9,152’18’Ty Gas Pool #1 02/07/17 Open D-3B 10,132’ 10,169’ 9,268’ 9,305’37’Ty Gas Pool #1 12/05/14 Open D-3C 10,178’ 10,198’ 9,314’ 9,334’ 20’ Ty Gas Pool #1 11/04/14 Isolated –wet (11/13/2014) D-4 (D4B)10,296’ 10,313’ 9,431’ 9,448’17’Ty Gas Pool #1 09/07/14 Isolated (11/4/2014)10,313’ 10,333’9,448’ 9,468’20’Ty Gas Pool #1 09/07/14 D-5 (D4D) 10,372’ 10,380’ 9,507’ 9,515’8’Ty Gas Pool #1 09/02/14 Isolated (9/6/2014) tested tight , possibly wet 10,380’ 10,394’ 9,515’ 9,529’ 14’ Ty Gas Pool #1 09/02/14 Fish: CIBP milled and pushed to bottom w/ WO Rig 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: ___CTU cleanout_____ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,895'See schematic Casing Collapse Structural Conductor Surface 2,470psi Intermediate 4,790psi Production 10,490psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Jake Flora Operations Manager Contact Email: Contact Phone: 777-8442 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 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 18, 2021 N/A 10,892' Perforation Depth MD (ft): 6,483' See Attached Schematic 10,892' 10,026'5" 16" 10-3/4" 135' 7-5/8"6,483' 1,595'5,210psi 135' 1,570' 5,801' 135' 1,595' N/A TVD Burst N/A 10,140psi MD 6,890psi Length Size CO 510B Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE A028142 214-089 50-133-20634-00-00 KBU 42-06Y Kenai Gas Field - Tyonek Gas Pool 1 COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic jake.flora@hilcorp.com 10,029'10,175'9,311'~1200psi See schematic Swell Pkr; N/A 6,006' MD / 5,387' TVD; 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 4:21 pm, Sep 08, 2021 321-456 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.08 10:15:49 -08'00' Taylor Wellman (2143) CT BOP test to 4000 psi. DLB 09/08/2021 /Beluga/Upper Tyonek Gas Pool DLB X 10-404 BJM 9/10/21 X DSR-9/8/21 dts 9/12/2021 JLC 9/13/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.13 10:14:36 -08'00' RBDMS HEW 9/13/2021 Well Prognosis Well: KBU 42-06Y Date: 09/07/2021 Well Name: KBU 42-06Y API Number: 50-133-20634-00-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: 9/18/21 Rig: Coil Tubing Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-089 First Call Engineer: Jake Flora (907) 777-8442 (O)(720)988-5375 (C) Second Call Engineer: Todd Sidoti (907) 777-8443 (O)(985)632-4113 (C) AFE Number: Current Bottom Hole Pressure: ~600 psi @ 7,824’ TVD (8,682’ MD) Max. Expected BHP: ~ 1200 psi @ 7,700’ TVD (Based on offset well max observed pressure) Max. Potential Surface Pressure ~ 1200 psi (Based on max BHP to surface) Well Status KBU 42-06Y is currently shut-in due to fill covering the perfs. Brief Well Summary KBU 42-06Y is a grassroots well drilled and completed in the Tyonek D in 2014 by Hilcorp. It was perf’d and produced in the D4B – which didn’t do great. It was then plugged back and the D3A was perforated coming online just over 11 MMCFD. In Feb. 2017, the well had decline off to about 4 MMCFD when the Tyonek D3B was added, doubling the rate – bringing it to over 8 MMCFD. The well declined off to about 605 MCFD @ 42 psi until 7/8/2021, when the Tyonek D2 was perforated adding about 60 MCFD. A couple of weeks later, a few upper Tyonek sands were added which sanded up the well. 42-06Y has cum’d 10.8 BCF TD – with a current expected EUR of 11 BCF. Objective The objective of this work is to clean the well out to PBTD with coil tbg and add the Upper Tyonek sands thru tbg. x Minimum ID is 4.276”. Last tag @ 8,873 ’ KB w/ 2.5” x 10’ DD Bailer on 8/25/2021. Full of clay/mud. Procedure: 1. MIRU Coiled Tubing, Provide AOGCC 24hrs notice. PT BOPE to 4,000 psi Hi 250 Low. 2. MU cleanout BHA, trip in to top of fill, clean out well to TD. 3. RU Nitrogen, blow well down trapping 1500 psi of pressure if possible. 4. RU E-line, PT lubricator to 2000 psi. 5. Perforate below sands from the bottom up: Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT MB 6 ±6,525' ±6,541' ±5,837' ±5,853' 16' MB 9 ±6,826' ±6,837' ±6,096' ±6,107' 11' LB1 ±6,863' ±6,879' ±6,127' ±6,143' 16' LB1B ±6,932' ±6,940' ±6,186' ±6,194' 8' LB1E ±7,098' ±7,106' ±6,328' ±6,336' 8' add the Upper Tyonek sands thru tbg. Well Prognosis Well: KBU 42-06Y Date: 09/07/2021 LB2E ±7,459' ±7,468' ±6,649' ±6,658' 9' LB3A ±7,535' ±7,549' ±6,720' ±6,734' 14' LB4B ±8,694' ±8,705' ±6,934' ±6,945' 11' LB4C ±7,832' ±7,841' ±6,999' ±7,008' 9' TY_72_8 ±8,142' ±8,174' ±7,299' ±7,331' 32' TY_73_1 ±8,186' ±8,195' ±7,340' ±7,349' 9' TY_73_2 ±8,237' ±8,243' ±7,390' ±7,396' 6' TY_75_8 ±8,466' ±8,483' ±7,612' ±7,629' 17' TY_75_8 ±8,491' ±8,498' ±7,635' ±7,642' 7' TY_76_7 ±8,556' ±8,574' ±7,700' ±7,718' 18' 6. Turn well over to production. 7. Within 30 days of first production: RU E-line, PT Lubricator, log spinner, pressure, temperature log from TD across all open perforations to satisfy the commingling agreement. Attachments 1. Current Well Schematic 2. Proposed Well Schematic 3. Coil Tubing BOP Diagram 4. Nitrogen SOP ?? _____________________________________________________________________________________ Updated by CRR 8/18/2021 SCHEMATIC Kenai Gas Field Well: KBU 42-06Y PTD: 214-089 API: 50-133-20634-00 PBTD = 10,175’ MD / 9,311’ TVD 16”66 RKB: MSL = 18.5’ 5” 3 4 10-00 3/4”44 7-5/8”5 1 2 Bel/Upper Tyonek Pool D-4 & 5 TD = 10,895’ MD / 10,029’ TVD TOFTT @ 10,250’00 5 D-3C 6 7 D-3B D-3A D-2 Ty Gas Pool #1 UT 4D TY_84_6C UT 3B Top fill: 8868’ MD (8/25/21) CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor 109 / X-56 / Weld Surf 135' 10-3/4”Surface 45.5 /L-80 / BTC 9.950 Surf 1,595' 7-5/8"Intermediate 29.7 / L-80 / BTC 6.875 Surf 6,483' 5"Production 18 / L-80 / DWC/C-HT4.276 Surf 10,892’ JEWELRY DETAIL No Depth Item 1 6,006’5” Swell Packer 2 9,425’RA Pup 3 9,631’RA Pup 4 10,175’ CIBP capped w/ 5’ cmt (11/13/14) 5 10,199’RA Pup 6 10,270’ CIBP capped w/cmt (11/4/14) 7 10,360’CIBP capped w/cmt (9/6/14) OPEN HOLE / CEMENT DETAIL 10-3/4”165BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"197BBL’s of cement in 9-7/8” Hole. TOC 1,575’Calculated 5”145BBL’s of cement in 6-3/4” Hole. TOC 4,150’ Calculated. Per 8/14/14 SCMT: Free pipe above 3600’. Top solid cement at 5390’ MD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FTPool Date Status UT 3B 8,682' 8,688' 7,824' 7,830' 6'Beluga/Upr_Ty 7/26/21 Open UT 4D 9,025' 9,045' 20'Beluga/Upr_Ty 7/26/21 Open TY_84_6C 9,357' 9,376' 8,498' 8,517' 19'Beluga/Upr_Ty 7/26/21 Open D-2 9,830’ 9,845’ 8,967’ 8,982’ 15’ Ty Gas Pool #1 07/08/21 Open D-3A 10,083’ 10,101’ 9,134’9,152’18’Ty Gas Pool #1 02/07/17 Open D-3B 10,132’ 10,169’ 9,268’ 9,305’37’Ty Gas Pool #1 12/05/14 Open D-3C 10,178’ 10,198’ 9,314’ 9,334’ 20’ Ty Gas Pool #1 11/04/14 Isolated –wet (11/13/2014) D-4 (D4B)10,296’ 10,313’ 9,431’ 9,448’17’Ty Gas Pool #1 09/07/14 Isolated (11/4/2014)10,313’ 10,333’9,448’ 9,468’20’Ty Gas Pool #1 09/07/14 D-5 (D4D) 10,372’ 10,380’ 9,507’ 9,515’8’Ty Gas Pool #1 09/02/14 Isolated (9/6/2014) tested tight , possibly wet 10,380’ 10,394’ 9,515’ 9,529’ 14’ Ty Gas Pool #1 09/02/14 Fish: CIBP milled and pushed to bottom w/ WO Rig _____________________________________________________________________________________ Updated by TRH 9/7/2021 PROPOSED SCHEMATIC Kenai Gas Field Well: KBU 42-06Y PTD: 214-089 API: 50-133-20634-00 PBTD = 10,175’ MD / 9,311’ TVD 16” RKB: MSL = 18.5’ 5” 3 4 10-3/4” 7-5/8” 1 2 Bel/Upper Tyonek Pool New Upper Tyonek / Beluga Perfs D-4 & 5 TD = 10,895’ MD / 10,029’ TVD TOF @ 10,250’ 5 D-3C 6 7 D-3B D-3A D-2 Ty Gas Pool #1 UT 4D TY_84_6C UT 3B CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor 109 / X-56 / Weld Surf 135' 10-3/4” Surface 45.5 /L-80 / BTC 9.950 Surf 1,595' 7-5/8" Intermediate 29.7 / L-80 / BTC 6.875 Surf 6,483' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 10,892’ JEWELRY DETAIL No Depth Item 1 6,006’ 5” Swell Packer 2 9,425’ RA Pup 3 9,631’ RA Pup 4 10,175’ CIBP capped w/ 5’ cmt (11/13/14) 5 10,199’ RA Pup 6 10,270’ CIBP capped w/cmt (11/4/14) 7 10,360’ CIBP capped w/cmt (9/6/14) OPEN HOLE / CEMENT DETAIL 10-3/4” 165BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 197BBL’s of cement in 9-7/8” Hole. TOC 1,575’ Calculated 5”145BBL’s of cement in 6-3/4” Hole. TOC 4,150’ Calculated. Per 8/14/14 SCMT: Free pipe above 3600’. Top solid cement at 5390’ MD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Pool Date Status MB 6 ±6,525' ±6,541' ±5,837' ±5,853' 16' Beluga/Upr_Ty TBD Proposed MB 9 ±6,826' ±6,837' ±6,096' ±6,107' 11' Beluga/Upr_Ty TBD Proposed LB1 ±6,863' ±6,879' ±6,127' ±6,143' 16' Beluga/Upr_Ty TBD Proposed LB1B ±6,932' ±6,940' ±6,186' ±6,194' 8' Beluga/Upr_Ty TBD Proposed LB1E ±7,098' ±7,106' ±6,328' ±6,336' 8' Beluga/Upr_Ty TBD Proposed LB2E ±7,459' ±7,468' ±6,649' ±6,658' 9' Beluga/Upr_Ty TBD Proposed LB3A ±7,535' ±7,549' ±6,720' ±6,734' 14' Beluga/Upr_Ty TBD Proposed LB4B ±8,694' ±8,705' ±6,934' ±6,945' 11' Beluga/Upr_Ty TBD Proposed LB4C ±7,832' ±7,841' ±6,999' ±7,008' 9' Beluga/Upr_Ty TBD Proposed TY_72_8 ±8,142' ±8,174' ±7,299' ±7,331' 32' Beluga/Upr_Ty TBD Proposed TY_73_1 ±8,186' ±8,195' ±7,340' ±7,349' 9' Beluga/Upr_Ty TBD Proposed TY_73_2 ±8,237' ±8,243' ±7,390' ±7,396' 6' Beluga/Upr_Ty TBD Proposed TY_75_8 ±8,466' ±8,483' ±7,612' ±7,629' 17' Beluga/Upr_Ty TBD Proposed TY_75_8 ±8,491' ±8,498' ±7,635' ±7,642' 7' Beluga/Upr_Ty TBD Proposed TY_76_7 ±8,556' ±8,574' ±7,700' ±7,718' 18' Beluga/Upr_Ty TBD Proposed UT 3B 8,682' 8,688' 7,824' 7,830' 6' Beluga/Upr_Ty 7/26/21 Open UT 4D 9,025' 9,045' 8,165’ 8,185’ 20' Beluga/Upr_Ty 7/26/21 Open TY_84_6C 9,357' 9,376' 8,498' 8,517' 19'Beluga/Upr_Ty 7/26/21 Open D-2 9,830’ 9,845’ 8,967’ 8,982’ 15’ Ty Gas Pool #1 07/08/21 Open D-3A 10,083’ 10,101’ 9,134’ 9,152’ 18’ Ty Gas Pool #1 02/07/17 Open D-3B 10,132’ 10,169’ 9,268’ 9,305’ 37’ Ty Gas Pool #1 12/05/14 Open D-3C 10,178’10,198’9,314’9,334’20’Ty Gas Pool #1 11/04/14 Isolated – wet (11/13/2014) D-4 (D4B)10,296’10,313’9,431’9,448’17’Ty Gas Pool #1 09/07/14 Isolated (11/4/2014)10,313’10,333’9,448’9,468’20’Ty Gas Pool #1 09/07/14 D-5 (D4D) 10,372’10,380’9,507’9,515’8’Ty Gas Pool #1 09/02/14 Isolated (9/6/2014) tested tight , possibly wet 10,380’10,394’9,515’9,529’14’Ty Gas Pool #1 09/02/14 ?? 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: _____ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,895 feet See Schematic feet true vertical 10,029 feet See Schematic feet Effective Depth measured 10,175 feet 6,006 feet true vertical 9,311 feet 5,387 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 6,006' MD 5,387' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ryan Rupert Authorized Title:Operations Manager Contact Email: Contact Phone:777-8503 WINJ WAG 663 Water-Bbl MD 135' 1,595' 0 Oil-Bbl measured true vertical Packer 5"10,892' 5,801' 10,026' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field - Tyonek Gas Pool 1 & Beluga/Upper Tyonek PoolN/A measured TVD Tubing Pressure 4314 Kenai Beluga Unit (KBU) 42-06Y N/A FEE A028142 6,483' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-089 50-133-20634-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-349 43 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 667 0 Representative Daily Average Production or Injection Data 135' 1,595' 6,483' 10,892' Conductor Surface Intermediate Production 10,490psi Casing Structural 16" 10-3/4" 7-5/8" Length 6,890psi 5,210psi Collapse 2,470psi 4,790psi ryan.rupert@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 10,140psi 135' 1,570' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 4:21 pm, Sep 08, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.08 11:36:29 -08'00' Taylor Wellman (2143) Perforate New Pool BJM 10/28/21 RBDMS HEW 9/10/2021 DSR-9/8/21 SFD 9/9/2021 Rig Start Date End Date EL / SL 7/26/21 8/25/21 08/04/2021 - Wednesday Sign in. Mobe to location. PTW and JSA. Spot equipment rig up lubricator. PT to 250 psi low and 2,500 psi high, TP-1,005 psi. RIH w/2.75" wt and 1-11/16" GPT tool. See Fluid level at 6,713' but pressure didn't show fluid but WHU tool did. POOH and find bottom cage filled with soapy muddy sand. Clean CTF out and put back on. RIH w/2.75" weight, 1-11/16" GPT tool and sat down at 7,640' correlated. FL - 7,352'. Tried getting past at 180 fpm, 50 fpm, 200' fpm and 220' pm. at 7,640'. No go and not very sticky picking up. POOH. Found muddy sandy grey stuff in bottom of GPT spinner cage. Wait on slickline tools from shop to run on E-line. RIH W/ 3" x 8' pump bailer and see FL at 7,352' and tagged at 7,640'. Worked pump bailer for about 1 hour. Might have made 3' to 4' of hole. POOH. Full of moist gray sandy mud. Rig lubricaator off well. Halliburton will bring slickline unit out in morning. 08/05/2021 - Thursday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 42-06Y 50-133-20634-00-00 214-089 07/26/2021 - Monday Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. Wait on tri-plex on another job. PT to 250 psi low and 2,500 psi high. Break off lubricator and arm and put perf gun on line. Quick test to 2,500 psi. RIH w/ 2-7/8" x 19' HC gas gun, 6 spf, 60 deg and tie into OHL. Run correlation and send to town. Told to ad 4'. Added 4' and spotted gun from 9,357' to 9,376' w/41 psi/600K. After 5 min - 41 psi/620K, 10 min - 43 psi/630K and 15 min - 42 psi 620K. POOH. All shots fired has a little sand and fluid in bull pug. Not much of either. RIH w/ 2-7/8" x 20' HC gas gun, 6 spf, 60 deg and tie into OHL. Run correlation and send to town. Get ok to perf from 9,025' to 9,045' w/41 psi/606K. Spotted and fired gun. After 5 min - 40 psi/614K, 10 min - 42 psi/605K and 15 min 640K. POOH. All shots fired/gun was a little wet. RIH w/ 2-7/8" x 6' HC gas gun, 6 spf, 60 deg and tie into OHL. Run correlation and send to town. Get ok to perf from 8,682' to 8,688'. Spot Gun and fire w/40.5 psi/608K, 5 min - 41.2 psi/608K 10 min - 40.4 psi/586K and 15 min - 43.9 psi/614K POOH. All shots fired/gun little wet. Rig down lubricator and equipment and turn well over to field. Arrive @ gas plant. Sign PTW & JSA. Continue to location. RU slickline. PT 250 psi low and 2,500 psi high. RU SL unit. TP - 790 psi. RIH w/ 10' 1-1/2" weight bar / 1¾" jars / 1-1/2" long spangs / 3" stroke bailer. Tag at 7,654.1'. Work bailer. Anchor point for bottom shelve not stable. POOH. Line covered in well debris and corrosion. Bailer full of grey sandy mud. Lay down lube. Move bottom sheave. Re-tie/restuff stuffing box. Service bailer. Clean line. Pickup lube. RIH with same tools and cant pass 141'. POOH heavy. Pump 90 gal of diesel in hole w/tri-plex. RIH w/ 10' 1-1/2" weight bar / 1¾" jars / 1-1/2" long spangs / 3" stroke bailer and tag at 7,654.' Work tools POOH. Got 1/2 bailer soft sand. RIH w/ 10' 1-1/2" weight bar / 1¾" jars / 1-1/2" long spangs / 2.5" stroke bailer. Tag at 7,658'. Work bailer 30 min and POOH. Bailer 1/2 full soft sand. RIH w/ 10' 1-1/2" weight bar / 1¾" jars / 1-1/2" long spangs / 3" stroke bailer. Tag at 7,658'. Work tools for 10 min. Call town and was told to shut it down. POOH . Bailer full of muddy gray sand and fluid. Rig down equipment and lubricator. Clean up work area. Get ok to perf from 9,025' to 9,045' w All shots fired/gun little wet. spotted gun from 9,357' to 9,376' w/41 psi/600K. After 5 min - 41 psi/620K,10 min - 43 psi/630K and 15 min - 42 psi 620K. POOH. All shots fired h All shots fired/gun was a little wet. Get ok to perf from 8,682' to 8,688'. Rig Start Date End Date EL / SL 7/26/21 8/25/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 42-06Y 50-133-20634-00-00 214-089 08/22/2021 - Sunday RIG UP W/L - REHEAD - PT LUB. RIH W/ 3.5" X 10' DD BAILER 6,175'KB - IDENTIFY FLUID LEVEL - CONTINUE IN HOLE TO 6,824'KB. WT TO 6,826'KB - POOH - OOH W/ SOUPY MUD - NO SOLIDS. RIH W/ 3.5" SPIRAL PRONG WIRE GRAB (AS DIGGER TOOL) TO 6,824'KB WT TO 6,825'KB - POOH. RECONFIGURE TOOLSTRING ADD 5' STEM ABOVE SPANGS (MORE FORCE TO BEAT DOWN). RIH W/ 40" SPEAR GRAB (DIGGER) TO 6,822'KB WT TO 6,854'KB - POOH. RIH W/ 2.5" X 6' DD BAILER TO 6,850'KB. WT TO 6,852'KB POOH - OOH W/ THICK MUD AND SAND. RIH W/ SAME TO 6,852'KB WT TO 6,854'KB - POOH - OOH W/ THICK MUD AND SAND. RIH W/ SPEAR TO 6,854'KB WT TO 6,860'KB FALL TO 7,193'KB WT FALL TO 7,448'KB WT FALL TO 7,650'KB WT TO 7,670'KB FALL TO 8,200'KB WT FALL TO 8,648'KB WT - GAIN NO HOLE - STICKY. 1,500 LBS PICK UP WEIGHT - POOH - WORKING THROUGH TIGHT SPOTS. RIH W/ 2.5" X 6' DD BAILER TO 7,100'KB WT FALL TO 7,548'KB WT FALL TO 7,650'KB WT FALL TO 8,200'. WT FALL TO 8,648'KB WT TO 8,652'KB (STICKY) POOH - OOH W/ LAY DOW LUB - SECURE WELL FOR NIGHT - REHEAD AND PREP FOR MORNING OPERATIONS. DEPART FIELD FOR PWL SHOP. 08/23/2021 - Monday RIG UP W/L - 7" CONNECTION GETS CROSS THREADED AT TREE - LAY DOWN LUB TO WORK TO FREE CONNECTION - GET FREE - FINISH RIGGING UP. RIH W/ 3.5" X 10 ' DD BAILER TO 6,900'KB - IDENTIFY FLUID - CONT IN HOLE TO 7,585'KB TO 7,595'KB. FALL TO 7,638'KB WT TO 7,650'KB - POOH - OOH W/ FULL MUD. RIH W/ 2.5" X 6' DD BAILER TO 7,650'KB WT TO 7,663'KB - POOH - OOH MUD. RIH W/ SPEAR TO 7,650'KB SET DOWN 8,650'KB WT TO 8,656'KB - POOH. RIH W/ 2.5" X 6' DD BAILER TO 7,650'KB. WT FALL TO 8,650'KB WT TO 8,660'KB - POOH - OOH W/ THICK MUD AND SAND. RIH W/ SAME TO 8,658'KB WT TO 8,668'KB FALL TO 8,702'KB PICK UP TO 8500'KB GO BACK DOWN TO 8,660'KB WT GAIN NO HOLE - POOH - OOH W/ FULL BAILER THICK MUD. RIH W/ SAME TO 8,662'KB WT TO 8,668'KB FALL TO 8,702'KB WT TO 8,710'KB FALL TO 8,800'KB WT TO 8,802'KB LOSE SPANGS - POOH - OOH W/ FULL MUD. RIG DOWN W/L - SECURE WELL. Rig Start Date End Date EL / SL 7/26/21 8/25/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 42-06Y 50-133-20634-00-00 214-089 08/24/2021 - Tuesday RIG UP W/L. RIH W/ 2.5" X 6' DD BAILER TO 8660'KB WT TO 8665'KB FALL TO 8760'KB WT TO 8788'KB - POOH. OOH W/ FULL BAILER MUD. RIH W/ SPEAR TO 8728'KB WT TO 8750'KB FALL TO 8800'KB WT TO 8806'KB - POOH. RIH W/ 2.5" X 6' DD BAILER TO 8728'KB WT TO 8740'KB FALL TO 8800'KB WT TO 8806'KB. POOH. OOH W/ FULL BAILER MUD/CLAY. RIH W/ SAME TO 8790'KB WT TO 8806'KB FALL TO 8843'KB WT TO 8850'KB - POOH - OOH W/ CLAY. RIH W/ 2.5" X 10' DD BAILER 8747'KB WT TO 8750'KB FALL TO 8806'KB WT TO 8820'KB FAL TO 8850'KB WT TO 8860'KB - POOH - OOH W/ FULL BAILER THICK HEAVY CLAY. RIH W/ SAME TO 8790'KB WT TO 8806'KB FALL TO 8843'KB WT TO 8858'KB - POOH - OOH W/ CLAY. RIH W/ SPEAR TO 8806'KB WT TO 8810'KB - FALL TO 8840'KB WT TO 8858'KB - POOH - OOH W/ SPEAR COVERED IN CLAY. LAY DOWN LUB - SECURE WELL - REHEAD - PREP FOR MORNING OPERATIONS. 08/25/2021 - Wednesday ON LOCATION - TGSM - JSA - PERMIT. RIG UP W/L. RIH W/ 2.5" X 10' DD BAILER TO 8,845'KB WT TO 8,858'KB - POOH - OOH W/ FULL BAILER OF CLAY. RIH W/ SAME TO 8,858'KB WT TO 8,870'KB - POOH - FULL BAILER CLAY. RIH W/ SAME TO 8,860'KB WT TO 8,868'KB. RIH W/ SAME TO 8,862'KB WT TO 8,873'KB - POOH - OOH W/ FULL BAILER OF CLAY. RIH W/ SAME TO 8,864'KB WT TO 8,870'KB - POOH - OOH W/ FULL BAILER OF CLAY/MUD. RIH W/ SPEAR TO 8867'KB WT TO 8,871'KB WT - LOSE HOLE - 8,865'KB - POOH - OOH W/ TOOL COVERED IN MUD. RIH W/ 2.5" X 10' DD BAILER TO 8,863'KB WT TO 8,868'KB - POOH - OOH W/ FULL CLAY. RIG DOWN W/L - CLEAN AREA. _____________________________________________________________________________________ Updated by CRR 9/8/2021 SCHEMATIC Kenai Gas Field Well: KBU 42-06Y PTD: 214-089 API: 50-133-20634-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor 109 / X-56 / Weld Surf 135' 10-3/4” Surface 45.5 /L-80 / BTC 9.950 Surf 1,595' 7-5/8" Intermediate 29.7 / L-80 / BTC 6.875 Surf 6,483' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 10,892’ JEWELRY DETAIL No Depth Item 1 6,006’ 5” Swell Packer 2 9,425’ RA Pup 3 9,631’ RA Pup 4 10,175’ CIBP capped w/ 5’ cmt (11/13/14) 5 10,199’ RA Pup 6 10,270’ CIBP capped w/cmt (11/4/14) 7 10,360’ CIBP capped w/cmt (9/6/14) OPEN HOLE / CEMENT DETAIL 10-3/4” 165BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 197BBL’s of cement in 9-7/8” Hole. TOC 1,575’ Calculated 5” 145BBL’s of cement in 6-3/4” Hole. TOC 4,150’ Calculated. Per 8/14/14 SCMT: Free pipe above 3600’. Top solid cement at 5390’ MD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Pool Date Status UT 3B 8,682' 8,688' 7,824' 7,830' 6' Beluga/Upr_Ty 7/26/21 Open UT 4D 9,025' 9,045' 8,165’ 8,185’ 20' Beluga/Upr_Ty 7/26/21 Open TY_84_6C 9,357' 9,376' 8,498' 8,517' 19' Beluga/Upr_Ty 7/26/21 Open D-2 9,830’ 9,845’ 8,967’ 8,982’ 15’ Ty Gas Pool #1 07/08/21 Open D-3A 10,083’ 10,101’ 9,134’ 9,152’ 18’ Ty Gas Pool #1 02/07/17 Open D-3B 10,132’ 10,169’ 9,268’ 9,305’ 37’ Ty Gas Pool #1 12/05/14 Open D-3C 10,178’ 10,198’ 9,314’ 9,334’ 20’ Ty Gas Pool #1 11/04/14 Isolated – wet (11/13/2014) D-4 (D4B) 10,296’ 10,313’ 9,431’ 9,448’ 17’ Ty Gas Pool #1 09/07/14 Isolated (11/4/2014) 10,313’ 10,333’ 9,448’ 9,468’ 20’ Ty Gas Pool #1 09/07/14 D-5 (D4D) 10,372’ 10,380’ 9,507’ 9,515’ 8’ Ty Gas Pool #1 09/02/14 Isolated (9/6/2014) tested tight , possibly wet 10,380’ 10,394’ 9,515’ 9,529’ 14’ Ty Gas Pool #1 09/02/14 Fish: CIBP milled and pushed to bottom w/ WO Rig UT 3B 8,682' 8,688'7,824'7,830'6'Beluga/Upr_Ty 7/26/21 Open UT 4D 9,025' 9,045'8,165’8,185’20' Beluga/Upr_Ty 7/26/21 Open Y_84_6CTY 9,357' 9,376'8,498'8,517'19'Beluga/Upr_Ty 7/26/21 Open 1 Donna Ambruz From:Roby, David S (CED) <dave.roby@alaska.gov> Sent:Friday, August 20, 2021 6:16 PM To:McLellan, Bryan J (CED) Cc:Donna Ambruz; Ryan Rupert; Benjamin Siks; Trudi Hallett; Chad Johnson; Taylor Wellman; Josh Allely - (C) Subject:[EXTERNAL] RE: KBU 42-06Y (PTD#214_089) Ryan, Your proposal to delay the initial production log required under CO 510B for this well is hereby approved. There’s no value in running a production log in a well incapable of flowing due to fill covering the perfs. If you are able to clean out the fill and get the well flowing then a production log will be required. The production log should be run within the first 30 days after establishing flow from the well, but not until production has stabilized. If you have any questions please let me know. Regards, Dave Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793-1232 From: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Sent: Friday, August 20, 2021 6:00 PM To: Roby, David S (CED) <dave.roby@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com>; Benjamin Siks <bsiks@hilcorp.com>; Trudi Hallett <thallett@hilcorp.com>; Chad Johnson <chjohnson@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com>; Josh Allely - (C) <Josh.Allely@hilcorp.com> Subject: RE: KBU 42-06Y (PTD#214_089) Dave, As discussed, can you respond to Ryan and all on the cc list? 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: Friday, August 20, 2021 12:49 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Benjamin Siks <bsiks@hilcorp.com>; Trudi Hallett <thallett@hilcorp.com>; Chad Johnson <chjohnson@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com>; Josh Allely - (C) 2 <Josh.Allely@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: RE: KBU 42-06Y (PTD#214_089) Bryan- Per our conversation, Hilcorp will not be able to obtain the production log per CO 510A on well KBU 42-06Y (PTD #214- 089). After shooting the Beluga/Upper Tyonek pool per approved sundry #321-349 on 7/26/21, fill came in and is now covering all perf intervals. The well will not flow. If removing the fill is successful, Hilcorp will bring the well online and run a production log across the 2 comingled pools within 30 days of bringing the well online. Please confirm this is acceptable. Thank you, Ryan Rupert Kenai Ops Engineer (13146) 907-301-1736 (Cell) 907-777-8503 (Office) From: Ryan Rupert Sent: Wednesday, August 18, 2021 10:53 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: KBU 42-06Y (PTD#214_089) Bryan- Please see attached for a current schematic of KBU 42-06Y. It’s open in 2 pools currently (allowed under CO 510A rule#5), but fill is currently blocking our ability to get a production log per the CO. Please give me a ring to discuss options. Thanks, Ryan Rupert Kenai Ops Engineer (13146) 907-301-1736 (Cell) 907-777-8503 (Office) 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, 3 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. David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 08/03/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL KBU 42-06Y (PTD 215-044) FTP Folder Contents: Log Print Files and LAS Data Files: Please include current contact information if different from above. Received By: 08/03/2021 37' (6HW By Abby Bell at 2:03 pm, Aug 03, 2021 David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 08/03/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL KBU 42-06Y (PTD 214-089) FTP Folder Contents: Log Print Files and LAS Data Files: Please include current contact information if different from above. Received By: 08/03/2021 37' (6HW By Abby Bell at 11:43 am, Aug 03, 2021 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: _____Patch / N2______ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,895'See schematic Casing Collapse Structural Conductor Surface 2,470psi Intermediate 4,790psi Production 10,490psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ryan Rupert Operations Manager Contact Email: Contact Phone: 777-8503 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng ryan.rupert @hilcorp.com 10,029'10,175'9,311'~1200psi See schematic Swell Pkr; N/A 6,006' MD / 5,387' TVD; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE A028142 214-089 50-133-20634-00-00 KBU 42-06Y Kenai Gas Field - Tyonek Gas Pool 1 Length Size CO 510B Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY N/A TVD Burst N/A 10,140psi MD 6,890psi 5,210psi 135' 1,570' 5,801' 135' 1,595' 10,026'5" 16" 10-3/4" 135' 7-5/8"6,483' 1,595' 10,892' Perforation Depth MD (ft): 6,483' See Attached Schematic 10,892' 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: July 28, 2021 N/A Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:54 am, Jul 13, 2021 321-349 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.07.12 22:42:26 -08'00' Taylor Wellman (2143) DSR-7/13/21BJM 7/21/21 DLB 07/13/2021 10-404X dts 7/22/2021 JLC 7/22/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.22 10:38:17 -08'00' RBDMS HEW 7/22/2021 Well Prognosis Well: KBU 42-06Y Date: 7/12/2021 Well Name:KBU 42-06Y API Number:50-113-20634-00-00 Current Status:Gas Producer Leg:N/A Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:214-089 First Call Engineer:Ryan Rupert (907) 777-8503 (O)(907) 301-1736 (C) Second Call Engineer:Ted Kramer (907) 777-8420 (O)(985) 867-0665 (C) Max. Expected BHP:~ 1200 psi @ 7,635’ TVD (Based on max offset well observed pressure) Max. Potential Surface Pressure ~ 1200 psi (Based on max BHP to surface) Well Summary KBU 42-06Y is a steady Tyonek Gas Pool #1 producer. It flows at 700mcfd and 15 bwpd. Given the opportunity uphole in the Beluga/Upper Tyonek Pool, additional perforations are proposed below. CO 510B Rule #5 allows comingling of the Beluga/Upper Tyonek Pool, Tyonek Pool #1, and the Kenai Deep Tyonek Pools, as long as certain post-perf production logging requirements are met. This job will comingle the existing Tyonek Gas Pool #1 perfs with proposed perfs in the Beluga/Upper Tyonek Pool. The goal of this project is to perforate uphole sands in the Beluga/Upper Tyonek Pool, to add production to the well Notes Regarding Wellbore Condition x Min ID = 4.276” (5” tubing/liner ID) x Max Inclination = 33 degrees at 3152’ MD x Drifts o 7/8/21: EL shot 15’ perfs with a 2-7/8” x 15’ gun assembly with bottom perf at 9845’ MD. Tagged bottom at 10159’ ELMD with spent gun after firing. o 3/24/17: SLB PLT run. 1-11/16” x 39’ BHA. Tagged bottom at 10,170’ ELMD o 2/18/17: After 11 days of fishing, all wire and BHA recovered. A 3.75” magnet drift made it to 10,167’ SLMD and tagged after all fish/wire recovered. o 2/7/17: EL shot 18’ of perfs down to 10,101’ MD with a 2-7/8” gun. Well was flowing 3.4MM at 320psi FTP. Appears line/gun jumped upward and got balled up. Ended up parting wire and leaving ~200’ of wire downhole Nitrogen Risk x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) x Ensure all crews are aware of stop work authority Min ID = 4.276” (5” tubing/liner ID) x Max Inclination = 33 degrees at 3152’ MD x Drifts 7/8/21: EL shot 15’ perfs with a 2-7/8” x 15’ gun assembly with bottom perf at 9845’ MD.o Tagged bottom at 10159’ ELMD with spent gun after firing. 3/24/17: SLB PLT run. 1-11/16” x 39’ BHA. Tagged bottom at 10,170’ ELMDo 2/18/17: After 11 days of fishing, all wire and BHA recovered. A 3.75” magnet drift made it too 10,167’ SLMD and tagged after all fish/wire recovered. 2/7/17: EL shot 18’ of perfs down to 10,101’ MD with a 2-7/8” gun. Well was flowing 3.4MMo at 320psi FTP. Appears line/gun jumped upward and got balled up. Ended CO 510B Rule #5 allows comingling of the Beluga/Upper Tyonek Pool, Tyonek Pool #1, and the Kenai Deep Tyonek Pools, as long as certain DLB 7/13/21post-perf production logging requirements are met. Well Prognosis Well: KBU 42-06Y Date: 7/12/2021 E-Line Perf 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2,500 psi High. 3. Consult with OE to determine if Nitrogen is needed to pressure up wellbore 4. RU Nitrogen Truck 5. Pressure up wellbore per OE 6. Rig up perf gun (Likely 2-7/8” 4-6 spf) 7. RIH and perforate the sands listed in the table below, per Geo/RE. Sand Perforation Top (MD) Perforation Bottom (MD) Perforation Top (TVD) Perforation Bottom (TVD) Total Footage (MD) TY_72_8 ±8,142'±8,174'±7,299'±7,331'32' TY_73_1 ±8,186'±8,195'±7,340'±7,349'9' TY_73_2 ±8,237'±8,243'±7,390'±7,396'6' TY_75_8 ±8,466'±8,483'±7,612'±7,629'17' TY_75_8 ±8,491'±8,498'±7,635'±7,642'7' TY_76_7 ±8,556'±8,574'±7,700'±7,718'18' UT 3B ±8,682'±8,688'±7,824'±7,830'6' UT 4D ±9,004'±9,051'±8,144'±8,191'47' TY_84_6C ±9,357'±9,376'±8,498'±8,517'19' Consult with OE for what WHP’s to use. May be shot while flowing Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a.Use Gamma/CCL to correlate. b. Record initial and 5/10/15 minute tubing pressures after firing c. Consult with RE/Geo between each perf interval: i. Trudi Hallett (RE): 301-6657 ii. Ben Siks (Geo): 229-0865 d. Above perfs will be shot in the Beluga/Upper Tyonek Pool. This comingling with currently open Tyonek Pool #1 is covered by CO 510B 8. RD E-Line Unit and turn well over to production. Well Prognosis Well: KBU 42-06Y Date: 7/12/2021 SL/EL Production log: Must be run within 30 days of commencement of comingled production, after well has stabilized per CO 510B 1. RU EL/SL and PT lubricator to 250 psi low / 2,500 psi high 2. RIH with PLT logging tool 3. Acquire dynamic passed and stop counts per OE (dependent on what’s shot) 4. Confirm good data, then RDMO EL/SL Contingency EL Plug or Patch 1. MIRU E-line, PT lubricator to 250 psi low / 2,500 psi high 2. RIH W/ GPT tool and find fluid level 3. RU Nitrogen Truck a. Push water back into formation b. Use GPT tool to confirm water level is below interval to perf c. Consult OE for pressure to leave on well for perforating 4. Once fluid level is below interval to isolate, MU 5” patch or plug 5. RIH and set plug or patch per OE. a. IF the entirety of the Tyonek Pool #1 is plugged off, 25’ of cement will need to be dump bailed on top of the plug b. Only a plug between the two pools would require cement. 6. RD E-Line Unit and turn well over to production. Attachments: 1. Current schematic 2. Proposed Schematic 3. Standard Well procedure – N2 Operations RIH with PLT logging tool _____________________________________________________________________________________ Updated by DMA 07-12-21 SCHEMATIC Kenai Gas Field Well: KBU 42-06Y PTD: 214-089 API: 50-133-20634-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor 109 / X-56 / Weld Surf 135' 10-3/4” Surface 45.5 /L-80 / BTC 9.950 Surf 1,595' 7-5/8" Intermediate 29.7 / L-80 / BTC 6.875 Surf 6,483' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 10,892’ JEWELRY DETAIL No Depth Item 1 6,006’ 5” Swell Packer 2 9,425’ RA Pup 3 9,631’ RA Pup 4 10,175’ CIBP capped w/ 5’ cmt (11/13/14) 5 10,199’ RA Pup 6 10,270’ CIBP capped w/cmt (11/4/14) 7 10,360’ CIBP capped w/cmt (9/6/14) OPEN HOLE / CEMENT DETAIL 10-3/4” 165BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 197BBL’s of cement in 9-7/8” Hole. TOC 1,575’ Calculated 5” 145BBL’s of cement in 6-3/4” Hole. TOC 4,150’ Calculated. Per 8/14/14 SCMT: Free pipe above 3600’. Top solid cement at 5390’ MD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Pool Date Status D-2 9,830’ 9,845’ 8,967’ 8,982’ 15’ Ty Gas Pool #1 07/08/21 Open D-3A 10,083’ 10,101’ 9,134’ 9,152’ 18’ Ty Gas Pool #1 02/07/17 Open D-3B 10,132’ 10,169’ 9,268’ 9,305’ 37’ Ty Gas Pool #1 12/05/14 Open D-3C 10,178’ 10,198’ 9,314’ 9,334’ 20’ Ty Gas Pool #1 11/04/14 Isolated – wet (11/13/2014) D-4 (D4B) 10,296’ 10,313’ 9,431’ 9,448’ 17’ Ty Gas Pool #1 09/07/14 Isolated (11/4/2014) 10,313’ 10,333’ 9,448’ 9,468’ 20’ Ty Gas Pool #1 09/07/14 D-5 (D4D) 10,372’ 10,380’ 9,507’ 9,515’ 8’ Ty Gas Pool #1 09/02/14 Isolated (9/6/2014) tested tight , possibly wet 10,380’ 10,394’ 9,515’ 9,529’ 14’ Ty Gas Pool #1 09/02/14 Fish: CIBP milled and pushed to bottom w/ WO Rig _____________________________________________________________________________________ Updated by CRR 7/12/2021 PROPOSED SCHEMATIC Kenai Gas Field Well: KBU 42-06Y PTD: 214-089 API: 50-133-20634-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor 109 / X-56 / Weld Surf 135' 10-3/4”Surface 45.5 /L-80 / BTC 9.950 Surf 1,595' 7-5/8"Intermediate 29.7 / L-80 / BTC 6.875 Surf 6,483' 5"Production 18 / L-80 / DWC/C-HT 4.276 Surf 10,892’ JEWELRY DETAIL No Depth Item 1 6,006’5” Swell Packer 2 9,425’RA Pup 3 9,631’RA Pup 4 10,175’CIBP capped w/ 5’ cmt (11/13/14) 5 10,199’RA Pup 6 10,270’CIBP capped w/cmt (11/4/14) 7 10,360’CIBP capped w/cmt (9/6/14) OPEN HOLE / CEMENT DETAIL 10-3/4”165BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"197BBL’s of cement in 9-7/8” Hole. TOC 1,575’ Calculated 5”145BBL’s of cement in 6-3/4” Hole. TOC 4,150’ Calculated. Per 8/14/14 SCMT: Free pipe above 3600’. Top solid cement at 5390’ MD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Pool Date Status TY_72_8 ±8,142'±8,174'±7,299'±7,331'32'Beluga/Upr_Ty TBD Proposed TY_73_1 ±8,186'±8,195'±7,340'±7,349'9'Beluga/Upr_Ty TBD Proposed TY_73_2 ±8,237'±8,243'±7,390'±7,396'6'Beluga/Upr_Ty TBD Proposed TY_75_8 ±8,466'±8,483'±7,612'±7,629'17'Beluga/Upr_Ty TBD Proposed TY_75_8 ±8,491'±8,498'±7,635'±7,642'7'Beluga/Upr_Ty TBD Proposed TY_76_7 ±8,556'±8,574'±7,700'±7,718'18'Beluga/Upr_Ty TBD Proposed UT 3B ±8,682'±8,688'±7,824'±7,830'6'Beluga/Upr_Ty TBD Proposed UT 4D ±9,004'±9,051'±8,144'±8,191'47'Beluga/Upr_Ty TBD Proposed TY_84_6C ±9,357'±9,376'±8,498'±8,517'19'Beluga/Upr_Ty TBD Proposed D-2 9,830’9,845’8,967’8,982’15’Ty Gas Pool #1 07/08/21 Open D-3A 10,083’10,101’9,134’9,152’18’Ty Gas Pool #1 02/07/17 Open D-3B 10,132’10,169’9,268’9,305’37’Ty Gas Pool #1 12/05/14 Open D-3C 10,178’10,198’9,314’9,334’20’Ty Gas Pool #1 11/04/14 Isolated – wet (11/13/2014) D-4 (D4B)10,296’10,313’9,431’9,448’17’Ty Gas Pool #1 09/07/14 Isolated (11/4/2014)10,313’10,333’9,448’9,468’20’Ty Gas Pool #1 09/07/14 D-5 (D4D) 10,372’10,380’9,507’9,515’8’Ty Gas Pool #1 09/02/14 Isolated (9/6/2014) tested tight , possibly wet 10,380’10,394’9,515’9,529’14’Ty Gas Pool #1 09/02/14 Fish: CIBP milled and pushed to bottom w/ WO Rig 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: ________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,895 feet See Schematic feet true vertical 10,029 feet See Schematic feet Effective Depth measured 10,175 feet 6,006 feet true vertical 9,311 feet 5,387 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 6,006' MD 5,387' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ryan Rupert Authorized Title:Operations Manager Contact Email: Contact Phone:777-8503 ryan.rupert@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 10,140psi 135' 1,570' 6,890psi 5,210psi Collapse 2,470psi 4,790psi 10,490psi Casing Structural 16" 10-3/4" 7-5/8" Length 135' 1,595' 6,483' 10,892' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 667 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-333 43 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 214-089 50-133-20634-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 4314 Kenai Beluga Unit (KBU) 42-06Y N/A FEE A028142 6,483' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field - Tyonek Gas Pool 1N/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 5"10,892' 5,801' 10,026' WINJ WAG 663 Water-Bbl MD 135' 1,595' 0 t Fra O 6. A G L PG , R _ Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:21 am, Jul 13, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.07.12 22:57:01 -08'00' Taylor Wellman (2143) DSR-7/13/21 RBDMS HEW 7/14/2021 BJM 10/12/21 SFD 7/16/2021 Rig Start Date End Date E-Line 7/8/21 7/8/21 07/08/2021 - Thursday Mobe from KU 11-07X . PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi and 2500 psi high. Well flowing. RIH w/ 2-7/8" x 20' spent HC perf gun as a drift and tag bottom at 10,166' uncorrelated. POOH. Did not have any trouble. RIH w/ 2-7/8" x 15' HC, 6 spf, 60 deg phase gas perf gun and tie into last log sent from town. Run correlation log and send to town. Get ok to perf from 9,830' to 9,845' w/40 psi/680K. Spot and fire gun. Wait a few minutes and go down and tag bottom at 10,159'. After 5 min- 41 psi/620K, 10 min - 40 psi/614K and 15 min - 39 psi/590K. POOH. All shots fired/gun wet. Rig down lubricator and secure well. Turn well back to field and finish rigging equipment down. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 42-06Y 50-133-20634-00-00 214-089 perf from 9,830' to 9,845' w/40 psi/680K. Spot and fire gun. W _____________________________________________________________________________________ Updated by DMA 07-12-21 SCHEMATIC Kenai Gas Field Well: KBU 42-06Y PTD: 214-089 API: 50-133-20634-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor 109 / X-56 / Weld Surf 135' 10-3/4” Surface 45.5 /L-80 / BTC 9.950 Surf 1,595' 7-5/8" Intermediate 29.7 / L-80 / BTC 6.875 Surf 6,483' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 10,892’ JEWELRY DETAIL No Depth Item 1 6,006’ 5” Swell Packer 2 9,425’ RA Pup 3 9,631’ RA Pup 4 10,175’ CIBP capped w/ 5’ cmt (11/13/14) 5 10,199’ RA Pup 6 10,270’ CIBP capped w/cmt (11/4/14) 7 10,360’ CIBP capped w/cmt (9/6/14) OPEN HOLE / CEMENT DETAIL 10-3/4” 165BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 197BBL’s of cement in 9-7/8” Hole. TOC 1,575’ Calculated 5” 145BBL’s of cement in 6-3/4” Hole. TOC 4,150’ Calculated. Per 8/14/14 SCMT: Free pipe above 3600’. Top solid cement at 5390’ MD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Pool Date Status D-2 9,830’ 9,845’ 8,967’ 8,982’ 15’ Ty Gas Pool #1 07/08/21 Open D-3A 10,083’ 10,101’ 9,134’ 9,152’ 18’ Ty Gas Pool #1 02/07/17 Open D-3B 10,132’ 10,169’ 9,268’ 9,305’ 37’ Ty Gas Pool #1 12/05/14 Open D-3C 10,178’ 10,198’ 9,314’ 9,334’ 20’ Ty Gas Pool #1 11/04/14 Isolated – wet (11/13/2014) D-4 (D4B) 10,296’ 10,313’ 9,431’ 9,448’ 17’ Ty Gas Pool #1 09/07/14 Isolated (11/4/2014) 10,313’ 10,333’ 9,448’ 9,468’ 20’ Ty Gas Pool #1 09/07/14 D-5 (D4D) 10,372’ 10,380’ 9,507’ 9,515’ 8’ Ty Gas Pool #1 09/02/14 Isolated (9/6/2014) tested tight , possibly wet 10,380’ 10,394’ 9,515’ 9,529’ 14’ Ty Gas Pool #1 09/02/14 Fish: CIBP milled and pushed to bottom w/ WO Rig (MD) (MD)(TVD)(TVD) D-2 9,830’9,845’8,967’8,982’15’Ty Gas Pool #1 07/08/21 Open (MD)(MD)(TVD)(TVD) TG 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: _____Patch / N2______ 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,895'See schematic Casing Collapse Structural Conductor Surface 2,470psi Intermediate 4,790psi Production 10,490psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ryan Rupert Operations Manager Contact Email: Contact Phone: 777-8503 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: July 16, 2021 N/A 10,892' Perforation Depth MD (ft): 6,483' See Attached Schematic 10,892'10,026'5" 16" 10-3/4" 135' 7-5/8"6,483' 1,595'5,210psi 135' 1,570' 5,801' 135' 1,595' N/A TVD Burst N/A 10,140psi MD 6,890psi Length Size CO 510B Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE A028142 214-089 50-133-20634-00 KBU 42-06Y Kenai Gas Field - Tyonek Gas Pool 1 COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic ryan.rupert@hilcorp.com 10,029'10,175'9,311'~665psi See schematic Swell Pkr; N/A 6,006' MD / 5,387' TVD; N/A Perforation Depth TVD (ft):Tubing Size: m n P 66 t _ c Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:55 am, Jul 02, 2021 321-333 s Managers ManagerManagDigitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.07.01 16:21:19 -08'00' Taylor Wellman (2143) SFD 7/2/2021 SFD-00 BJM 7/2/21 DSR-7/6/21 dts 7/6/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.07 13:07:29 -08'00' RBDMS HEW 7/7/2021 10-404 Well Prognosis Well: KBU 42-06Y Date: 7/1/2021 Well Name:KBU 42-06Y API Number:50-113-20634-00-00 Current Status:Gas Producer Leg:N/A Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:214-089 First Call Engineer:Ryan Rupert (907) 777-8503 (O)(907) 301-1736 (C) Second Call Engineer:Ted Kramer (907) 777-8420 (O)(985) 867-0665 (C) Maximum Expected BHP:~ 665 psi @ 8982’ TVD 2017 RFT pressure in D2 Max. Potential Surface Pressure:~ 665 psi Using Max BHP to surface (if no gas weight) Well Summary KBU 42-06Y is a steady Tyonek Gas Pool #1 producer. It flows at 650mcfd and 15 bwpd. The goal of this project is to perforate the D2 sand to add production to the well Notes Regarding Wellbore Condition x Min ID = 4.276” (5” tubing/liner ID) x Max Inclination = 33 degrees at 3152’ MD x Drifts o 3/24/17: SLB PLT run. 1-11/16” x 39’ BHA. Tagged bottom at 10,170’ ELMD o 2/18/17: After 11 days of fishing, all wire and BHA recovered. A 3.75” magnet drift made it to 10,167’ SLMD and tagged after all fish/wire recovered. o 2/7/17: EL shot 18’ of perfs down to 10,101’ MD with a 2-7/8” gun. Well was flowing 3.4MM at 320psi FTP. Appears line/gun jumped upward and got balled up. Ended up parting wire and leaving ~200’ of wire downhole Nitrogen Risk x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) x Ensure all crews are aware of stop work authority Well Prognosis Well: KBU 42-06Y Date: 7/1/2021 E-Line Perf 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2,500 psi High. 3. Consult with OE to determine if Nitrogen is needed to pressure up wellbore 4. RU Nitrogen Truck 5. Pressure up wellbore per OE 6. Rig up perf gun (Likely 2-7/8” 4-6 spf) 7. RIH and perforate the sand listed in the table below, per Geo/RE. Sand Perforation Top (MD) Perforation Bottom (MD) Perforation Top (TVD) Perforation Bottom (TVD) Total Footage (MD) D2 ±9,830’±9,845’±8,967’±8,982’15‘ Consult with OE for what WHP to use. May be shot while flowing Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a.Use Gamma/CCL to correlate. b. Record initial and 5/10/15 minute tubing pressures after firing c. Consult with RE/Geo between each perf interval: i. Trudi Hallett (RE): 301-6657 ii. Ben Siks (Geo): 229-0865 8. RD E-Line Unit and turn well over to production. Contingency EL Plug or Patch 1. MIRU E-line, PT lubricator to 250 psi low / 2,500 psi high 2. RIH W/ GPT tool and find fluid level 3. RU Nitrogen Truck a. Push water back into formation b. Use GPT tool to confirm water level is below interval to perf c. Consult OE for pressure to leave on well for perforating 4. Once fluid level is below interval to isolate, MU 5” patch or plug 5. RIH and set plug or patch per OE. 6. RD E-Line Unit and turn well over to production. Attachments: 1. Current schematic 2. Proposed Schematic 3. Standard Well procedure – N2 Operations _____________________________________________________________________________________ Updated by CRR 07-01-21 SCHEMATIC Kenai Gas Field Well: KBU 42-06Y PTD: 214-089 API: 50-133-20634-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor 109 / X-56 / Weld Surf 135' 10-3/4”Surface 45.5 /L-80 / BTC 9.950 Surf 1,595' 7-5/8"Intermediate 29.7 / L-80 / BTC 6.875 Surf 6,483' 5"Production 18 / L-80 / DWC/C-HT 4.276 Surf 10,892’ JEWELRY DETAIL No Depth Item 1 6,006’5” Swell Packer 2 9,425’RA Pup 3 9,631’RA Pup 4 10,175’CIBP capped w/ 5’ cmt (11/13/14) 5 10,199’RA Pup 6 10,270’CIBP capped w/cmt (11/4/14) 7 10,360’CIBP capped w/cmt (9/6/14) OPEN HOLE / CEMENT DETAIL 10-3/4”165BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"197BBL’s of cement in 9-7/8” Hole. TOC 1,575’ Calculated 5”145BBL’s of cement in 6-3/4” Hole. TOC 4,150’ Calculated. Per 8/14/14 SCMT: Free pipe above 3600’. Top solid cement at 5390’ MD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Pool Date Status D-3A 10,083’10,101’9,134’9,152’18’Ty Gas Pool #1 02/07/17 Open D-3B 10,132’10,169’9,268’9,305’37’Ty Gas Pool #1 12/05/14 Open D-3C 10,178’10,198’9,314’9,334’20’Ty Gas Pool #1 11/04/14 Isolated – wet (11/13/2014) D-4 (D4B) 10,296’10,313’9,431’9,448’17’Ty Gas Pool #1 09/07/14 Isolated (11/4/2014)10,313’10,333’9,448’9,468’20’Ty Gas Pool #1 09/07/14 D-5 (D4D) 10,372’10,380’9,507’9,515’8’Ty Gas Pool #1 09/02/14 Isolated (9/6/2014) tested tight , possibly wet10,380’10,394’9,515’9,529’14’Ty Gas Pool #1 09/02/14 Fish: CIBP milled and pushed to bottom w/ WO Rig _____________________________________________________________________________________ Updated by CRR 07-01-21 PROPOSED SCHEMATIC Kenai Gas Field Well: KBU 42-06Y PTD: 214-089 API: 50-133-20634-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor 109 / X-56 / Weld Surf 135' 10-3/4”Surface 45.5 /L-80 / BTC 9.950 Surf 1,595' 7-5/8"Intermediate 29.7 / L-80 / BTC 6.875 Surf 6,483' 5"Production 18 / L-80 / DWC/C-HT 4.276 Surf 10,892’ JEWELRY DETAIL No Depth Item 1 6,006’5” Swell Packer 2 9,425’RA Pup 3 9,631’RA Pup 4 10,175’CIBP capped w/ 5’ cmt (11/13/14) 5 10,199’RA Pup 6 10,270’CIBP capped w/cmt (11/4/14) 7 10,360’CIBP capped w/cmt (9/6/14) OPEN HOLE / CEMENT DETAIL 10-3/4”165BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"197BBL’s of cement in 9-7/8” Hole. TOC 1,575’ Calculated 5”145BBL’s of cement in 6-3/4” Hole. TOC 4,150’ Calculated. Per 8/14/14 SCMT: Free pipe above 3600’. Top solid cement at 5390’ MD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Pool Date Status D-2 ±9,830’±9,845’±8,967’±8,982’15’Ty Gas Pool #1 TBD Proposed D-3A 10,083’10,101’9,134’9,152’18’Ty Gas Pool #1 02/07/17 Open D-3B 10,132’10,169’9,268’9,305’37’Ty Gas Pool #1 12/05/14 Open D-3C 10,178’10,198’9,314’9,334’20’Ty Gas Pool #1 11/04/14 Isolated – wet (11/13/2014) D-4 (D4B) 10,296’10,313’9,431’9,448’17’Ty Gas Pool #1 09/07/14 Isolated (11/4/2014)10,313’10,333’9,448’9,468’20’Ty Gas Pool #1 09/07/14 D-5 (D4D) 10,372’10,380’9,507’9,515’8’Ty Gas Pool #1 09/02/14 Isolated (9/6/2014) tested tight , possibly wet10,380’10,394’9,515’9,529’14’Ty Gas Pool #1 09/02/14 Fish: CIBP milled and pushed to bottom w/ WO Rig 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. ! • 214009 Seth Nolan Hilcorp Alaska, LLC q S G GeoTech 3800 Centerpoint Drive, Suite 100 f f� Anchorage, AK 99503 Te : 907 IIil.v,rp.,l.EMka,,. { RECEIVE"' Fax 907 777-8510 E-mail: snolan@hilcorp.com MAY 052017 DATE 03/31/17 DATA LOGGED AOGCC /16,201, M.K BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 42-06 Prints: Production Profile CD 1 : BUS Data 3/31/2.117 2:14 PM File folder LAS Data 3/31/2017 2:14 PM File folder Log 3/31/2017 2:14 PM File folder Please include current contact information if different from above. SCANNED JUN 1 9 2017 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By�� O , 4Date: STATE OF KA ALA.OIL AND GAS CONSERVATION COMMOION RECEIVED REPORT OF SUNDRY WELL OPERATIONS APR 2 7 2017 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U AOGGC'wn U Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ =rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well Cl Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑✓ Exploratory ❑ 214-089 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic El Service ❑ 6.API Number: AK 99503 50-133-20634-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEE A028142 Kenai Beluga Unit(KBU)42-06Y 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai-Beluga/Upper Tyonek Gas and Tyonek Gas Pool 11.Present Well Condition Summary: 10,175; Total Depth measured 10,895 feet Plugs measured 10,270; 10,360 feet true vertical 10,029 feet Junk measured -10,265(CIBP) feet Effective Depth measured 10,170 feet Packer measured 6,006' feet true vertical 9,306 feet true vertical 5,387' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16" 135' 135' Surface 1,595' 10-3/4" 1,595' 1,570' 5,210psi 2,470psi Intermediate 6,483' 7-5/8" 6,483' 5,801' 6,890psi 4,790psi Production 10,895' 5" 10,892' 10,026' 10,140psi 10,490psi Liner Perforation depth Measured depth See Attached Schematic scomED MAY 17 2017, 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) 5"Swell Pkr;N/A 6,006'MD 5,387'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 4153 3 0 339 Subsequent to operation: 0 8258 1.4 0 1840 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas Q WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-042 Authorized Name: Chad Helgeson 777-8405 Contact Name: Joe Kaiser Authorized Title: Operations Manager Contact Email:jkaiser(C7hilcorp.corn ,/,//:c , Authorized Si nature: 9 Date: 0.61 f 7 Contact Phone: 777-8393 Form 10-404 Revised 4/2017 RBDMS cN MAY - 3 2010 R I G I N A L — 4g% ubmit Original Only • • r r Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KBU 42-06Y 50-133-20634-00 214-089 2/7/17 3/24/17 Daily Operations: 02/07/2017 -Tuesday Sign in. PTW aand JSA. Mobe to location and rig up lubricator. PT to 250 psi low and 3500 psi high. Had o-ring leak and some trouble with tool catcher to release. Well flow at 3.5 mil at 318 psi. RIH with 3.6" GR and 3-3/8" CCL, tie into log sent from town and tag fill at 10,170'. No problem going in hole flowing 3.5 million at 318 psi. POOH. RIH with 2- 7/8"x20' (18' loaded) Connex HC, 6 spf, 60 deg phase and tie into perf log sent from town. Run correlation log and send to town. Get ok to perf from 10,083' to 10,101' (D3A Sand). Spot shot and fired gun flowing at 3.4 mil at 318 psi. Started pulling out of hole and gun wt was light. Line wt would even out about 2-300 lbs lighter and then get 10 lbs lighter like fluid was pushing us. Got to 1100' and line hung up. It looks like line is hung in grease tube. Can't come up pi or down. Line drops immediately so it is right at surface. Call HLB WL manager and he said to pull half of breaking strength (2,900 lbs). Line parted at 2,100 lbs. Tried to close swab but line was in it according to number of turns to close. Secured well and placed 24hr watch (Halliburton) on well and equipment while plan was developed overnight to p� remove fish. Secured well and placed 24hr watch (Halliburton) on well and equipment while plan was developed overnight to remove fish. 02/08/2017-Wednesday Sign in and mobe to location. Fill out PTW and have JSA. Change out grease skid and check out. Fixed a few minor / things and pumped grease between wireline rams to 3000 psi. Got rams to hold. Pick up lubricator and had approx. 125' of wire balled up in lubricator. Cut wire off and re-string wire thru grease head.Took 30' of lubricator off and tied two lines together. Pulled another 18' and hit a ball of wire that was approx. 75' long. Cut that line off and restring wire thru grease head and 60' of lubricator. Re-head line and pump grease between rams (3000 psi). Well flowing to production 4.3 mmscf at 336 psi. Secure well and clean up around well.This was a good stopping point. SDFN. Halliburton hand will be on location all night. 02/09/2017 -Thursday Sign in and mobe to location. PTW and JSA. Warm up equipment. Made 6 runs today pulling 55' of 7/32" line (60' lub) using footage by depth counter head. Line was balled up and kinked on every run so it was hard to really get an exact measurement. It appears that we left approx. 200' of e-line in hole plus perf gun tool string. We got approx. 900' of line out of hole. (Got approx. 175' out first day). Rig down eline and clean up. Will have slickline out tomorrow to fish wire and tool string. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KBU 42-06Y 50-133-20634-00 214-089 2/7/17 3/24/17 Daily Operations: 02/10/2017 - Friday Arrive at Office. Permit/JSA Travel to location, inspect location. Spot in equipment. Pre-Job and review JSA. Begin rig- up. 60' of 4" Lubricator. Triple WLV for slickline and e-line, pressure test lubricator 250/3500 psi RIH w/3.5" GR, 3.5" Bait Sub, XO, 4.05" Wire finder, 3' stem, 2.62" 3 Prong Grab. OAL 6' Set down @ 4,275' wlm. Pull bind. Sheard off after three licks. 1400# No movement on fish. POOH RIH w/3.5" GR, Latch bait sub @ 4,272' WLM. Latch fish. Beat up, shear tool. Try beating down. No movement. POOH. RIH w/3.5" GS. Latch bait sub &fish. 12 licks and tools come free. POOH, retrieved approx. 35' of broken wire out of well. RIH w/3.5" GS 3.5" Bait sub, XO, 4.00" Wire finder 3' stem 2.62 3 prong grab. OAL=6'. S/D @ 4,277' WLM. Pull a few small binds. Unable to bury three prong grab. POOH and swap tools. 3.5" GS 3.5" Bait sub, XO, 4.00" Wire finder 3' stem 1.25" Center spear. OAL=5' 10". Planted spear and sheared off. POOH. Lay down Lub and secure well. 02/11/2017 -Saturday Arrive at Office. Permit/JSA Travel to location, Inspect location. Pre-Job and review JSA. Rig up .125 slickline. Triplex out of fluid, filled pump PRESSURE TEST 3000 passed. RIH w/3.5" GS. S/D @ 4272' WLM. Pull 1200# bind. Gained 25#s. POOH. No wire. RIH W/4.05 wirefinder/3.80" LIB, S/D @ 4275' WLM. Tap down once. POOH. No impression. Run again RIH w/4.05 wirefinder 3.80 LIB Tap down hard @ 4269' WLM POOH, Impressions of wire on side of LIB. RIH w/3.5" GR, 3.5" bait sub, 4.05 Wire finder 3 prong grab. S/D @ 4274' WLM. Beat down for ten minutes. Pull a bind...sheared off. RIH w/3.5" GS. Latch up to bait sub. 4269' WLM. Beat upward for 20 minutes. Come free. POOH. Retrieved 4' feet of broken wire. Partially broken barb. RIH w/3.5" GR, 3.5" bait sub, 4.05 Wire finder 3 prong grab. S/D @ 4275' WLM. Beat down, pull a bind and shear off. RIH w/3.5" GS. S/D @ 4268' WLM/ Unable to latch. Work tools and POOH. Sheared tool. Winds gusting past 35mph. Lay down for the night. 02/12/2017 -Sunday Arrive at Office. Permit/JSA Travel to location, Inspect location. Pre-Job and review JSA, Rig up .125 slickline. Lay down Lubruicator due to high winds. Rig up .125 slickline. RIH W 3.5" GS. Unable to latch. POOH, Not sheared, add knuckle. RIH w knukle, 3 1/2" GS. Latch @ 4269' WLM. Jar licks for 20 minutes. Come free, POOH 4' of wire on grabs. RIH w/3.5 " GR, Bait sub, 4.05" Wirefinder, 3' stem, 2.805 3 Prong wire grabs. Plant wire grabs on fish @ 4276' WLM. Shear off POOH RIH w/3.5 " GS, Pull a 1500# bind and come off. POOH, No wire RIH w/3.5" GS Bait Sub, 4.05 Wirefinder, 2.805 3 -prong wire grab, Set Down @ 4278' WLM. 10 Licks and POOH. 4' of wire on grabs. Rig down, move on. Secure wellhead. • Hilcorp Alaska, LLC kit kAko, Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KBU 42-06Y 50-133-20634-00 214-089 2/7/17 3/24/17 Daily Operations: 02/14/2017-Tuesday Arrive KGF, meet w/ Mac TGSM,JSA permit, discuss procedure. Rig up .160 wire P/T Lub 3,000psi, good. RIH, 3.9" centralizer w/3" Lib to 4,285' KB. Sit hit one time. POOH. Wire marks on face and sides. RIH w/4-1/2" bait sub w/ center spear to 4,289' KB. Sit w/tool, latch wire 1 jar lick, came free. POOH. Pin sheared. RIH w/4-1/2" GS to 4,286' KB, latch w/tool 1 jar lick, came free. POOH w/6 pieces wire 27' long. RIH w/4-1/2" GS to 4,284' KB, sit latch w/tool, came free. POOH w/6 pieces of wire 11'. RH w/4-1/2" GR w/4-1/2" bait sub w/2 prong wire grab to 4,291' KB. Sit w/tool latch 2 jar licks, came free. POOH, pin sheared. RIH w/4-1/2" GS to 4,268' KB, WT 6 jar licks, came free. POOH. OOH 3' wire and bent grab. Crew change out. RIH w/3.7" centralizer w/3" Lib 4,290' KB. WT POOH, OOH w/ wire marks. RIH w/4-1/2" GR w/ bait sub w/wire grab to 4,291'KB. Latch 3 jar licks, shear. POOH. RIH w/4-1/2" GS to 4,290'KB, WT. POOH, OOH w/8' wire. RIH w/4-1/2" GR w/ bait sub to 4,291' KB. POOH, OOH w/21' wire. RIH w/ same to 4,293' KB WT. POOH, OOH w/9' wire. RIH w/same to 4,293' KB WT. Slip off multiple time. POOH, OOH no wire, grab bent. RIH w/4.5" GS w/ bait sub and wire grab to 4,293' KB WT, no overpull. POOH. OOH, no wire. RIH w/ 3.7" centralizer w/3" LIB to 4,293' KB. POOH, OOH w/ impression of wire. RIH w/4.5" GS w/ bait sub &wire grab to 4,294' KB WT, shear off. POOH. RIH w/4.5" GS to 4,294' KB WT, latch. POOH, OOH w/bent grab, no wire. RIH w/ 1.5" RB w/3.4" Bell guide to 4,294' KB WT, could not latch. POOH. RIH w/2.6" blind box on 5' stem to 4,294' KB WT, (beat down) no movement. POOH. RIH w/3" LIB to 4,294' KB WT. POOH, OOH w/faint impression of wire. RIH w/4.5" GS w/ bait sub and KJ w/single prong wire grab to 4,295' KB WT, no latch. RIH w/same w/3 prong grab to 4,295' KB WT, friction bite (400 lbs). POOH, OOH no wire. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number •Start Date End Date KBU 42-06Y 50-133-20634-00 214-089 2/7/17 3/24/17 Daily Operations: 02/15/2017-Wednesday RIH w/same w/4 prong grab, flared to 4" to 4,295' KB, 1800 lb jar lick, slip off 1,500 lb over pull, came free. POOH, 1 piece wire 1 ft long. Crew C/O. Lay down lub, cut wire, re-head. RIH w/3.9" centralizer w/3" LIB to 4,294' KB, hit one time. POOH w/wire marks. RIH w/3.5" GR w/3.5" bait sub w/2 prong wire grab to 4,295' KB WT, friction bites. POOH w/grab, 3 pieces wire 5' total length. RIH w/same to 4,297' KB WT, friction bites. POOH, no wire. RIH w/same w/3 prong grab to 4,296' KB WT, 1 friction bite, slips off. POOH, OOH, no wire. RIH w/3.5" GR w/3.5" bait sub w/ center spear to 4,297' KB WT, no friction bite. POOH. RIH w/3.5" GR w/3.5" bait sub w/3 prong wire grab to 4,297' KB WT, small friction bites, would not latch. POOH, no wire. RIH w/3.5" GR w/ bait sub & sgl prong to 4,297' KB WT, no friction bites. POOH. RIH w/3.9" cent w/3" LIB to 4,297' KB. hit 2 times. POOH, impression of wire. RIH w/3.9" cent w/3.75" magnet to 4,297' KB WT. POOH, no wire. RIH w/3.9" cent w/ 1.75" DD bailer to 4,297' KB. POOH, empty. RIH w/3.5" GR w/ bait sub & sgl prong to 4,297' KB WT, no frictions bites. POOH, OOH w/6" ball of wire strands. RIH w/4.5" GR bait sub, 4 pong grab to 4,298' KB WT, 1200 lb oil jar lick, shear. RIH w/4.5" GS to 4,298' KB, latch bait sub, no over pull. POOH, OOH w/ bent grab. RIH w/4.5" GR w/ bait sub & KJ 5' stem & prong grab to 4,298' KB WT, no latch. RIH w/same W/O KJ, could not latch. POOH. RIH w/same w/2.25" LIB to 4,298' KB WT. POOH, OOH w/ impression of wire. RIH w/2.25" LIB to 4,299' KB. Hit one time. POOH, impression of wire. RIH w/4-1/2" GR w/5' stem w/ prong grab to 4,299' KB. Small friction bites. POOH. RIH w/4-1/2" GR w/3 prong wire grab w/tool 1,000#. Jar lick, came free. POOH. RIH w/4-1/2" GS to same w/tool, came free. POOH, pin sheared. RIH w/4-1/2" GS to same w/tool. Came free., POOH, pin sheared. RIH w/4-2/" GR to 4,294' KB. Latch. POOH, no wire. RIH w/ 2-1/2" JUC to 1.75" prong to 4,294' KB w/tool. POOH, no wire. Add stem, RIH w/2.1" blind box to 4,299' KB. Beat down 45 min. POOH. RIH w/4-1/2" GS w/ bait sub w/2 prong grab to 4,300' KB w/tool 1,500#jar lick. POOH w/6" wire. RIH w/same 3 prong wire grab to 4,300' KB w/tool. •• • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KBU 42-06Y 50-133-20634-00 214-089 2/7/17 3/24/17 Daily Operations: 02/16/2017-Thursday POOH, no wire, bent grab. RIH w/same single prong grab to 4,300' KB w/tool 1500#jar lick 2,500#dead pull, came free. POOH, no wire. RIH w/4-1/2" GR w/ bait sub w/single spear to 4,300' KB w/tool no friction bites. POOH. Lay down LUB, cut wire, re-head, check tool string. RIH w/2-1/2" JUC w/alligator grab to 4,300' KB w/tool. POOH 1 strand wire 5". RIH w/same, add 3' stem w/tool. POOH, pin not sheared. RIH w/same to same w/tool. POOH, pin sheared no wire. RIH w/same w/center spear to 4,300' KB w/tool w/2-400#friction bites. POOH 1 strand wire 4 inches. RIH w/ 2.5" JUC w/sgl spear to 4,300' KB WT 1,000#, pull slips off. POOH, no wire, bent grab. RIH w/2.5" RB w/2 prong grab to 4,300' KB WT 1,000#, bits slips off. POOH, no wire. RIH w/ KJ 3" steam w/2" RB to 4,300' KB WT, would not latch. POOH. RIH w/4.5" R w/ bait sub w/5' stem w/3.9" Cent, 5' stem, 2.23" LIB to 4,300' KB, hit one time. POOH, impression of wire. RIH w/same w/ magnet to 4,300' KB WT. POOH w/wire strands. RIH w/2.5"JUC baited w/ 1.75" rope socket, 5' steam, 3.9" Cent, 4' stem center spear to 4,300' KB WT. POOH, OOH w/8" single stand of wire. RIH w/ KJ 3.9" Cent, 3' 1.75" stem, 3.73" Cent, 3' stem w/ 1.87" LIB to 4,300 KB WT. POOH, OOH w/ impression of wire and metal, no rope socket. RIH w/same w/3" magnet to 4,300' KB WT. POOH, OOH w/shavings and 1 small strand. RIH w/same w/2.25GR to 4,301' KB WT. Gain no hole. POOH, metal marks. RIH w/4.5" GR w/ bait sub w/5' steam w/3.9" Cent 5' stem w/wire grab to 4,302' KB WT, could not latch wire. POOH. RIH w/same w/ 2 prong grab 3.5" OD to 4,302' KB WT, friction bites. POOH, no wire. RIH w/same w/3 prong grab flared to 4" to 4,301' KB WT, no latch. POOH. FIH w/4 1/S GR w/centralizer, 3' stem 4 prong grab to 4,301' KB WT, could not latch. POOH, OOH, no wire. RIH w/same w/2.65" gauge ring to 4,300' KB, beat down 30 mins, no movement. POOH. RIH w/4-1/2" GR w/2 prong grab to 4,300' KB WT, no latch. POOH, OOH w/ bent grab. RIH w/4-1/2" GR w/3.7" centralizer w/2.75" wedge to 4,300' KB WT, beat down. POOH, OOH w sheared GR. RIH w/4-1/2" GS to 4,298' KB latch. POOH, OOH w/ bait sub and swedge. RIH w/4-1/2" GR w/3.5 LIB to 4,300' KB WT. POOH, OOH w/impressions of wire marks. RIH w/2.5"JUC w/ baited 5' stem KJ 3.5" centralizer wire grab (designed to position grab on high side of tubing) to 4,301' KB WT, no latch. POOH. RIH w/same w/ prong grab to 4,301' KB WT, friction bites. POOH. RIH w/same w/2 prong grab to 4,301 KB WT, grab wire. 1800 lb oil jar lick, shear. • • Hilcorp Alaska, LLC Litt Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KBU 42-06Y 50-133-20634-00 214-089 2/7/17 3/24/17 Daily Operations: 02/17/2017 - Friday RIH w/2-12" JDC w/2.68" bell guide to 4,297' KB WT, latch bait sub, 1800 lb OJ lick come. POOH, OOH w/ no wire. RIH w/same to 4,302' KB WT, several oil jar licks slipping off. POOH, OOH, no wire. RIH w/2-1/2" RB 5' stem KJ 3" Cent 1 prong grab to 4,300' KB WT. POOH, bent grab, 1 strand of wire. RIH w/2-1/2" RB 5' stem KJ 3.70" Cent 2 prong grab to 4,303' KB. RIH w/3.75" magnet to 4,303' KB. OOH, 3 strands of wire. Stand by to flow well. Lay down LUB, re- head cut wire. RIH w/2-1/2" RB baited 5' stem KJ 3.9" Cent 3 prong grab sit down 2,970' KB WT, could not latch. RIH w/2-1/2" RB baited 3.9" Cent 3.9" LIB to 2,970' KB, hit one time. POOH, fine wire marks. RIH w/2-1/2" RB 3.7" Cent 5' stem 3.9" Cent 3' stem 2.6" LIB, fine wire marks. RIH w/ 2-1/2"JDC baited center spear to 2,970' KB WT latched. Came free WT latched. POOH, OOH w/ big ball of wire. RIH w/4-1/2" Bowen wire finder to 2,973' KB, sit down. POOH. RIH w/3.7" LIB to 2,970' KB. OOH, same fine wire marks. RIH w/center spear to 2,970' KB w/tool latch shear off. POOH. RIH w/2-1/2"JDC w/3.7" bell guide to 2,963' KB, latch w/tool, came free. POOH. RIH w/2-1/2" RB w/ 3.7" Cent w/5' stem w/3.9" Cent w/3' stem w/ 1 prong grab to 2,970' KB WT, could not latch. POOH. RIH w/same w/center spear to 2,970' KB WT latched, 1 1700#jar lick, came free, WT cold not relatch. OOH, lower hooks bent. RIH w/same w/ 3 prong grab to 2,970' KB WT, latched, 100#over. POOH, OOH w/ hand full of single stands. RIH w/ same to 2,970' KB WT, 1,800 lb jar lick, shear tool. POOH. RIH w/2-1/2"JDC w/2.68" bell guide to 2,964' KB WT, latch bait sub. POOH, OOH w/ bait sub and grab, no wire. RIH w/2-1/2" JUC w/ baited prong grab to 2,970' KB WTA, 1,800 lb jar licks, shear. POOH. RIH w/2-1/5"JUC to 2,970' KB WT, 1,500 lb jar lick come free. POOH, OOH no wire. RIH w/ 3.5" magnet centralized to 2,970' KB WT. POOH, OOH w/ hand of strands. RIH w/3.5" magnet centralized to 2,970' KB WT. POOH, OOH w/fine shavings. RIH w/3.9" centralizer w/3' stem w/ 1.85" LIB to 2,970' KB WT. POOH, OOH w/ impression of wire frayed on top of rope socket. RIH w/3.9" centralizer w/3' stem w/2"JDC w/2.25" bell guide to 2,970' KB WT, could not latch. POOH, not sheared. RIH w/2"JUC inside 3.9" bell guide to 2,970' KB, could not latch. POOH. RIH w/3.9" centralizer w/3.65" LIB to 2,970' KB WT. POOH, OOH w/wire marks. RIH w/same w/2.25" GR to 2,971' KB WT, move tools to 2,974' KB. POOH. RIH w/same w/2"JUC to 2,974' KB WT, could not latch. POOH. RIH w/ 2-1/2"JDC w/ bail sub and wire grab to 2,973' KB WT, latch wire 2,000 Ib, OJ lick come free, drag 1,000 lbs over. POOH. OOH w/approx. 50' wire balled up. Lay down LUB to get ball of wire out. 02/18/2017-Saturday RIH w/3.9" Cent w/3.5" LIB to 10,129' KB WT. POOH, OOH w/shows faint trace wire. RIH w/2-1/2" RB baited w/4- 1/2" wire finder w/4 prong wire grab to 10,160' KB, latch w/tool 2,500# pull, came free. POOH w/approx. 30' wire. RIH w/3.7" LIB to 10,160' KB sit, hit 2 times. POOH w/ impression of rope socket. RIH w/ 2" JDC w/3.7" bell guide to 10,160' KB w/tool latch pull 2,500#jar lick slipped off w/tool, could not latch. POOH, check tool. RIH w/2"JDC to 10,160' KB sit w/tool, friction bites, slipping off. POOH, broken dog on JDC. Discuss w/Chris, call Halliburton determine rope socket size of fishing neck. Standby for tools. RIH w/3.75" over shot w/ 1-7/16" grapple baited w/4- 1/2" GR to 10,160' KB w/tool latch 2 jar licks, came free. POOH. RIH w/4-1/2" GS to 10,161' KB w/tool latch several jar licks, came free. POOH w/fish. RIH w/3.75" magnet to 10,167' KB. Tag, POOH w/several strands of wire. • • • • 1M pm- Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date •End Date KBU 42-06Y 50-133-20634-00 214-089 2/7/17 3/24/17 Daily Operations: 03/24/2017- Friday Sign in. PTW aand JSA. Mobe to location and rig up lubricator. PT to 250 psi low and 3500 psi high. . Well flow at 8 mil at 1600 psi. RIH with SLB PLT and logged from 10,050 to 10,170' up and down at 30 fpm, 60 fpm and 90 fpm.Took 5 min stations at 10,010', 10,130' and 10,160'.Tagged at 10,170'. Used a log that was sent from anchorage that they made to tie in with. Rig down lubricator and turn well back over to field. , 11 • 0 Kenai Gas Field Well: KBU 42-06Y SCHEMATIC PTD: 214-089 Fiilcorp Alaska,LLC API: 50-133-20634-00 RKB:MSL=18.5' CASING DETAIL E+ Size Type Wt/Grade/Conn ID Top Btm y 16" Conductor 109/X-56/Weld Surf 135' 14 10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,595' 16" 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,483' 5" Production 18/L-80/DWC/C-HT 4.276 Surf 10,892' 4 4i 10-3/4" c:it e, 11 JEWELRY DETAIL No Depth Item 1 6,006' 5"Swell Packer 4 2 9,425' RA Pup LA 3 9,631' RA Pup 4 10,175' CIBP capped w/5'cmt 5 10,199' RA Pup 31 6 10,270' CIBP capped w/cmt 7 10,360' CIBP capped w/cmt • 1. kg .1 OPEN HOLE/CEMENT DETAIL r?r 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface I.. 7-5/8" 197BBL's of cement in 9-7/8"Hole.TOC 1,575'Calculated 5" 145BBL's of cement in 6-3/4"Hole. TOC 4,150'Calculated st' '1 m " 1 `. PERFORATION DETAIL x ., Btm 1 7-5/8" Sands Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status D-3A 10,083' 10,101' 9,134' 9,152' 18' 02/07/17 Open B 10,132' 10,169' 9,268' 9,305' 37' 12/05/14 Open D-3C 10,178' 10,198' 9,314' 9,334' 20' 11/03/14 Isolated 2 D-4 10,296' 10,313' 9,431' 9,448' 17' 09/07/14 Isolated D-4 10,313' 10,333' 9,448' 9,468' 20' 09/07/14 Isolated D-5 10,372' 10,380' 9,507' 9,515' 8' 09/02/14 Isolated J 3 D-5 10,380' 10,394' 9,515' 9,529' 14' 09/02/14 Isolated , D-3A 0-3B TOF @ 10,250' 1'- 4 Fish: CIBP milled and pushed to bottom w/WO Rig 5 D-3C .,4 5,' Y;-'' '�;6 7 tj s, ,. D-4&5 5„ f PBTD=10,805'MD/9,940'TVD ID=10,895'MD/10,029'TVD Updated by DMA 04-26-17 2J Op o Seth Nolan Hilcorp Alaska, LCC O j 3 GeoTech 3800 Centerpoint Drive, Suite 100 RECEIVED Tele:Ancho 907 777-83083 tti�rnr�,Aiaola.LTA. Fax: 907 777-8510 MAR 0 9 2017 E-mail: snolan@hilcorp.com DATE 03/08/17 AOGrtj DATA LOGGED V A'S/2011 To: Alaska Oil & Gas Conservation Commission M K. BENDER Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 42-06 Prints: Perforation Record CD 1 : KBU_42-06Y PERF_O/rt817.pdf 2/28/2017 9:19 AM PDF Document 513K8 KBU_42-06Y PERF_07FEB17 CORRELATION... 2/28/2017 9:19 AM LAS File 70 KB KBU_42-06Y PERF_O7FEB17_img.tif 2/28/2017 9:19 AM TIF File 1,537 KB __KBU_42-06Y PERF 07FEB17_SHOOTING_10... 2/28/2017 1:34 PM LAS File 55 KB Please include current contact information if different from above. SCANNED APR 4 7 2017, Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: 17) ,/a.41.42(4.11%) 6eier_eetie • • 94•P\ Art ��\1 v- �� UfLASI�;A THE STATE Alaska Oil and Gas Conservation Commission = _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \*� Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson � O ivIAR 2, $7117 Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Kenai Field, Beluga/Upper Tyonek and Tyonek Gas Pools, KBU 42-06Y Permit to Drill Number: 214-089 Sundry Number: 317-042 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, 01. 7 Daniel T. Seamount, Jr. Commissioner DATED this day of January,2017. RBD1VIS (,L- FE3 - 3 2017 • , • • - ECEIVED STATE OF ALASKA JAN 2 4 7017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS O GGO 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑., • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0• 214-089 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20634-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.510h('eed---- Will planned perforations require a spacing exception? Yes ❑ No 0 piii. „17 Kenai Beluga Unit(KBU)42-06Y , 9.Property Designation(Lease Number): 10.Field/Pool(s): FEE A028142• Kenai-Beluga/Upper Tyonek Gas and Tyonek 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): 10,175'; Junk(MD): 10,895' • 10,029' • 10,805' 9,940' 3,041 psi 10,270';10,360' —10,265'(CIBP) Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16” 135' 135' Surface 1,595' 10-3/4" 1,595' 1,570' 5,210psi 2,470psi Intermediate 6,483' 7-5/8" 6,483' 5,801' 6,890psi 4,790psi Production 10,895' 5" 10,892' 10,026' 10,140psi 10,490psi Liner p 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): 5"Swell Pkr;N/A 6,006'MD/6,387'TVD;N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑., ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: February 7,2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑✓ • 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 jkaiser@hilcorp.com Printed Name Chad Helgeson Title / �%,/�y� 9 Operations Manager Signature /'��< Phone 907-777-8405 Date V211(7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ( 3 \-1- 0�,12. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ i•--13 +►r" ( ( ),q Other: r V� Post Initial Injection MIT Req'd? Yes ❑ No ❑ / 7 Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required: < ��-yob R€3I� S l (- - LO!/ APPROVED BY /) 3&L 1 7 Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-403 Revised 11/2015 A rov d j0' I cot 4i 1 v id for 12 m nths from the date of approval. /Attachmen s in Duplicate .Pp ` VAI 1 �1 M /.2 7/7 .. 1.46/if ./.--.6 /'2-4' ./1 • • Well Prognosis Well: KBU 42-6Y Hilcon)Alaska,LL Date: 1/24/2017 Well Name: KBU 42-6Y ! API Number: 50-133-20634-00-00 Current Status: Gas Well Leg: N/A Estimated Start Date: February 7th, 2017 Rig: Eline Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-089 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: Current Bottom Hole Pressure: -793 psi @ 9,302' TVD (Based on static survey on 10/18/16) Max. Potential Surface Pressure: -3,041 psi (Based on expected formation pressure) Brief Well Summary KBU 42-6Y was drilled and completed in September 2014. It was initially completed in the Tyonek gas sands in the D-5. Hilcorp was unsuccessful in an economic gas show in the D-5, D-4, and D3C sands and was plugged back. The D-3B sand was perforated 12/5/14 where an economic gas show was found. This well is currently an active gas well. The purpose of this sundry is to add the D3A perforations. Notes Regarding Wellbore Condition • The well is currently on production at 4.2MMscfd at 342 psig with 2.5 bbl water/day. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. 2. RU 6 spf wireline guns. 3. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT Tyonek D3A ±10,083' ±10,101' 18' 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. Correlate using Correlation Log from Geologist. d. Use Gamma/CCU to correlate. e. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. f. All perforations in table above are located in the Tyonek Pool based on Conservation Order No. 510. 4. RD E-line. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic _ ..11 S • Kenai Gas Field Well: KBU 42-06Y SCHEMATIC PTD: 214-089 Hilcurp Alaska,LLC API: 50-133-20634-00 RKB:MSL=18.5' i ; CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 16" Conductor 109/X-56/Weld Surf 135' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,595' 16" 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,483' i a 5" Production 18/L-80/DWC/C-HT 4.276 Surf 10,892' a a ,J" 10-3/4" ,-.. `11 !,, igf p JEWELRY DETAIL No Depth Item ,. ' 1 6,006' 5"Swell Packer s r; ;' 2 9,425' RA Pup + s 3 9,631' RA Pup • 1 4 10,175' CIBP capped w/5'cmt J .it 5 10,199' RA Pup 6 10,270' CIBP capped w/cmt ' 7 10,360' CIBP capped w/cmt OPEN HOLE/CEMENT DETAIL ' 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface r,=, 7-5/8" 197BBL's of cement in 9-7/8"Hole.TOC 1,575'Calculated 5" 145BBL's of cement in 6-3/4"Hole. TOC 4,150'Calculated " PERFORATION DETAIL ei /' t Sands Top(MD) Btm(MD) Top(TVD) (TVD FT Date Status `N* a D-3B 10,132' 10,169' 9,268' 9,305' 37' 12/5/14 Open 7-5/8" ', '* D-3C 10,178' 10,198' 9,314' 9,334' 20' 11/03/14 Isolated z D-4 10,296' 10,313' 9,431' 9,448' 17' 09/07/14 Isolated V4 tio D-4 10,313' 10,333' 9,448' 9,468' 20' 09/07/14 Isolated 11 1 D-5 10,372' 10,380' 9,507' 9,515' 8' 09/02/14 Isolated D-5 10,380' 10,394' 9,515' 9,529' 14' 09/02/14 Isolated tt:i i 2 r .4 3 yr, t t 'Nt 10 44 '14 1 j 4 D38 TOF@10,250 '= 4 I Fish: CIBP milled and pushed to bottom w/WO RigJ "4s ,..`� 'ti 6 7il ilk r D4&5 5" 3Ate PBTD=10,805'MD/9,940'TVD TD=10,895'MD/10,029'TVD Updated by CAH 10/8/15 ell • Kenai Gas Field • Well: KBU 42-06Y PROPOSED SCHEMATIC PTD: 214-089 Hilcorp Alaska,LLC API: 50-133-20634-00 RKB:MSL=18.5' CASING DETAIL .� i Size Type Wt/Grade/Conn ID Top Btm 16" Conductor 109/X-56/Weld Surf 135' 16 t '��+ 10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,595' " 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,483' s 5" Production 18/L-80/DWC/C-HT 4.276 Surf 10,892' a 'h4' 4 41 10-3/4"sf s , 1,1 JEWELRY DETAIL li No Depth Item P 1 6,006' 5"Swell Packer 2 9,425' RA Pup o 3 9,631' RA Pup +44 10,175' CIBP capped w/5'cmt 5 10,199' RA Pup 6 10,270' CIBP capped w/cmt . r 7 10,360' CIBP capped w/cmt e, i 45 ,, OPEN HOLE/CEMENT DETAIL i.'4 i 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface k,i�, 7-5/8" 197BBL's of cement in 9-7/8"Hole.TOC 1,575'Calculated 1i 5" 145BBL's of cement in 6-3/4"Hole. TOC 4,150'Calculated /3 * 1 III PERFORATION DETAIL 7-5/8" Sands Top(MD) Btm(MD) Top(TVD) (ND) FT Date Status D-3A 10,083' 10,101' 9,134' 9,152' 18' Proposed D-3B 10,132' 10,169' 9,268' 9,305' 37' 12/5/14 Open D-3C 10,178' 10,198' 9,314' 9,334' 20' 11/03/14 Isolated • 2 D-4 10,296' 10,313' 9,431' 9,448' 17' 09/07/14 Isolated D-4 10,313' 10,333' 9,448' 9,468' 20' 09/07/14 Isolated ' D-5 10,372' 10,380' 9,507' 9,515' 8' 09/02/14 Isolated a 3 D-5 10,380' 10,394' 9,515' 9,529' 14' 09/02/14 Isolated i 1 a3a D-36 TOF@ :. 4 Fish: CIBP milled and pushed to bottom w/WO Rig 5 D3C .... . - . - 7)j- .; -r D-4&5 PBTD=10,805'MD/9,940'TVD TD=10,895'MD/10,029'TVD Updated byJEK 1-24-17 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 . - oFq Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RES AN: OVERSIZED: NOTES: Color Items: ❑ Maps: Gpirayscale Items: c7 ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: g a,'li S /s/ ne Project Proofing BY: Maria Date: 8 �,1 S /s/ vvjP V Scanning Preparation 5 x 30 = l 5V + as = TOTAL PAGES 1 7-5- (Count does not include cover sheet) BY: 4232bDate: dt a /s/ Production Scanning Stage 1 Page Count from Scanned File: !f 7( (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ✓YES NO BY: 44:13P Date: gig./ /ic- /s/ alp Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: a 11P NO TOTAL PAGES: Digital version appended by: Meredith...."—r\A-4Michal Date: 2,/2i 4s--- /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: a0(,9 Scanning is complete at this point unless rescanning is required. 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V O Davies, Stephen F (DOA) From: Luke Keller <Ikeller@hilcorp.com> Sent: Monday,July 27, 2015 10:30 AM To: Davies, Stephen F (DOA) Subject: RE: KBU 42-06Y (PTD #214-089) Confirm Surface, Productive Interval and Bottom-hole Location Coordinates Steve, We are definitely taking steps to make sure we have no typos or inconsistencies on these forms. We understand how important it is to have these 100% before they are submitted to the AOGCC. It is very frustrating that this one slipped through the cracks like this. Luke From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, July 27, 2015 10:16 AM To: Luke Keller Subject: RE: KBU 42-06Y (PTD #214-089) Confirm Surface, Productive Interval and Bottom-hole Location Coordinates Luke, No, your email is sufficient. I'll make the correction on the form. Thanks for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC From: Luke Keller [mailto:Ikeller@hilcorp.com] Sent: Monday, July 27, 2015 9:57 AM To: Davies, Stephen F (DOA) Cc: Cody Dinger - (C) Subject: RE: KBU 42-06Y (PTD #214-089) Confirm Surface, Productive Interval and Bottom-hole Location Coordinates Steve, You are 100% correct. This was a cut and paste error on the form. I apologize for that. Would you like for me to correct it and resend? The correct surface location for the KBU 42-06Y is: Surface: 83' FNL, 1009' FEL, S. 7,T4N, R11W, SM, AK 1 Davies, Stephen F (DOA) From: Luke Keller <Ikeller@hilcorp.com> Sent: Monday,July 27, 2015 9:57 AM To: Davies, Stephen F (DOA) Cc: Cody Dinger- (C) Subject: RE: KBU 42-06Y (PTD #214-089) Confirm Surface, Productive Interval and Bottom-hole Location Coordinates Steve, You are 100% correct. This was a cut and paste error on the form. I apologize for that. Would you like for me to correct it and resend? The correct surface location for the KBU 42-06Y is: Surface: 83' FNL, 1009' FEL, S. 7,T4N, R11W, SM, AK Luke From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, July 27, 2015 9:45 AM To: Luke Keller Subject: FW: KBU 42-06Y (PTD #214-089) Confirm Surface, Productive Interval and Bottom-hole Location Coordinates Hi Luke, Have you had the time to look into this request? 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. Sent from my desktop PC From: Davies, Stephen F (DOA) Sent: Friday, July 17, 2015 11:10 AM To: Ikeller@hilcorp.com Subject: KBU 42-06Y (PTD #214-089) Confirm Surface, Productive Interval and Bottom-hole Location Coordinates Luke, While reviewing the well history file for KBU 42-06Y, I noticed that the footage coordinates for the surface location presented in Box 4a of the Well Completion Report do not match those presented on the surveyor's as-built survey plat for the well. In all likelihood, this is a cut-and-paste error on the Well Completion Report, but I want to ensure that the well record is correct. 1 Surveyor's Plat Surface: 83' FNL, 1009' FEL, S. 7,T4N, R11W, SM Well Completion Report Surface: 30' FSL, 1053' FEL, Section 6, T4N, R11W, SM Productive Horizon: 10867' FNL, 102' FEL, Section 6,T4N, R11W, SM Total Depth: 1849' FNL, 38' FEL, Section 6,T4N, R11W, SM Could you please provide the correct footage coordinates for the Surface Location,Top of Productive Horizon, and Total Depth Location? Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 2 STATE OF ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION COMMIS—ON JAN 2 2 2015 • REPORT OF SUNDRY WELL OPERATIONS Otherd GCC 1.Operations Abandon URe air Well UPlu Perforations U Perforate U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other El Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 214-089 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20634-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEE A028142 Kenai Beluga Unit(KBU)42-06Y 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai-Beluga/Upper Tyonek Gas and Tyonek Gas Pool 11.Present Well Condition Summary: 10,175; Total Depth measured 10,895 feet Plugs measured 10,270; 10,360 feet true vertical 10,029 feet Junk measured —10,265(CIBP) feet Effective Depth measured 10,805 feet Packer measured 6,006 feet true vertical 9,940 feet true vertical 5,387 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16" 135' 135' Surface 1,595' 10-3/4" 1,595' 1,570' 5,210psi 2,470psi Intermediate 6,483' 7-5/8" 6,483' 5,801' 6,890psi 4,790psi Production 10,895' 5" 10,892' 10,026' 10,140psi 10,490psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) 5"Swell Pkr;N/A 6,006'MD 5,387'ND 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 64 Subsequent to operation: 0 10,019 4 0 1,507 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory El Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑✓ WDSPL❑ GSTOR El WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-569&314-626 Contact Paul Chan Email pchanOhiIcorp.com Printed ••kulift, A Paul Chan Title Sr.Operations Engineer f Signature . ' Phone 907-777-8333 Date (,1 3i S RBDMS� \ JAN 2 2 2015 Form 10-404 Revised 10/2012 ij �� Submit Original Only • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 42-06Y 50-133-20634-00 214-089 11/3/14 12/5/14 Daily Operations: 11/03/2014- Monday Obtain permit and MIRU Halliburton E-line. SITP 0 psi. MU lubricator and 5" CIBP to setting tool. Stab on well. PT lubricator w/well pressure-good test. RIH w/5" CIBP and correlate to SLB RST dated 8/27/14. Log correlation pass from 10,330'- 10,110' and send in for verification. Set CIBP @ 10,270' and confirm set w/tag. POOH w/setting tool. RD E-line and RU Halliburton slickline. MU lubricator and 3" bailer. Mix cement and stab on well. RIH and dump cement on plug @ 10,270'. POOH- bailer empty. Mix cement and RIH, dump cement on plug @ 101270'. POOH, bailer empty. Dumped 4.8 gals cement total (6'), estimated TOC 10,264'. Cement in place 11/3/14 @ 19:00. RD slickline, RU E-line. Spot Schlumberger N2 pumping equipment. RU SLB pumping unit and hard line. PT lines and pump 1,700 gals N2 in well to pressure up to 2,500 psi. MU lubricator and PT to 4,000 psi, good test. LD lubricator and MU 20' perf gun. Stab on well. RIH w/20'gun and correlate to previous correlation. Perforate Tyonek D-3C(10,178'-10,198')with 2-7/8" Connex 60 deg 6 SPF guns and 2,350 psi SITP. Positive indication of firing. POOH. No psi change after firing, built slowly in 15 min to 2,375 psi. Bled well down to 2,150 psi and built to 2,170 psi in 15 min. Bled well down to 1,900 psi and built to 2,000 psi in 30 min. Left shut in to monitor build up. OOH, all shots fired, guns wet and swollen. LD spent guns and lubricator. RD Halliburton E-line. 11/12/2014-Wednesday Arrive Location/sign in.Safety Meeting/ Permit to work. Spot unit and rig up. Pressure test 250 psi Low and 4,000 psi High - Good test. RIH w/5" Cast Iron Bridge Plug and setting tool. Log Correlation Passes. Send to Senior Operations Engineer and Discuss. Good to set_at 10,145'. Place plug on depth 10,145' and set CIBP. POOH. At surface with setting tool. MU 20'X 3" Dump Bailer and fill with 5 Gallons of Baker Class C cement(6.7'). RIH To CIBP at 10,145,'; Tag Plug 10,145' and Dump Cement. POOH. At surface. Secure well. RDMO. P .�- 11/17/2014- Monday Decision made to move Halliburton CTU to KGF 42-06Y. Roustabout crew at 41-7 pad laying pit liner and berming tank area. Vac truck round tripping from Beaver Creek to KGF with 3% KCL. Halliburton crew arrives. Spotting equipment. RIG up CTU. 11/18/2014-Tuesday Obtain PTW. JSA and safety meeting. Fuel equipment. Fire equipment, pick injector head and BOP stack. Flange up to wellhead. Fluid pack coil. Start BOP test. Low pressure test rams and valves to 250 psi. High pressure test to 4,500 psi. Finish BOP test. Witness waived by Jim Regg, AOGCC. Remove riser from BOPs. Make up MHA(coil connector, check valves, disconnect). All tools drifed prior to assembly. Pull test coil connector to 25K. Pressure test MHA to 250/4,500 psi. Make up motor and mill. Flange up to Wellhead. Pressure test connection break. 250/4,500 psi. Open well RIH. 2in coil with BHA consisting of the following: 1: coil connector 2.875" OD. 2: DF back pressure valve 2.875" OD. 3: Hydraulic disconnect 2.875" OD. 4: Dual Circ Sub 2.875" OD. 5: NOV Hi-Torque Motor 2.875" OD. 6: JZ rock bit. 3.625" OD. Hilcorp Alaska, LLC its Well Operations Summary + ,3 Well Name API Number Well Permit Number Start Date End Date KBU 42-06Y 50-133-20634-00 214-089 11/3/14 12/5/14 Daily Operations: Complete BHA length 18.45ft. Well is full of fluid returns at surface 100ft in hole. Come online with fluid 1.75 bbls min @ 5,900 ft. Tagged @ 10,121 ft CTMD. RIH weight 25K. Pick up weight 42k. Clean pick up 15 ft off tag. Increase fluid rate to 2.25 bbls/min. RIH start milling. 1645 saw 5001bs of motor work then stall. Clean, pick up weight of 42k. Circulating pressure leveled out RIH to mill. 1653. 10,123 ft Stall. From 10,121' first tag to 10,123' second tag. Believed to be through the 6.6 ft of cement that was dump bailed on CIBP. 1659 Milling at 10,123 ft. Stall. Down on pump to pick up. Over pull on Coil 70K. 28,000 lb over pull. Coiled tubing Tension limit is 88,570 lbs without dynamics of fluid movement. Coiled tubing traction pressure maxed out. Chains slipping consistently between 60-70k on weight indicator. Coiled tubing stuck. Still have circulation. Believed to be bit stuck on CIBP. Increased pump rate to 2.5 bbls min. Circulating pressure 4,200 psi. Send 10 bbl gel sweep for safe measure. Attempt to free Bit. Stack weight then come online with pump. Push and pull coil without pumping. Run coil in and out as fast as possible while pumping and without pumping. Cavitate pump will POOH and RIH. Called town and discuss option. Halliburton called management and tool hand. Continue attempts to free coiLDecision made to drop 7/8" ball to disconnect. Drop ball in launcher. Pressure up back side of reel valve to 4,000 psi. Launch ball. Audible confirmation that ball is rolling in reel. 33 bbl coil volume. Ball on seat. Pressure 4,000 psi. Holding. Increase pressure to 4,800 psi. Disconnect shear pins. POOH 49K weight to pop out of disconnect profile. No bobbles in weight while pulling. Continue circulating OOH. 11/19/2014-Wednesday Communicate with town on which direction to go. Decision made to run Baker 3-1/8" MHA,jars, accelerators and 3in GS. Halliburton crew enroute to location. Obtain Permit to work and Hold JSA. Rig up Halliburton CTU. Make up Baker 3-1/8" coil connector, back pressure valves, Accelerators,Jars, hydraulic disconnect, circ sub. Pressure test low pt 250 high pt 3,500. All tools drifted with disco ball and circ sub ball. Boths balls landed on each seat. On well flanging up. Hydraulic leak on BOPE hose. Crews tightened hose. Pressure test stack low 250/ high 4,500. Well open RIH, perform weight checks every 3,000 ft. Stopped coil at 10,100 ft. RIH weight is 21K. Up weight prior to latching in 45K. Performed two weight checks f�vC prior to stacking weight on fish. Saw first weight stack on fish at 10,112 ft CTMD. Set down 5k. Jars fired down. Same r, results on all jar licks. UP hole Jar licks 45K up weight to 75K . 30K overpull. Took jars three minutes to fire on each up lick. At surface saw 10K jump on weight indicator each time. All up jar licks were at depth 10,113 ft after pipe stretch. No movement seen. Down jar licks . RIH wt 24K Stacked to 0. 24K down each down lick. Weight would break back to 10K. At surface saw 10K lick. No down movement. Total Up jar licks = 25. Total down Jar Licks = 15. Complete jar licks for fishing 40. Halliburton service lead was starting to get concerned with coil life at depth of stuck fish. Coiled tubing was nearing its 80% life limit. Decison made to disengage GS spear from fishing neck. Stacked down 10K weight and brought pump online at 2.5 bbls/min. Pick up off fishing profile and POOH. Up weight 48K. At surface. Swab and master closed. Breaking down tools. Inspected GS spear. Did not see anything out of the ordinary. Back on well. N2 cooled down. Blowing down coil to open top tank. Low pressure hoses blown back to tank. C pumps and fluid end freeze protected. Bleeding down N2. Stacking down equipment. Install night cap on tree. Crews off location. No luck retrieving fish. Description of fish left in hole. 1. nov high torque motor . 2.875" OD. 12.85ft long. 1.JZ rock bit. 3.625" Od .94 Ft long. Fishing neck. Internal 3 in GS profile. Need 3in Reg GS to latch into fishing profile. • ti Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 42-06Y 50-133-20634-00 214-089 11/3/14 12/5/14 Daily Operations: 11/20/2014-Thursday Mob M401 from Swanson River. /2-t - (y -- 11/21/2014- Friday Held JSA, Discussed PPE and loader safety operations with Crew. Laid containment (100'x 75'). Spotted the support bean and M401. Raised the derrick and secured the guide lines. ND flowline and 5" tree, leaving the bottom Master in place/ NU the adapter spool (5-1/8" 10m to 7-1/6" 5m),Tbg Head (2-1/16" outlets), double gate rams and annular. Continued spotting equipment with Weaver Bro's support. 11/22/2014-Saturday Finish RU BOP and accumulator lines. RU rig floor and winterizing. Fill pits w/ KCL and perform BOP function and shell test. Troubleshoot issues with PT pump. MU test joint. Perform BOP test as follows to 250 psi low and 3,500 psi high: 2-7/8" pipe rams, annular, blinds, HCR, choke, and kill manifold valves, TIW, safety valve, and Kelly valve. Performed accumulator drawdown test. All passed except Kelly valve - replaced XO and passed. Rack and tally BHA and work string. Jim Regg waived witness 11/20/14 @ 18:35. Shut down for night. 11/23/2014-Sunday Obtained permit and held PJSM. Open well to check for pressure -troubleshoot accumulator issues. No pressure on well. MU fishing BHA as follows: 3-5/8" overshot w/2-7/8" grapple, bumper jar, oil jar, (4) 3-1/8" spiral DC's, and accelerator jar. Total length: 145.63'. RIH w/overshot and PU 2-7/8" 7.9# PH6 work string. RIH to"'8,000'. Shut down for night. 11/24/2014- Monday Held PJSM and obtained permit. Continue RIH w/overshot BHA on 2-7/8" 7.9# PH6 work string, picking up singles from '"8,000'-10,080'. RU power swivel. Stiff arm too long for power swivel. Wait on shorter stiff arm. Finish RU power swivel. Troubleshoot pump issues. Break circulation @ 2 BPM and 1,100 psi, final pressure 600 psi after bottoms up. Wash down to top of fish and tag @ 10,130'. Set down 2K lbs w/pressure increase and saw small overpull on pickup. Set down w/ increasing weight and rotation seeing pressure increase but no overpull. Continue several times with no change. Decision to POOH and check fish. Chain back power swivel and LD 2 singles. Secure well for night. Shut down for night. 11/25/2014-Tuesday Held PJSM and obtained permit. Continue POOH from 10,080'-1,000' and missing overshot BHA and 28 joints of 2-7/8" 7.9# PH6 work string left in hole. Pin shows no signs of damage. Decision to run cut-lip screw in sub and attempt to screw into fish. Wait on sub. MU cut-lip screw in sub (2-7/8" PH6)to work string. Work on power tongs. RIH w/work string checking torque on connections to TOF. Secure well and shut down for night. 11/26/2014-Wednesday Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 42-06Y 50-133-20634-00 214-089 11/3/14 12/5/14 Daily Operations: Held PJSM and obtained permit. Troubleshoot frozen air lines on rig. Rig up power swivel, troubleshoot pump issues. Wash down to TOF @ 9,131'. Set down on TOF and screw in. PU and engaged fish, set down and rotate seeing 3,200 ft-lbs torque. PU 100K lbs (22K lbs over full string weight) and came free. Troubleshoot air hoist issues. LD single and chain back power swivel. LD single and pulling wet. RU mud bucket. POOH w/ potential fish. Recovered work string fish. Little sign of damaged threads on box end. LD joint and continue POOH. Recovered CT fish- hydraulic disconnect, circulating sub, mud motor, and bit. Nothing missing. LD fish and overshot BHA.'Secure well and shut down for night. 11/27/2014-Thursday Held PJSM and obtained permit. Clear plugged off DC's and jars. MU milling BHA as follows: 3.875" Piranha mill, bit sub, oil jar, (4) 3-1/8" spiral DC's, and accelerator jar. RIH. Thaw Kelly hose, trouble getting pump started. Fill hole and break circulation through BHA to ensure clear. Thaw ice plugs in work string. RIH w/ milling assembly on 2-7/8" 7.9# PH6 work string. Check connection torque on first 14 stands. Pick up singles and tag CIBP @ 10,145'. LD single. RU power swivel and prep for milling. Secure well and shut down for night. 11/28/2014- Friday Held PJSM and obtained permit. Thaw power swivel. RU power swivel. Add second dead line to rig. Thaw frozen lines and stack. Mill CIBP @10,145', 2K lbs WOB, 4K ft-lbs torque, 2 BPM @ 900 psi. Made about 12" of progress. Circulate bottoms up, LD power swivel. Secure well. Shut down for night. 11/29/2014-Saturday Held PJSM and obtained permit. RU power swivel. Controls not working properly. Work on power swivel. Mill on CIBP @ 10,145'. Circulating rubber leaking. Circulate bottoms up and replace circulating rubber. Mill on CIBP, string kept plugging off. Switch between reverse and regular circulation when plugging. Mill through CIBP. Circulate 2x bottoms up reverse circulating. LD pup joints and chase CIBP to bottom,tag @ 10,250'. RD power swivel and LD 6 joints of pipe. Secure well. Shut down for night. 11/30/2014-Sunday Held PJSM and obtained permit. POOH and LD 2-7/8" 7.9# PH6 workstring. LD milling BHA. Mill badly worn and partially plugged off. Secure well. RD floor, pump lines, prep to ND BOP. Shut down for night. 12/01/2014- Monday Held PJSM and obtained permit. ND BOP and NU tree and flowline. RD rig, mud pits, choke house, accumulator, generator, berms, hoses and lines. Stage equipment on edge of location and begin RDMO to Beaver Creek. Clean location. 12/02/2014-Tuesday Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 42-06Y 50-133-20634-00 214-089 11/3/14 12/5/14 Daily Operations: Obtained permit and RU slickline. MU lubricator and tool string, stab on well. PT lubricator to 250 psi low/3500 psi high- tighten tree cap flange, good test. RIH w/3.895" GR and tag bottom @ 10,294' WLM RKB. POOH- no issues. RD slickline. Wait on Pollard. Obtained permit and RU E-line. MU lubricator and tool string, stab on well. PT lubricator, replace o-ring. PT pump went down. Wait on PT pump. PT lubricator to 250 psi low/3500 psi high-good test. RIH w/5" CIBP and correlate to SLB RST dated 8/27/14. Send correlation in for verification. Set CIBP@ 10,175'and POOH. LD setting tool and MU 3" bailer. Mix 3 gals cement (4') and pour in bailer. RIH w/bailer and dump 4' cement on CIBP @ 10,175'. Estimated TOC: 10,171'. POOH w/bailer and LD. LD lubricator and secure well. RD Pollard. 12/03/2014-Wednesday Hold Safety meeting with Halliburton Slick line. Discussed rigging up unit on back side of well to allow SLB coiled tubing unit to rig up on opposite side while slick line performs intervention. Slick line rigged up with sample bailer . RIH, estimated fluid level at 200 ft. Tag Top of cement 10,212' SLMD. POOH rig down move out. Slb spotting up on pit liner. Rigging up SLB CTU 12. Fluid pack unit with methanol. Pressure Test BOPS low pt 250 psi/high pt 4,500 psi. 12/04/2014-Thursday Obtain PTW. Hold safety meeting and review JSA. Start equipment. Pick up injector head, make lubricator and BHA. Coil connector 2in stinger, DFCV, 2in ball drop nozzle. Stab onto well and secure injector head. Transfer Nitrogen into pump holding tank. Fluid pack reel with field Triplex pump. Shell pressure test, low pt 265 psi/ high pt 4,500 psi. Bleed down. Open master swab valve, RIH performing weight checks every 3,000 ft. Cooling down n2 pump. Online with n2 at 1,000 scf/min. CT depth 6,500 ft. RIH 85 ft/min. Tagged top of cement at 10,120 ft CTMD. Picked up 5 ft from tag. Parked at depth lifting fluid. Increase N2 rate 1,600 scf/min. Well blown dry. 20 minute visual confirmation at tank. All returns nitrogen. Tank strapped and total fluid recovered from well was 174 bbls. Vac truck transporting wellbore returns to G&I facility. Start POOH, swap nitrogen down back side to pressurize well while pulling out of hole. At surface 1,600. Wellhead pressure when shut in was 2510 psi. Swab and Master closed. Bled down remaining coil tubing pressure. Total n2 pumped = 305,000 scf or 3,275 gallons. Rigged down CTU 12. Tree cap installed and opened up to well for verification that Flange x bowen connection tight with no leaks. Wellhead closed back in. CTU crew staged equipment off to edge of pad. Pit liner, light plant remain for wire line perforating operation. Rain for Rent contacted to demobe 500 bbl diffuser tank from location. Location secure. PTW closed. Crews off location 1900 hrs. 12/05/2014- Friday PTW and JSA. Mobe to location spot equip and rig up eline. Arm gun. PT equipment from 250 psi low and 4,000 psi high. 2,420 psi of N2 on well. RIH w/2-7/8" x 20' Connex HC, 6 spf. 60 deg phase and tie into SLB RST log dated 24-Aug-14.Tag cement at 10,170'. Run correlation log and send to town. Get ok to perf. Spot guns from 10,169'to 10,149'.TP-2,420 psi. Fired gun and pressure went to 2,450 psi. POOH. Gun had a little fluid in bull plug but could of been from fluid in well. RIH w /2-7/8" x 20' Connex HC, 6 spf. 60 deg phase and tie into SLB RST log dated 24-Aug-14. Spot guns from 10,132' to 10,148'. TP- 2,430 psi. Fired gun and no psi change. POOH,guns were same as first run. Rig down lubricator and turn well over to field. TP-2,430 psi. Kenai Gas Field Well: KBU 42-06Y r SCHEMATIC PTD: 214-089 Hilcorp Alaska,LLC API: 50-133-20634-00 RKB:MSL=18.5' 1 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm t' P16" Conductor 109/X-56/Weld Surf 135' i,410-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,595' 16' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,483' a 5" Production 18/L-80/DWC/C-HT 4.276 Surf 10,892' t r' a, a ' JEWELRY DETAIL 10-3/4" - I !' No Depth Item 1 6,006' 5"Swell Packer 1 2 9,425' RA Pup 3 9,631' RA Pup 4 10,175' CIBP capped w/cmt o 5 10,199' RA Pup kt 6 10,270' CIBP capped w/cmt L 7 10,360' CIBP capped w/cmt k w OPEN HOLE/CEMENT DETAIL 'R 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface 7-5/8" 197BBL's of cement in 9-7/8"Hole.TOC 1,575'Calculated }" " 5" 145BBL's of cement in 6-3/4"Hole. TOC 4,150'Calculated m y , PERFORATION DETAIL t t Sands Top(MD) Btm(MD) Top(TVD) Btm FT Date Status (TVD) D-3B 10,132' 10,148' 9,268' 9,284' 16 12/05/14 Open 7_5/8" z .M C. D-3B 10,149' 10,169' 9,285' 9,305' 20 12/05/14 Open '� D-3C 10,178' 10,198' 9,314' 9,334' 20 11/03/14 Isolated iK i D-4 10,296' 10,313' 9,431' 9,448' 17 09/07/14 Isolated IN D-4 10,313' 10,333' 9,448' 9,468' 20 09/07/14 Isolated D-5 10,372' 10,380' _ 9,507' 9,515' 8 09/02/14 Isolated 7'` D-5 10,380' 10,394' 9,515' 9,529' 14 09/02/14 Isolated 0 0 2 4 r tete 1 P. �3 y', Ft ' TOF(CIBP) t` . D-38 1" C 41'4--)�Z') 10,265' ,a' ` /,,',.4 1 017 c Z 5 - V, ;;6v 7k D4&5 • 4 ' PBTD=10,805'MD/9,940'ND 1D=10,895'MD/10,029'TVD Updated by DMA 01-22-15 �• _,\\��%%j�, THE ST"ME Alafrx and, CO Et'EervaCii 11 CemniTf;Eferl 47''',-,zia _-::-7.7-_--- ---.--;-.(A ' oft 1 P\ CilliA ViT- --'-'-=---2 I3 G — — -- --— 333 West Seventh Avenue " GOVERNOR SEAN FAIZNELh Anchorage, Alaska 99501-3572 'r' — Main. 907.279 1433 ALAS 5" Fax. 907.276.7542 Paul Chan Senior Operation Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Field, Beluga/Upper Tyonek and Tyonek Gas Pools, KBU 42-06Y Sundry Number: 314-626 Dear Mr. Chan: 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, f-77e—t-oV-c,_ Cathy P. oerster Chair DATED this�day of November, 2014. Encl. RECEIVED + STATE OF ALASKA N0\/ 2 d 2014 . ALASKA OIL AND GAS CONSERVATION COMMISSION 0,51- ��,� APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool 0 Repair Well❑✓ ' Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate 0 Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number. Exploratory ❑ Development ❑✓ . 214-089 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20634-00 ' 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.510A ' Kenai Beulga Unit(KBU)42-06Y ' Will planned perforations require a spacing exception? Yes 0 No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEE A028142 • Kenai/Beluga/Upper Tyonek Gas and Tyonek Gas Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,895 • 10,029• 10,805 9,940 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16" 135' 135' Surface 1,595' 10-3/4" 1,595' 1,570' 5,210psi 2,470psi Intermediate 6,483' 7-5/8" 6,483' 5,801' 6,890psi 4,790psi Production 10,895' 5" 10,892' 10,026' 10,140psi 10,490psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: . Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/21/14 Oil 0 Gas Q WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: ((-Z(r-/'Y WINJ ❑ GINJ ❑ WAG 0 Abandoned 0 Commission Representative: C c5 a,,f-L GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and rrect to the best of my knowledge. Contact Paul Chan Phone: 907-777-8333 1-0Es Email pchanahilcorp.com Printed Name Paul Chan 'RIC eit•c .i1.- (:lkNU Title Senior Operations Engineer Signature Zr r= Phone 907-777-8333 Date i)2,�'(�`�r N COMMISSION USE ONLY Conditions of appro al: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 12/ MechanicalicIntegrity Test 0 Location Clearance 0 Other 74-45�Oc /S1 O°/4° /e--3(-- ( ( st' J ys s - c,) Spacing Exception Required? Yes ❑ No g Subsequent Form Required: /6 —di D 4( 6147 APPROVED BY Approved by: %��/if.......__ COMMISSIONER THE COMMISSION Date://-� - /V I��2('!�1 n Anr A Submit Form and Form 1n.dn3(Ralik 7N9f11 O1 O e Ihf1 n valid fru.12 mnnfhc from Mei dafn M annrnvnl ...__�-__._._...._,.__._ Well Prognosis • Well: KBU 42-06Y • AFE: 1411969C Ililcorp Alaska,LL Well Name: KBU 42-06Y API Number: 50-133-20634-00-00 Current Status: CIBP set over Tyonek D3-C Leg: N/A Sands with Fish in Hole Estimated Start Date: 11/21/2014 Rig: Moncla 401 Reg.Approval Req'd? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-0890 First Call Engineer: Paul Chan (907)777-8333 (0) (907) 345-3161 (H) (907)444-2881 (C) Second Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (C) Estimated Bottom Hole Pressure: —4,279 psi at 9,110' TVD (Assumed 0.45 psi/ft gradient) Max.Anticipated Surface Pressure: —3,453 psi (0.075 psi/ft gas gradient) Brief Well Summary: KBU 42-06Y was drilled and cased/cemented in August 2014. The Tyonek D-5, D-4, and D3-C sands have been perforated but are non-commercial/wet. A CIBP was set and capped with cement to isolate the D3-C sands from the proposed Tyonek D3-B sands. Unfortunately, the CIBP as set too high. CTU was mobilized to drill out the CIPB so that another CIBP could be set at the proper depth. During the CTU operations,the motor and bit became stuck while attempting to mill the CIBP. An attempt was made to fish the stuck BHA with jars and accelerators without any success. The Moncla 401 pulling unit is required to fish the stuck BHA so as to be able to access the Tyonek D3-B sands. RWO Objective: Fish motor and bit. Drill out CIBP in preparation for setting new CIBP post-rig. ✓ RWO Procedure: 1. MIRU Moncla#401 WO Rig. 2. Confirm well is dead. Set TWC. ND tree and adapter flange. 3. NU BOPE with 2-7/8" pipe rams in the upper ram cavity. Test to 250 psi low/r3.0gjasihigh. Record accumulator pre-charge pressures and chart tests. Notify AOGCC 24 hours prior to testing at http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html 4. Pull TWC with lubricator. 5. PU fishing BHA consisting of jars, accelerator and 3" GS on 2-7/8" EUE 8rd workstring. 6. RIH to top of fish. 7. Engage fish and jar free. 8. POOH and LD fish. 9. PU -4" OD concave/flat bottom mill and RIH on 2-7/8" workstring. 10. Drill out CIBP and push to top of CIBP at 10,270' MD. 11. POOH and lay down workstring. 12. Set TWC. ND BOPE. NU adapter flange and tree. PT tree. RU lubricator and pull TWC. 13. RD Moncla#401 WO Rig. E-Line 1. MIRU e-line and PT lubricator to 250 psi low/3,500 psi high. 2. PU 5" CIBP and set at 10,174' MD and cap with 4'of cement. Well Prognosis • Well: KBU 42-06Y AFE: 1411969C Hilcorp Alaska,LL 3. POOH and RDMO Coiled Tubing Blow Well Dry with N2 Procedure 1. MIRU Coiled Tubing Unit and tanks as needed. 2. NU BOP stack on tree and function test BOP's 3. Shell test BOPE/lubricator to 250psi low/4,500psi high(unless due for weekly BOPE test—then a full BOPE test will be done). Notify AOGCC 24 hrs in advance of BOPE test at http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html 4. Fill coil and perform Shell Test on all treatment lines and equipment with 6% KCI brine (500 psi low test and 4500 psi high test). 5. RIH and blow well dry with N2 to maximum depth. Leave 2400 psi N2 on the well. 6. POOH and RD CTU. Perforating the remaining Tyonek D3 and D2 sands will be performed under the approved Sundry 314-569. ' Attachments: 1. Actual Schematic 2. Proposed Schematic 3. CT BOPE Schematic Kenai Gas Field fir Well: KBU 42-06Y CURRENT PTD: 214-089 Moan)Alaska,LLC API: 50-133-20634-00 RKB:MSL=18.5' CASING DETAIL #� Size Type Wt/Grade/Conn ID Top Btm 16" Conductor 109/X-56/Weld Surf _ 135' 16" r 10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,595' a 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,483' % r 5" Production 18/L-80/DWC/C-HT 4.276 Surf 10,892' a a! 10-3/4" d JEWELRY DETAIL '" No Depth Item 1 6,006' 5"Swell Packer 14 1 2 9,425' RA Pup I. R` 3 9,631' RA Pup v 4 10,145' CIBP capped w/cmt isr 5 10,199' RA Pup P 4 '. 4t 6 10,270' CIBP n 7 10,360' CIBP capped w/cmt d r 1-44 - r OPEN HOLE/CEMENT DETAIL 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface 7-5/8" 197BBL's of cement in 9-7/8"Hole.TOC 1,575'Calculated a ` C 5" 145BBL's of cement in 6-3/4"Hole. TOC 4,150'Calculated i ; N; V. 4 PERFORATION DETAIL di • 4i t Sands Top(MD) Btm(MD) Top(ND) (TVD) FT Date Status D-3C 10,178' 10,198' 9,314' 9,334' 20' 11/03/14 Isolated 7-5/8" '� D-4 10,296' 10,313' 9,431' 9,448' 17' 09/07/14 Isolated I,' ' D-4 10,313' 10,333' 9,448' 9,468' 20' 09/07/14 Isolated e 1. 1; 4D-5 10,372' 10,380' 9,507' 9,515' 8' 09/02/14 Isolated i 1 1 'A D-5 10,380' 10,394' 9,515' 9,529' 14' 09/02/14 Isolated .' isitt 2 0 013 Y'4 1, ,I TOF @10,112' 101 3. r, 4 d _ 5 D-3 til •- 1' s• 7t - ' - -_• D-4&5 5" 44:. PBTD=10,805'MD/9,940'1VD TD=10,895'MD/10,029'TVD Updated by DMA 11-20-14 Kenai Gas Field .11 Well: KBU 42-06Y PROPOSED PTD: 214-089 !Warp Alaska,1.,1,11: API: 50-133-20634-00 RKB:MSL=18.5' CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm . [ 16" Conductor 109/X-56/Weld Surf 135' 16" 10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,595' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,483' 5" Production 18/L-80/DWC/C-HT 4.276 Surf 10,892' JEWELRY DETAIL 10-3/4" + 14 No Depth Item 1 6,006' 5"Swell Packer 2 9,425' RA Pup 3 9,631' RA Pup 4 10,199' RA Pup 5 10,270' CIBP capped w/cmt 6 10,360' CIBP capped w/cmt OPEN HOLE/CEMENT DETAIL 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface 7-5/8" 197BBL's of cement in 9-7/8"Hole.TOC 1,575'Calculated 5" 145BBL's of cement in 6-3/4"Hole. TOC 4,150'Calculated ,i r PERFORATION DETAIL Btm g g 1 Sands Top(MD) Btm(MD) Top(TVD) (gip) FT Date Status • D-3C 10,178' 10,198' 9,314' 9,334' 20' 11/03/14 Isolated 7-5/8" A 1► D-4 10,296' 10,313' 9,431' 9,448' 17' 09/07/14 Isolated D-4 10,313' 10,333' 9,448' 9,468' 20' 09/07/14 Isolated D-5 10,372' 10,380' 9,507' 9,515' 8' 09/02/14 Isolated D-5 10,380' 10,394' 9,515' 9,529' 14' 09/02/14 Isolated a 2 3 3 4 5 D-3 f 6 D-4&5 r PBTD=10,805'MD/9,940'1VD TD=10,895'MD/10,029'1VD Updated by DMA 11-20-14 Swanson River 2014 Moncla Rig 401 Ilsk„rp Knight Oil Tools BOP O • I lil 1 til I I I 2.57' Shaffer 71/16 5000 t li 1ffilft�tt TNIPM I11 I11 !fl If! III /- _ 2 3/8-3Y2 variable I CAMERON 3.68' - H a - - : li. Blind '�� -� 71/16 500000 li111 111111 111 2 1/16 10M Kill Valves 2 1/16 10M Choke Valves Manual and HCR Manual and HCR .1 ; 1 1.1lI 111 1!1 111 . • 1.56 ,E s �, , 71/16 5000 r i II2. I It? 11111'110l � '��W'/ • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, November 21, 2014 10:06 AM To: 'Chad Helgeson'; Regg,James B (DOA) Cc: Wade Hudgens- (C); Paul Chan;James Ostroot- (C); Donna Ambruz Subject: RE: KGF KBU 42-06Y Sundry(PTD#214-089) Chad, I have reviewed your submitted sundry. No issues with procedure. You have verbal approval to move onto well KBU 42-06Y and perform fishing operations as proposed with Moncla 401. 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: Chad Helgeson [mailto:chelgeson@ahilcorp.com] Sent: Friday, November 21, 2014 6:27 AM To: Schwartz, Guy L(DOA); Regg, James B (DOA) Cc: Wade Hudgens - (C); Paul Chan; James Ostroot- (C); Donna Ambruz Subject: KGF KBU 42-06Y Sundry(PTD# 214-089) Guy, Attached is the sundry and procedure we talked about yesterday. The hard copies were delivered late yesterday afternoon to your office. The summary of this job is we got a coil tubing BHA stuck trying to drill up a cast iron bridge plug. We want to use the Moncla#401 rig on the well to fish the BHA and then drill up the bridge plug. We are mobilizing the rig on the well today and we will be submitting 24hr BOP Test notification to Jim. We won't proceed with testing anything until we receive your approval for this work. If you have any questions on this, please give Paul Chan (777-8333)or myself(777-8405)a call. Sorry for the last minute request and appreciate your help. We are hoping to lay down the Moncla#401 for a while after this job. (as long as nothing breaks before we lay them down.) Thanks Chad Helgeson ; 2Nk - ' 6.w 1%y ,, , THE STATE ,A,.1�zEl e, C� .I. Tlid ��..0 ,tom —^1f�,v,1 '_I 1' ,' .., �� low- ,' , - - -- -- - --- -- - ---- - , s} ;,-_ 333 West Seventh Avenue k..r:.: -.! .. Gov1-.RNt;R S1:,NN PAR\1 L Anchorage Alaska 99501-3572 op 'a,n 907 2;/9 1423 -41, Paul Chan Senior Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Field, Beluga/Upper Tyonek Gas and Tyonek Gas Pool, KBU 42-06Y Sundry Number: 314-569 Dear Mr. Chan: 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, A 719-7??..e.„,i----,— Cathy P. Foerster Chair DATED this Z day of October, 2014. Encl. -. ECEWED STATE OF ALASKA OCT2 1 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION -S )0 I 3-ii( / DUIA APPLICATION FOR SUNDRY APPROVALS 10I AOGCC 20 AAC 25.280 1.Type of Request. Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Change Approved Program 0 Suspend❑ Plug Perforations ❑ Perforate Q . Pull Tubing❑ Time Extension❑ Operations Shutdown 0 Re-enter Susp.Wel ❑ Stimulate ❑ Alter Casing 0 Other. 0 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development Q . 214-089 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20634-00- 7. If perforating: 6-7,e-j 570/q 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool?�V /at..z.34N / J Kenai Beulga Unit(KBU)42-06Y - Will planned perforations require a spacing exception? Yes b No ❑� 9.Property Designation(Lease Number): 10.Field/Pool(s): FEE A028142 Kenai/Beluga/Upper Tyonek Gas and Tyonek Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured). 10,895 10,029 10,805 9,940 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16" 135' 135' Surface 1,595' 10-3/4" 1,595' 1,570' 5,210psi 2,470psi Intermediate 6,483' 7-5/8" 6,483' 5,801' 6,890psi 4,790psi Production 10,895' 5" 10,892' 10,026' 10,140psi 10,490psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade: Tubing MD(ft). See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A;N/A N/A;N/A 12.Attachments. Description Summary of Proposal Q 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: 10/31/14 Commencing Operations: Oil 0 Gas Q. WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ 0 WAG 0 Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing i e and correct to the best of my knowledge. Contact Paul Chan Phone: 907-777-8333 Email pchan(pilcorp.com Printed N.• e 'GL tan Title Senior Operations Engineer Signature ii, , Phone 907-777-8333 Date 10/21/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:_ \L&^ 6^(\ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance 0 1= �- Other: Spacing Exception Required? Yes ❑ No [i Subsequent Form Required: 1 c; — y0 Li p APPROVED BY `I Approved by(' 9 y COMMISSIONER THE COMMISSION Date:/U -� -/y 1' G7 1 Submit Form and Form 10-403(R sed 10/ 1 A v ddpVtit faH fL 2 months from the date oproval. Attachments in Duplicate NOV - 6 �„. `- 79M .2& /je, zs./V Well Prognosis Well: KBU 42-06Y Hilcorp Alaska,LU Well Name: _ KBU 42-06Y API Number: 50-133-20634-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 10/31/2014 Rig: N/A Reg.Approval Req'd? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-089 First Call Engineer: Paul Chan (907)777-8333 (0) (907) 345-3161 (H) (907)444-2881 (C) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228(C) Estimated Bottom Hole Pressure: —4,279 psi at 9,110' ND (Assumed 0.45 psi/ft gradient) Max.Anticipated Surface Pressure: —3,453 psi (0.075 psi/ft gas gradient) Brief Well Summary: KBU 42-06Y was drilled and cased/cemented in August 2014. The Tyonek D-5 perforated interval is below a CIBP. The Tyonek D-4 sands are perforated. Objective: • Ad perforations in the Tyonek D sands E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/4,000 psi high. Note that the well is pressurized with nitrogen. 2. If necessary, bleed nitrogen pressure down as requested by the RE to establish a drawdown on the formation. RA markers are at 9,425', 9,631', 10,199' MD as per the Casing and Cementing Report dated 8/20/2014. 3. Perforate the Tyonek D sands with 2-7/8" 6 SPF 60 deg phased GEODynamics Connex gun. Depths are from the Schlumberger RST/GR/CCL run August 27, 2014. Send the correlation pass to Paul Chan and Jacob Dunston for confirmation. Gross Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Tyonek D-3 ± 10,045' ± 10,330' ±285' Tyonek D-2 ±9,810' ± 10,325' ±515' 4. POOH. 5. Flow well through test separator and record water and gas rates 6. If any of the Tyonek D sands are not commercial,then the zone will be patched if there are productive intervals below 7. RD e-line. 8. Turn well over to production. Attachments:As-built Well Schematic and Proposed Well Schematic Kenai Gas Field Well: KBU 42-06Y 14 SCHEMATIC PTD: 214-089 liilcnrp Alaska,LLC API: 50-133-20634-00 RKB:MSL=18.5' I. CASING DETAIL Size Typeil Wt/Grade/Conn ID Top Btm V16" Conductor 109/X-56/Weld Surf 135' F. y 10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,595' 16" 4 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,483' L. ; 5" Production 18/L-80/DWC/C-HT 4.276 Surf 10,892' I (+ 1 10-3/4"4 JEWELRY DETAIL x ,+ No Depth Item P it h 1 6,006' 5"Swell Packer I 2 9,425' RA Pup II 3 9,631' RA Pup F 4 10,199' RA Pup 1" 5 10,360' CIBP OPEN HOLE/CEMENT DETAIL t" 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface r - 7-5/8" 197BBL's of cement in 9-7/8"Hole.TOC 1,575'Calculated 5" 145BBL's of cement in 6-3/4"Hole. TOC 4,150'Calculated ,f PERFORATION DETAIL w Btm Sands Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status t. 4 10,296' 10,313' 9,431' 9,448' 17' 09/07/14 Open D-4 10,313' 10,333' 9,448' 9,468' 20' 09/07/14 Open r` 10,372' 10,380' 9,507' 9,515' 8' 09/02/14 Isolated D-5 10,380' 10,394' 9,515' 9,529' 14' 09/02/14 Isolated o: 8 1 p" 7-5/8" + +z.� n y :a Y I ."i 3 4 dit k TOC@10,354 4` 4t _, 5" +' PBTD=10,805'MD/9,940'TVD TD=10,895'MD/10,029'TVD Updated by DMA 09-30-14 Kenai Gas Field Well: KBU 42-06Y PROPOSED PTD: 214-089 Hilcorp Alaska,LLC API: 50-133-20634-00 RKB:MSL=18.5' • CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 16" Conductor 109/X-56/Weld Surf 135' 16" 10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,595' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,483' s 5" Production 18/L-80/DWC/C-HT 4.276 Surf 10,892' JEWELRY DETAIL 10-3/4" i i - No Depth Item g 1 6,006' 5"Swell Packer 2 9,425' RA Pup 3 9,631' RA Pup 4 10,199' RA Pup 5 10,360' CIBP OPEN HOLE/CEMENT DETAIL 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface . 7-5/8" 197BBL's of cement in 9-7/8"Hole.TOC 1,575'Calculated '' 5" 145BBL's of cement in 6-3/4"Hole. TOC 4,150'Calculated r PERFORATION DETAIL :,' Sands Top(MD) Btm(MD) Top(ND) (rvp) FT Date Status }0D-2 ±10,045' ± 10,330' ±9,181' ±9,465' ±285' Future Proposed D-3 ±9,810' ±10,325' ±8,947' ±9,460' ±515' Future Proposed 10,296' 10,313' 9,431' 9,448' 17' 09/07/14 Open D-4 10,313' 10,333' 9,448' 9,468' 20' 09/07/14 Open gi 10,372' 10,380' 9,507' 9,515' 8' 09/02/14 Isolated 5/g„ r D 5 10,380' 10,394' 9,515' 9,529' 14' 09/02/14 Isolated V 1 i 2 fl J Ea3 1 TOC @ 10,350' 4 e §., , 5 0- D-5 V 5" 6, ,. PBTD=10,805'MD/9,940'TVD TD=10,895'MD/10,029'TVD Updated by PC 10-21-14 STATE OF ALASKA RECEIVED ALA, _S OIL AND GAS CONSERVATION COM._,ION TI 0 8 2014 WELL COMPLETION OR RECOMPLETION REPORT AND LO -ilk- la. 1 a.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended El b.Well Class: ' [ q1 20AAC 25.105 20AAC 25.11 + Development ❑ Exploratory ❑ • GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: h._ 2 + Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5.DateCom�.,Susp.,or 12. Permit to Drill Number: Hilcorp Alaska, LLC Aband.: 9/7/2014 214-089 je-1-'iii-. : ' / 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Drive STE 1400 Anchorage,AK 99503 7/26/2014 50-133-20634-00 ' 4a. Location of Wells,(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface`30FSL„ic i 1053'FEL,Sec 6,T4N, R11W,SM,AK I, C ` /;: 8/17/2014 Kenai Beluga Unit(KBU)42-06Y Top of Productive Horizon: 7' 8. KB(ft above MSL): 84.8 15. Field/Pool(s): 1867'FNL, 102'FEL,Sec 6,T4N, R11W,SM,AK GL(ft above MSL): 66.2 Kenai Total Depth: 9. Plug Back Depth(MD+TVD): Upper Tyonek Beluga Gas 1849'FNL, 38'FEL,Sec 6,T4N, R11W,SM,AK •10,805'/9,940'TVD Tyonek Gas 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 274899.43 y- 2361930.7 Zone- 4 . 10,895'MD/10,029'TVD- FEE A028142 TPI: x- 275907.6 y- 2365390.5 Zone- 4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 275971.90 y- 2365407.40 Zone- 4 N/A NA(Located entirely within unit) 18. Directional Survey: Yes 0 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 MD/TVD: GR+Res from 1595'to 6493',GR+Res+Den/Neu+Sonic f/6493'to 10,800', mud lord- `c IA Fi.------"I`c-ro.0 N/A 23. CASING, LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 109 X-56 0 135 0 135 Driven Driven N/A 10-3/4" 45.5 L-80 0 1595 0 1570 13-1/2" 98 bbl lead/67 bbl tail N/A 7-5/8" 29.7 L-80 0 6483 0 5801 9-7/8" 170 bbl lead/27 bbl tail N/A 5" 18# L-80 0 10892 0 10025 6-3/4" 145 bbls 15.7 ppg tail N/A 24. Open to production or injection? Yes 0 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 N/A 10,296'-10,333'MD/9,431'-9,468'TVD;2-7/8"and 6 SPF 26. ACID, FRACTURE,CEMENT SQUEEZE,ETC. .E' Was hydraulic fracturing used during completion? Yes ❑ No 0 1. DEPTH INTERVAL(MD) 'AMOUNT AND KIND OF MATERIAL USED V FED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 9/12/2014 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 9/12/2014 1/24/1900 Test Period ... p 0 1153 0.1 N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 148 N/A 24-Hour Rate -1 0 1153 0.1 N/A 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No❑� Sidewall Cores Acquired? Yes ❑ No Q 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. P�M�N. OCT. 14 2014. Form 10-407 Revised iD+2Qi2 tONTINuED ON REVERSE` Su�nflii oriyindl oily -7-I6-tc ,>� 7/Z7<l- -727/> 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? 0 Yes ❑ No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, A6 Sterling Ss 3,661' 3,363' and submit detailed test information per 20 AAC 25.071. Upper Beluga Fm 5,238' 4,723' 10,296-10,333': Active perforations 1 mmcfgd @ 183 psi Middle Beluga Fm 5,900' 5,295' Lower Beluga Fm 6,732' 6,015' Tyonek 8,061' 7,219' D-1 Tyonek 9,648' 8,785' D-4 Tyonek 10,281' 9,416' Formation at total depth: D-8 Tyonek 31. List of Attachments: Well Schematic,MW vs Depth,Days vs Depth, Definitive directional survey,Drilling composite report,Casing and cmt reports for all strings 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Luke Keller 907-777-8395 Email: Ikeller(a)hilcorp.com Printed Name. Luke Keller Title: Drilling Engineer n Signature _2i_ 11(1/ Phone: 907-777-8395 Date: /0 Oc 2d/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item lb: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23 Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Kenai Gas Field Ili Well: KBU 42-06Y SCHEMATIC PTD: 214-089 Hilcorp Alaska,LLC API: 50-133-20634-00 RKB:MSL=18.5' CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 16" Conductor 109/X-56/Weld Surf 135' "' 0 103/4" Surface 45.5/L-80/BTC 9.950 Surf 1,595' 16' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,483' ,. 5" Production 18/L-80/DWC/C-HT 4.276 Surf 10,892' * u x *ii JEWELRY DETAIL 10-3/4"'�i 15-45 FNo Depth Item 1 6,006' 5"Swell Packer .. i 2 9,425' RA Pup t 4 3 9,631' RA Pup 4 10,199' RA Pup % i 7 5 10,360' CIBP i-kLAG OPEN HOLE/CEMENT DETAIL t " C. ' 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface C 4/ 7-5/8" 197BBL's of cement in 9-7/8"Hole.TOC 1,575'Calculated * i 5" 145BBL's of cement in 6-3/4"Hole. TOC 4,150'Calculated ' iG i.'Z 1 . X PERFORATION DETAIL > * s Sands Top(MD) Btm(MD) Top(ND) (gip) FT Date Status a ,, 10,296' 10,313' 9,431' 9,448' 17' 09/07/14 Open t . a D-4 10,313' 10,333' 9,448' 9,468' 20' 09/07/14 Open 4..c.18/' r 10,372' 10,380' 9,507' 9,515' 8' 09/02/14 Isolated x D-5 10,380' 10,394' 9,515' 9,529' 14' 09/02/14 Isolated It r.t t1 Y R y, 7-5/8" 6'473' N r; ►! 2 '' i 44, I l It h j TOC @10,350' '` 4 C( P •�7r' 5 Db t M 5„ ,srs" , i'�i I a`Mt PBTD=10,805 MD/9,940'TVD 1D=10,895'MD/10,029'TVD Uodated by DMA 09-30-14 a a I- ° us o v , mCO 0 _ c O D 13 al o > 1 2 Ymem Nava .- O mc o.- .c: ea.- ra c a) a oE Ncaa cEyU aa . 25 2a a ' 0 y `m d dm m 3-o a OY@E - m cm. o '- n m Y m ma) 5 a0) v o w 0 c r _ ' a ,-U coE Np m 0 - oo a 0 rs T No Q .. c0 CD a s0 Na mOEmL 3 o m .Oca o Nr o o w m mN >rc oro p > oaa = atooa c .' rb °Li.. c '$ m U n - a' o N -o c ° E a a) ° co o 3a° o c3o co i = 0 > sr 3 c a m 0 Z > Y oEc Nc () is. to = mn • o -,, E JEdU mx ° 5aO .- o -° m1- z o a a E ° ' aE m , c U > o E o E si caOmY m m cO ° .Na C .c Q m a Q U) C Oo C "O O .O Nd .W Lc -O i0) a - N3. 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20 27 -gu) -5 � 3 < \ \ m 0)/ © °, G = c- _ < e v m� �_\ 0 .» % o & o = 4 / 5 L. \ T. a 7 ) 2 2 I _ /& / kk0C0 o $ co 2 = = 0 0 0 a 3 co % o \ \ / -0 k • x o I o E f / / k\ / $ U I@ E a e » U) Tii ,- >- / o co § \ ° >- $ o $ I \ \ / C. ƒ7 (0 = e k D e / / / / - a ± _% % Q ■ / 5 �: ƒ � / \ \ \ co ETu. \ / E \ E o w 2 k # # co k O < k 5 < < La \ \ Z1 % 2 / 0 E \ ' 6 R $ \ 47,- 0 m ' a a o « $ 2 '71- co # 0 � / \ \ a % c re o a Hilcorp Energy Company Kenai Gas Field KGF 41-7 Pad KBU 42-06Y 501332063400 I501332063400 Sperry Drilling Definitive Survey Report 29 August, 2014 III II HALLIBURTON ti p Sperry Drilling Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 42-06Y Project: Kenai Gas Field TVD Reference: KBU 42-06Y:Actual @ 84.90usft Site: KGF 41-7 Pad MD Reference: KBU 42-06Y:Actual @ 84.90usft Well: KBU 42-06Y North Reference: True Wellbore: KBU 42-06Y Survey Calculation Method: Minimum Curvature Design: KBU 42-06Y Database: Sperry EDM-NORTH US+CANADA Project Kenai Gas Field Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well KBU 42-06Y Well Position +N/-S 0.00 usft Northing: 2,361,930.88 usft Latitude: 60°27'33.450 N +El-W 0.00 usft Easting: 274,897.09 usft Longitude: 151°14'49.370 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 66.20 usft Wellbore KBU 42-06Y Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 7/19/2014 16.86 73.44 55,358 Design KBU 42-06Y Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.50 Vertical Section: Depth From(ND) +NIS +EI-W Direction (usft) (usft) (usft) (0) 18.50 0.00 0.00 16.96 Survey Program Date 8/29/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 264.25 1,601.10 KBU 42-06Y[MWD+SC+sag](KBU 42-0 MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 07/26/2014 1,663.12 6,449.72 KBU 42-06Y[MWD+SC+sag](KBU 42-0 MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 07/26/2014 6,449.72 10,856.69 KBU 42-06Y[MWD+SC+sag](KBU 42-0 MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 07/26/2014 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 18.50 0.00 0.00 18.50 -66.40 0.00 0.00 2,361,930.88 274,897.09 0.00 0.00 UNDEFINED 264.25 0.66 121.31 264.24 179.34 -0.74 1.21 2,361,930.12 274,898.29 0.27 -0.35 MWD+SC+sag(1) 325.99 0.33 140.44 325.98 241.08 -1.06 1.63 2,361,929.79 274,898.70 0.59 -0.54 MWD+SC+sag(1) 387.47 0.50 179.28 387.46 302.56 -1.46 1.74 2,361,929.38 274,898.81 0.52 -0.89 MWD+SC+sag(1) 448.65 0.66 78.08 448.64 363.74 -1.66 2.09 2,361,929.18 274,899.15 1.47 -0.97 MWD+SC+sag(1) 510.73 0.96 39.45 510.71 425.81 -1.18 2.77 2,361,929.64 274,899.84 0.98 -0.32 MWD+SC+sag(1) 571.71 1.64 32.34 571.68 486.78 -0.05 3.56 2,361,930.76 274,900.65 1.14 0.99 MWD+SC+sag(1) 633.40 3.49 23.96 633.30 548.40 2.41 4.80 2,361,933.20 274,901.94 3.05 3.71 MWD+SC+sag(1) 695.86 4.83 22.60 695.60 610.70 6.58 6.58 2,361,937.33 274,903.80 2.15 8.21 MWD+SC+sag(1) 758.67 6.06 19.08 758.12 673.22 12.15 8.68 2,361,942.86 274,906.00 2.03 14.16 MWD+SC+sag(1) 820.07 7.43 17.22 819.10 734.20 19.01 10.91 2,361,949.67 274,908.37 2.26 21.36 MWD+SC+sag(1) 881.76 8.46 13.52 880.19 795.29 27.23 13.16 2,361,957.85 274,910.76 1.86 29.88 MWD+SC+sag(1) 8/29/2014 5:50:59PM Page 2 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 42-06Y Project: Kenai Gas Field TVD Reference: KBU 42-06Y:Actual @ 84.90usft Site: KGF 41-7 Pad MD Reference: KBU 42-06Y:Actual @ 84.90usft Well: KBU 42-06Y North Reference: True Wellbore: KBU 42-06Y Survey Calculation Method: Minimum Curvature Design: KBU 42-06Y Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc AzI ND TVDSS +N/S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 946.23 9.81 13.63 943.84 858.94 37.18 15.56 2,361,967.75 274,913.35 2.09 40.10 MWD+SC+sag(1) 1,005.75 11.05 15.38 1,002.38 917.48 47.61 18.27 2,361,978.13 274,916.26 2.15 50.86 MWD+SC+sag(1) 1,069.06 11.63 14.63 1,064.45 979.55 59.63 21.49 2,361,990.09 274,919.71 0.95 63.31 MWD+SC+sag(1) 1,130.91 12.28 16.32 1,124.96 1,040.06 71.98 24.91 2,362,002.37 274,923.36 1.19 76.11 MWD+SC+sag(1) 1,193.73 13.13 17.08 1,186.24 1,101.34 85.21 28.88 2,362,015.52 274,927.59 1.38 89.93 MWD+SC+sag(1) 1,255.57 13.73 15.77 1,246.39 1,161.49 98.99 32.94 2,362,029,22 274,931.90 1.09 104.29 MWD+SC+sag(1) 1,317.14 14.88 16.57 1,306.05 1,221.15 113.59 37.18 2,362,043.74 274,936.42 1.90 119.50 MWD+SC+sag(1) 1,380.40 16.77 15.63 1,366.91 1,282.01 130.17 41.96 2,362,060.22 274,941.51 3.01 136.75 MWD+SC+sag(1) 1,443.09 17.71 14.50 1,426.78 1,341.88 148.11 46.78 2,362,078.07 274,946.67 1.59 155.32 MWD+SC+sag(1) 1,505.09 19.57 14.53 1,485.53 1,400.63 167.29 51.75 2,362,097.15 274,952.00 3.00 175.11 MWD+SC+sag(1) 1,565.39 20.55 15.41 1,542.17 1,457.27 187.27 57.09 2,362,117.03 274,957.72 1.70 195.78 MWD+SC+sag(1) 1,601.10 20.68 16.67 1,575.59 1,490.69 199.36 60.57 2,362,129.04 274,961.42 1.29 208.35 MWD+SC+sag(1) 1,663.12 21.94 17.64 1,633.37 1,548.47 220.89 67.22 2,362,150.45 274,968.48 2.11 230.89 MWD+SC+sag(2) 1,725.41 22.47 15.75 1,691.04 1,606.14 243.44 73.98 2,362,172.86 274,975.67 1.43 254.43 MWD+SC+sag(2) 1,787.76 23.83 15.73 1,748.37 1,663.47 267.03 80.63 2,362,196.32 274,982.76 2.18 278.94 MWD+SC+sag(2) 1,849.25 25.18 17.32 1,804.32 1,719.42 291.48 87.89 2,362,220.62 274,990.48 2.44 304.44 MWD+SC+sag(2) 1,911.55 27.10 17.70 1,860.25 1,775.35 317.65 96.15 2,362,246.63 274,999.24 3.09 331.88 MWD+SC+sag(2) 1,972.68 28.76 18.22 1,914.26 1,829.36 344.88 104.98 2,362,273.70 275,008.59 2.74 360.51 MWD+SC+sag(2) 2,035.67 30.19 17.61 1,969.09 1,884.19 374.37 114.51 2,362,303.00 275,018.67 2.32 391.50 MWD+SC+sag(2) 2,095.91 30.14 17.89 2,021.17 1,936.27 403.20 123.74 2,362,331.65 275,028.44 0.25 421.76 MWD+SC+sag(2) 2,159.30 31.02 17.36 2,075.75 1,990.85 433.94 133.50 2,362,362.19 275,038.79 1.45 454.01 MWD+SC+sag(2) 2,221.68 30.75 17.48 2,129.28 2,044.38 464.49 143.09 2,362,392.56 275,048.95 0.44 486.03 MWD+SC+sag(2) 2,283.50 30.33 16.94 2,182.53 2,097.63 494.50 152.39 2,362,422.38 275,058.81 0.81 517.44 MWD+SC+sag(2) 2,345.31 30.58 16.75 2,235.81 2,150.91 524.48 161.46 2,362,452.19 275,068.45 0.43 548.77 MWD+SC+sag(2) 2,407.20 30.99 16.09 2,288.98 2,204.08 554.87 170.42 2,362,482.39 275,077.98 0.86 580.45 MWD+SC+sag(2) 2,469.28 30.63 16.46 2,342.30 2,257.40 585.39 179.33 2,362,512.74 275,087.47 0.66 612.24 MWD+SC+sag(2) 2,532.12 31.30 15,78 2,396.18 2,311.28 616.45 188.30 2,362,543.63 275,097.03 1.20 644.57 MWD+SC+sag(2) 2,593.49 31.43 16.01 2,448.58 2,363.68 647.17 197.05 2,362,574.17 275,106.36 0.29 676.51 MWD+SC+sag(2) 2,655.72 30.98 15.85 2,501.81 2,416.91 678.17 205.90 2,362,605.00 275,115.79 0.74 708.74 MWD+SC+sag(2) 2,717.60 30.40 15.98 2,555.02 2,470.12 708.55 214.56 2,362,635.20 275,125.02 0.94 740.32 MWD+SC+sag(2) 2,779.25 31.31 16.48 2,607.95 2,523.05 738.90 223.40 2,362,665.39 275,134.44 1.53 771.93 MWD+SC+sag(2) 2,841.05 31.66 16.67 2,660.65 2,575.75 769.84 232.61 2,362,696.14 275,144.23 0.59 804.21 MWD+SC+sag(2) 2,903.97 31.13 17.08 2,714.36 2,629.46 801.20 242.12 2,362,727.32 275,154.33 0.91 836.99 MWD+SC+sag(2) 2,966.21 30.55 16.55 2,767.79 2,682.89 831.75 251.35 2,362,757.68 275,164.14 1.03 868.89 MWD+SC+sag(2) 3,028.27 30.65 16.28 2,821.21 2,736.31 862.05 260.28 2,362,787.81 275,173.64 0.27 900.48 MWD+SC+sag(2) 3,090.20 31.89 15.45 2,874.14 2,789.24 892.97 269.06 2,362,818.56 275,183.01 2.12 932.62 MWD+SC+sag(2) 3,152.09 32.52 14.67 2,926.51 2,841.61 924.82 277.63 2,362,850.24 275,192.18 1.22 965.59 MWD+SC+sag(2) 3,214.25 32.11 14.94 2,979.05 2,894.15 956.95 286.12 2,362,882.20 275,201.27 0.70 998.79 MWD+SC+sag(2) 3,276.49 31.88 14.62 3,031.83 2,946.93 988.83 294.53 2,362,913.92 275,210.29 0.46 1,031.75 MWD+SC+sag(2) 3,338.84 31.43 14.81 3,084.90 3,000.00 1,020.48 302.85 2,362,945.40 275,219.20 0.74 1,064.44 M1ND+SC+sag(2) 8/29/2014 5:50:59PM Page 3 COMPASS 5000.1 Build 70 Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 42-06Y Project Kenai Gas Field TVD Reference: KBU 42-06Y:Actual @ 84.90usft Site: KGF 41-7 Pad MD Reference: KBU 42-06Y:Actual @ 84.90usft Well: KBU 42-06Y North Reference: True Wellbore: KBU 42-06Y Survey Calculation Method: Minimum Curvature Design: KBU 42-06Y 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 3,400.50 31.03 14.53 3,137.63 3,052.73 1,051.41 310.94 2,362,976.17 275,227.88 0.69 1,096.39 MWD+SC+sag(2) 3,462.59 30.54 14.53 3,190.97 3,106.07 1,082.17 318.92 2,363,006.77 275,236.43 0.79 1,128.14 MWD+SC+sag(2) 3,524.62 30.02 14.64 3,244.54 3,159.64 1,112.44 326.79 2,363,036.88 275,244.88 0.84 1,159.39 MWD+SC+sag(2) 3,586.72 29.65 15.04 3,298.41 3,213.51 1,142.31 334.70 2,363,066.59 275,253.35 0.68 1,190.26 MWD+SC+sag(2) 3,648.72 30.05 15.42 3,352.18 3,267.28 1,172.08 342.81 2,363,096.21 275,262.02 0.71 1,221.11 MWD+SC+sag(2) 3,710.23 30.00 15.39 3,405.44 3,320.54 1,201.75 350.99 2,363,125.72 275,270.76 0.08 1,251.87 MWD+SC+sag(2) 3,772.41 29.73 15.69 3,459.36 3,374.46 1,231.58 359.28 2,363,155.39 275,279.62 0.50 1,282.83 MWD+SC+sag(2) 3,834.53 29.50 15.51 3,513.36 3,428.46 1,261.15 367.54 2,363,184.79 275,288.43 0.40 1,313.52 MWD+SC+sag(2) 3,896.80 29.99 17.37 3,567.43 3,482.53 1,290.78 376.28 2,363,214.24 275,297.73 1.68 1,344.41 MWD+SC+sag(2) 3,959.07 30.18 18.08 3,621.31 3,536.41 1,320.51 385.79 2,363,243.79 275,307.80 0.65 1,375.62 MWD+SC+sag(2) 4,020.67 30.90 16.66 3,674.37 3,589.47 1,350.38 395.13 2,363,273.48 275,317.70 1.65 1,406.92 MWD+SC+sag(2) 4,082.55 31.36 16.23 3,727.34 3,642.44 1,381.07 404.18 2,363,303.98 275,327.34 0.83 1,438.90 MWD+SC+sag(2) 4,144.55 31.07 16.70 3,780.36 3,695.46 1,411.88 413.29 2,363,334.62 275,337.03 0.61 1,471.03 MWD+SC+sag(2) 4,205.65 30.70 16.59 3,832.80 3,747.90 1,441.93 422.27 2,363,364.49 275,346.58 0.61 1,502.40 MWD+SC+sag(2) 4,268.63 30.33 15.93 3,887.05 3,802.15 1,472.63 431.23 2,363,395.01 275,356.11 0.79 1,534.37 MWD+SC+sag(2) 4,330.79 30.03 15.87 3,940.79 3,855.89 1,502.68 439.79 2,363,424.90 275,365.24 0.49 1,565.62 MWD+SC+sag(2) 4,392.80 29.72 15.83 3,994.56 3,909.66 1,532.40 448.22 2,363,454.45 275,374.24 0.50 1,596.50 MWD+SC+sag(2) 4,454.98 29.51 16.22 4,048.61 3,963.71 1,561.93 456.71 2,363,483.81 275,383.28 0.46 1,627.22 MWD+SC+sag(2) 4,516.84 30.50 16.45 4,102.18 4,017.28 1,591.61 465.41 2,363,513.33 275,392.54 1.61 1,658.16 MWD+SC+sag(2) 4,578.69 30.84 16.67 4,155.38 4,070.48 1,621.85 474.40 2,363,543.39 275,402.10 0.58 1,689.70 MWD+SC+sag(2) 4,641.29 30.56 16.74 4,209.21 4,124.31 1,652.47 483.59 2,363,573.82 275,411.86 0.45 1,721.66 MWD+SC+sag(2) 4,703.17 30.39 16.96 4,262.54 4,177.64 1,682.50 492.68 2,363,603.68 275,421.53 0.33 1,753.05 MWD+SC+sag(2) 4,765.40 30.07 16.94 4,316.31 4,231.41 1,712.47 501.82 2,363,633.47 275,431.23 0.51 1,784.38 MWD+SC+sag(2) 4,827.59 29.89 16.90 4,370.18 4,285.28 1,742.20 510.86 2,363,663.02 275,440.83 0.29 1,815.45 MWD+SC+sag(2) 4,889.67 30.72 17.82 4,423.77 4,338.87 1,772.10 520.21 2,363,692.73 275,450.75 1.53 1,846.78 M1ND+SC+sag(2) 4,951.40 31.62 17.65 4,476.59 4,391.69 1,802.53 529.94 2,363,722.97 275,461.05 1.46 1,878.72 MWD+SC+sag(2) 5,013.68 31.24 17.83 4,529.73 4,444.83 1,833.46 539.84 2,363,753.71 275,471.53 0.63 1,911.20 MWD+SC+sag(2) 5,075.64 31.19 17.73 4,582.72 4,497.82 1,864.04 549.64 2,363,784.10 275,481.91 0.12 1,943.30 MWD+SC+sag(2) 5,137.44 30.81 17.52 4,635.70 4,550.80 1,894.37 559.28 2,363,814.24 275,492.12 0.64 1,975.13 MWD+SC+sag(2) 5,199.44 30.46 17.46 4,689.04 4,604.14 1,924.51 568.78 2,363,844.19 275,502.19 0.57 2,006.72 MWD+SC+sag(2) 5,261.65 30.29 18.37 4,742.71 4,657.81 1,954.44 578.45 2,363,873.93 275,512.43 0.79 2,038.18 MWD+SC+sag(2) 5,324.09 30.03 18.09 4,796.70 4,711.80 1,984.23 588.27 2,363,903.53 275,522.80 0.47 2,069.54 MWD+SC+sag(2) 5,385.28 29.60 17.69 4,849.79 4,764.89 2,013.19 597.61 2,363,932.30 275,532.69 0.77 2,099.96 MWD+SC+sag(2) 5,447.51 30.06 18.01 4,903.78 4,818.88 2,042.65 607.10 2,363,961.58 275,542.74 0.78 2,130.91 MWD+SC+sag(2) 5,508.25 30.62 18.18 4,956.20 4,871.30 2,071.82 616.63 2,363,990.56 275,552.82 0.93 2,161.58 MWD+SC+sag(2) 5,571.88 30.30 18.07 5,011.04 4,926.14 2,102.47 626.67 2,364,021.02 275,563.43 0.51 2,193.83 MWD+SC+sag(2) 5,633.76 30.15 17.96 5,064.51 4,979.61 2,132.09 636.30 2,364,050.45 275,573.63 0.26 2,224.98 M1ND+SC+sag(2) 5,696.13 29.93 18.33 5,118.50 5,033.60 2,161.76 646.02 2,364,079.93 275,583.91 0.46 2,256.19 MWD+SC+sag(2) 5,756.90 29.73 18.19 5,171.22 5,086.32 2,190.47 655.50 2,364,108.45 275,593.92 0.35 2,286.42 MWD+SC+sag(2) 5,819.82 29.57 18.49 5,225.90 5,141.00 2,220.02 665.29 2,364,137.80 275,604.27 0.35 2,317.53 MWD+SC+sag(2) 8/29/2014 5:50:59PM Page 4 COMPASS 5000.1 Build 70 Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 42-06Y Project: Kenai Gas Field ND Reference: KBU 42-06Y:Actual @ 84.90usft Site: KGF 41-7 Pad MD Reference: KBU 42-06Y:Actual @ 84.90usft Well: KBU 42-06Y North Reference: True Wellbore: KBU 42-06Y Survey Calculation Method: Minimum Curvature Design: KBU 42-06Y Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi ND TVDSS +NIS +EI-W Northing Easting DLS Section (usft) (°) (") (usft) (usft) (usft) (usft) (ft) (ft) (11001 (ft) Survey Tool Name 5,881.51 29.71 18.51 5,279.52 5,194.62 2,248.95 674.97 2,364,166.55 275,614.50 0.23 2,348.03 MWD+SC+sag(2) 5,943.76 30.51 16.19 5,333.37 5,248.47 2,278.75 684.27 2,364,196.17 275,624.36 2.27 2,379.25 MWD+SC+sag(2) 6,006.44 30.55 15.45 5,387.36 5,302.46 2,309.39 692.95 2,364,226.63 275,633.62 0.60 2,411.09 MWD+SC+sag(2) 6,068.36 30.18 15.45 5,440.79 5,355.89 2,339.56 701.29 2,364,256.64 275,642.53 0.60 2,442.38 MWD+SC+sag(2) 6,129.47 29.96 15.13 5,493.68 5,408.78 2,369.09 709.37 2,364,286.01 275,651.16 0.45 2,472.98 MWD+SC+sag(2) 6,191.67 29.97 15.14 5,547.56 5,462.66 2,399.08 717.48 2,364,315.84 275,659.84 0.02 2,504.03 MWD+SC+sag(2) 6,254.15 29.83 15.48 5,601.73 5,516.83 2,429.12 725.70 2,364,345.72 275,668.63 0.35 2,535.17 MWD+SC+sag(2) 6,315.93 29.73 15.30 5,655.35 5,570.45 2,458.71 733.84 2,364,375.14 275,677.33 0.22 2,565.84 MWD+SC+sag(2) 6,377.79 29.46 16.06 5,709.14 5,624.24 2,488.12 742.10 2,364,404.39 275,686.14 0.75 2,596.38 MWD+SC+sag(2) 6,449.72 29.24 15.73 5,771.83 5,686.93 2,522.03 751.76 2,364,438.11 275,696.44 0.38 2,631.63 MWD+SC+sag(2) 6,506.58 29.97 17.31 5,821.27 5,736.37 2,548.95 759.75 2,364,464.88 275,704.94 1.88 2,659.72 MWD+SC+sag(3) 6,568.79 31.01 17.30 5,874.88 5,789.98 2,579.09 769.14 2,364,494.83 275,714.90 1.67 2,691.28 MWD+SC+sag(3) 6,630.74 31.29 17.36 5,927.90 5,843.00 2,609.68 778.68 2,364,525.23 275,725.02 0.45 2,723.33 MWD+SC+sag(3) 6,693.02 31.12 16.89 5,981.16 5,896.26 2,640.52 788.18 2,364,555.88 275,735.10 0.48 2,755.59 M1ND+SC+sag(3) 6,755.20 30.66 16.07 6,034.52 5,949.62 2,671.13 797.24 2,364,586.32 275,744.74 1.00 2,787.52 MWD+SC+sag(3) 6,816.23 30.91 15.84 6,086.96 6,002.06 2,701.16 805.83 2,364,616.18 275,753.89 0.45 2,818.75 MWD+SC+sag(3) 6,877.10 31.00 15.72 6,139.16 6,054.26 2,731.29 814.34 2,364,646.14 275,762.97 0.18 2,850.05 MWD+SC+sag(3) 6,939.49 31.30 15.69 6,192.55 6,107.65 2,762.36 823.08 2,364,677.04 275,772.29 0.48 2,882.31 MWD+SC+sag(3) 7,003.09 31.23 15.61 6,246.91 6,162.01 2,794.14 831.98 2,364,708.65 275,781.80 0.13 2,915.31 MWD+SC+sag(3) 7,064.88 30.70 16.04 6,299.90 6,215.00 2,824.73 840.65 2,364,739.06 275,791.04 0.93 2,947.10 MWD+SC+sag(3) 7,127.13 30.42 16.03 6,353.50 6,268.60 2,855.15 849.39 2,364,769.31 275,800.36 0.45 2,978.75 MWD+SC+sag(3) 7,189.02 30.00 15.73 6,406.99 6,322.09 2,885.10 857.91 2,364,799.09 275,809.45 0.72 3,009.88 MWD+SC+sag(3) 7,251.14 27.43 14.89 6,461.46 6,376.56 2,913.88 865.80 2,364,827.72 275,817.88 4.19 3,039.71 MWD+SC+sag(3) 7,313.26 26.16 13.70 6,516.91 6,432.01 2,941.01 872.72 2,364,854.71 275,825.31 2.22 3,067.68 MWD+SC+sag(3) 7,374.77 24.51 14.68 6,572.50 6,487.60 2,966.53 879.17 2,364,880.10 275,832.24 2.77 3,093.97 MWD+SC+sag(3) 7,437.42 23.09 16.13 6,629.82 6,544.92 2,990.91 885.87 2,364,904.35 275,839.41 2.45 3,119.24 MWD+SC+sag(3) 7,498.68 22.87 15.58 6,686.22 6,601.32 3,013.91 892.41 2,364,927.22 275,846.37 0.50 3,143.15 MWD+SC+sag(3) 7,561.10 22.07 15.33 6,743.90 6,659.00 3,036.91 898.77 2,364,950.09 275,853.17 1.29 3,167.00 MWD+SC+sag(3) 7,621.41 21.12 15.00 6,799.98 6,715.08 3,058.33 904.57 2,364,971.40 275,859.38 1.59 3,189.19 MWD+SC+sag(3) 7,684.81 19.72 14.73 6,859.39 6,774.49 3,079.71 910.25 2,364,992.67 275,865.46 2.21 3,211.29 MWD+SC+sag(3) 7,747.13 19.13 15.26 6,918.17 6,833.27 3,099.73 915.61 2,365,012.58 275,871.20 0.99 3,232.01 MWD+SC+sag(3) 7,809.13 16.73 18.48 6,977.15 6,892.25 3,118.00 921.12 2,365,030.74 275,877.05 4.19 3,251.09 MWD+SC+sag(3) 7,871.57 16.62 18.27 7,036.97 6,952.07 3,135.00 926.76 2,365,047.63 275,883.01 0.20 3,269.00 MWD+SC+sag(3) 7,929.20 16.24 17.43 7,092.24 7,007.34 3,150.51 931.76 2,365,063.05 275,888.30 0.78 3,285.29 MWD+SC+sag(3) 7,994.75 15.87 16.86 7,155.24 7,070.34 3,167.84 937.11 2,365,080.27 275,893.98 0.61 3,303.42 MWD+SC+sag(3) 8,056.79 15.50 17.49 7,214.97 7,130.07 3,183.86 942.06 2,365,096.19 275,899.23 0.66 3,320.19 MWD+SC+sag(3) 8,119.54 14.99 18.06 7,275.51 7,190.61 3,199.57 947.09 2,365,111.81 275,904.56 0.85 3,336.69 MWD+SC+sag(3) 8,181.83 15.02 17.92 7,335.67 7,250.77 3,214.91 952.07 2,365,127.05 275,909.83 0.08 3,352.82 MWD+SC+sag(3) 8,244.00 14.78 17.67 7,395.75 7,310.85 3,230.13 956.96 2,365,142.17 275,915.01 0.40 3,368.80 MWD+SC+sag(3) 8,305.33 14.50 17.54 7,455.09 7,370.19 3,244.91 961.65 2,365,156.86 275,919.97 0.46 3,384.30 MWD+SC+sag(3) 8/29/2014 5:50:59PM Page 5 COMPASS 5000.1 Build 70 ` Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 42-06Y Project: Kenai Gas Field TVD Reference: KBU 42-06Y:Actual @ 84.90usft Site: KGF 41-7 Pad MD Reference: KBU 42-06Y:Actual @ 84.90usft Well: KBU 42-06Y North Reference: True Wellbore: KBU 42-06Y Survey Calculation Method: Minimum Curvature Design: KBU 42-06Y Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°11001 (ft) Survey Tool Name 8,368.78 14.38 17.30 7,516.54 7,431.64 3,260.00 966.39 2,365,171.86 275,924.99 0.21 3,400.12 MWD+SC+sag(3) 8,429.68 12.50 16.86 7,575.77 7,490.87 3,273.53 970.55 2,365,185.31 275,929.41 3.09 3,414.28 MWD+SC+sag(3) 8,491.48 11.71 16.28 7,636.19 7,551.29 3,285.95 974.24 2,365,197.65 275,933.34 1.29 3,427.24 MWD+SC+sag(3) 8,553.38 9.16 17.44 7,697.06 7,612.16 3,296.68 977.48 2,365,208.32 275,936.78 4.13 3,438.45 MWD+SC+sag(3) 8,613.15 7.14 19.39 7,756.23 7,671.33 3,304.73 980.14 2,365,216.31 275,939.59 3.41 3,446.91 MWD+SC+sag(3) 8,678.61 7.20 19.35 7,821.18 7,736.28 3,312.44 982.85 2,365,223.97 275,942.45 0.09 3,455.08 MWD+SC+sag(3) 8,740.58 6.87 18.16 7,882.68 7,797.78 3,319.62 985.29 2,365,231.11 275,945.03 0.58 3,462.66 MWD+SC+sag(3) 8,802.57 6.85 15.63 7,944.23 7,859.33 3,326.71 987.44 2,365,238.15 275,947.31 0.49 3,470.07 MWD+SC+sag(3) 8,864.97 6.56 15.37 8,006.20 7,921.30 3,333.73 989.39 2,365,245.13 275,949.39 0.47 3,477.35 MWD+SC+sag(3) 8,925.67 6.53 14.86 8,066.50 7,981.60 3,340.40 991.20 2,365,251.77 275,951.32 0.11 3,484.26 MWD+SC+sag(3) 8,988.04 6.21 12.77 8,128.49 8,043.59 3,347.12 992.85 2,365,258.46 275,953.10 0.63 3,491.17 MWD+SC+sag(3) 9,050.13 6.06 12.47 8,190.22 8,105.32 3,353.60 994.30 2,365,264.90 275,954.68 0.25 3,497.79 MWD+SC+sag(3) 9,112.03 5.92 12.41 8,251.78 8,166.88 3,359.91 995.69 2,365,271.19 275,956.19 0.23 3,504.23 MWD+SC+sag(3) 9,174.80 5.58 11.51 8,314.24 8,229.34 3,366.06 997.00 2,365,277.31 275,957.61 0.56 3,510.49 MWD+SC+sag(3) 9,237.17 5.72 10.71 8,376.31 8,291.41 3,372.08 998.18 2,365,283.31 275,958.90 0.26 3,516.60 MWD+SC+sag(3) 9,299.39 5.69 9.96 8,438.22 8,353.32 3,378.17 999.29 2,365,289.37 275,960.13 0.13 3,522.75 MWD+SC+sag(3) 9,361.25 5.39 7.89 8,499.79 8,414.89 3,384.07 1,000.22 2,365,295.25 275,961.17 0.58 3,528.66 MWD+SC+sag(3) 9,423.50 5.39 7.81 8,561.76 8,476.86 3,389.86 1,001.02 2,365,301.03 275,962.08 0.01 3,534.43 MWD+SC+sag(3) 9,483.77 5.15 6.76 8,621.78 8,536.88 3,395.35 1,001.72 2,365,306.51 275,962.88 0.43 3,539.89 MWD+SC+sag(3) 9,545.33 5.30 7.76 8,683.08 8,598.18 3,400.91 1,002.43 2,365,312.05 275,963.70 0.29 3,545.42 MWD+SC+sag(3) 9,609.37 5.50 7.06 8,746.84 8,661.94 3,406.89 1,003.21 2,365,318.01 275,964.59 0.33 3,551.36 MWD+SC+sag(3) 9,670.53 5.23 6.05 8,807.73 8,722.83 3,412.57 1,003.86 2,365,323.68 275,965.35 0.47 3,556.98 MWD+SC+sag(3) 9,732.97 5.16 5.67 8,869.91 8,785.01 3,418.19 1,004.44 2,365,329.29 275,966.03 0.12 3,562.53 MWD+SC+sag(3) 9,795.66 4.90 4.67 8,932.36 8,847.46 3,423.66 1,004.93 2,365,334.76 275,966.63 0.44 3,567.91 MWD+SC+sag(3) 9,857.00 4.89 5.27 8,993.48 8,908.58 3,428.88 1,005.39 2,365,339.96 275,967.19 0.09 3,573.03 MWD+SC+sag(3) 9,919.09 4.68 4.98 9,055.35 8,970.45 3,434.04 1,005.85 2,365,345.11 275,967.75 0.34 3,578.10 MWD+SC+sag(3) 9,980.94 4.41 5.52 9,117.01 9,032.11 3,438.92 1,006.30 2,365,349.98 275,968.29 0.44 3,582.90 MWD+SC+sag(3) 10,042.29 4.26 5.94 9,178.18 9,093.28 3,443.53 1,006.76 2,365,354.58 275,968.84 0.25 3,587.45 MWD+SC+sag(3) 10,104.37 3.84 6.12 9,240.11 9,155.21 3,447.89 1,007.22 2,365,358.93 275,969.38 0.68 3,591.75 MWD+SC+sag(3) 10,166.92 3.61 4.14 9,302.52 9,217.62 3,451.94 1,007.59 2,365,362.97 275,969.82 0.42 3,595.73 MWD+SC+sag(3) 10,229.19 3.40 2.98 9,364.68 9,279.78 3,455.74 1,007.82 2,365,366.77 275,970.13 0.36 3,599.43 MWD+SC+sag(3) 10,291.04 3.58 4.44 9,426.41 9,341.51 3,459.50 1,008.07 2,365,370.52 275,970.45 0.32 3,603.10 MWD+SC+sag(3) 10,353.12 3.67 3.80 9,488.37 9,403.47 3,463.41 1,008.35 2,365,374.43 275,970.80 0.16 3,606.93 MWD+SC+sag(3) 10,415.40 3.41 3.20 9,550.53 9,465.63 3,467.25 1,008.59 2,365,378.26 275,971.11 0.42 3,610.67 MWD+SC+sag(3) 10,476.96 3.58 3.44 9,611.98 9,527.08 3,471.00 1,008.80 2,365,382.00 275,971.40 0.28 3,614.31 MWD+SC+sag(3) 10,539.73 3.54 1.64 9,674.62 9,589.72 3,474.89 1,008.98 2,365,385.89 275,971.65 0.19 3,618.09 MWD+SC+sag(3) 10,601,39 3.06 1.38 9,736.18 9,651.28 3,478.44 1,009.07 2,365,389.44 275,971.81 0.78 3,621.51 MWD+SC+sag(3) 10,663.46 2.94 1.44 9,798.17 9,713.27 3,481.68 1,009.15 2,365,392.68 275,971.95 0.19 3,624.64 MWD+SC+sag(3) 10,725.82 2.66 359.38 9,860.45 9,775.55 3,484.73 1,009.18 2,365,395.73 275,972.03 0.48 3,627.56 MWD+SC+sag(3) 10,787.68 2.41 359.68 9,922.25 9,837.35 3,487.47 1,009.15 2,365,398.46 275,972.06 0.40 3,630.17 MWD+SC+sag(3) 8/29/2014 5:50:59PM Page 6 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 42-06Y Project: Kenai Gas Field ND Reference: KBU 42-06Y:Actual©84.90usft Site: KGF 41-7 Pad MD Reference: KBU 42-06Y:Actual @ 84.90usft Well: KBU 42-06Y North Reference: True Wellbore: KBU 42-06Y Survey Calculation Method: Minimum Curvature Design: KBU 42-06Y Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,856.69 2.09 358.65 9,991.21 9,906.31 3,490.17 1,009.12 2,365,401.17 275,972.07 0.47 3,632.75 MWD+SC+sag(3) 10,895.00 2.09 358.65 10,029.49 9,944.59 3,491.57 1,009.08 2,365,402.57 275,972.07 0.00 3,634.08 PROJECTED to TD Checked By: Patrick Walker z"ars„ ,,, •w Approved By: Cary Taylor o,, ,,,a ii.FS Date: 8/29t2014 5:50:59PM Page 7 COMPASS 5000.1 Build 70 KBU 42-06Y Definitive Surveys H HEADER INFORMATION H COMPANY : Hilcorp Energy Company H FIELD : Kenai Gas Field H SITE : KGF 41-7 Pad H WELL : KBU 42-06Y H WELLPATH: KBU 42-06Y H DEPTHUNT: usft H SURVDATE: 8/29/2014 H H WELL INFORMATION H WELL EW MAP : 274897.09 H WELL NS MAP : 2361930.88 H DATUM ELEVN : 84.90 H VSECT ANGLE : 16.96 H VSECT NORTH : 0.00 H VSECT EAST : 0.00 H H SURVEY TYPE INFORMATION H 264.25 - 1601.10 KBU 42-06Y [MWD+SC+SAG] : MWD+SC+SAG H 1663.12 - 6449.72 KBU 42-06Y [MWD+SC+SAG] : MWD+SC+SAG H 6449.72 - 10856.69 KBU 42-06Y [MWD+SC+SAG] : MWD+SC+SAG H H SURVEY LIST H MD INC AZI TVD NS EW 18.50 0.00 0.00 18.50 0.00 0.00 264.25 0.66 121.31 264.24 -0.74 1.21 325.99 0.33 140.44 325.98 -1.06 1.63 387.47 0. 50 179.28 387.46 -1.46 1.74 448.65 0.66 78.08 448.64 -1.66 2.09 510.73 0.96 39.45 510.71 -1.18 2.77 571.71 1.64 32.34 571.68 -0.05 3. 56 633.40 3.49 23.96 633.30 2.41 4.80 695.86 4.83 22.60 695.60 6.58 6. 58 758.67 6.06 19.08 758.12 12.15 8.68 820.07 7.43 17.22 819.10 19.01 10.91 881.76 8.46 13. 52 880.19 27.23 13.16 946.23 9.81 13.63 943.84 37.18 15. 56 1005.75 11.05 15.38 1002.38 47.61 18.27 1069.06 11.63 14.63 1064.45 59.63 21.49 1130.91 12.28 16.32 1124.96 71.98 24.91 1193.73 13.13 17.08 1186.24 85.21 28.88 1255. 57 13.73 15.77 1246.39 98.99 32.94 1317.14 14.88 16. 57 1306.05 113.59 37.18 1380.40 16.77 15.63 1366.91 130.17 41.96 1443.09 17.71 14. 50 1426.78 148.11 46.78 1505.09 19.57 14.53 1485. 53 167.29 51.75 1565.39 20.55 15.41 1542.17 187.27 57.09 1601.10 20.68 16.67 1575. 59 199.36 60. 57 1663.12 21.94 17.64 1633.37 220.89 67.22 1725.41 22.47 15.75 1691.04 243.44 73.98 1787.76 23.83 15.73 1748.37 267.03 80.63 1849.25 25.18 17.32 1804.32 291.48 87.89 1911.55 27.10 17.70 1860.25 317.65 96.15 1972.68 28.76 18.22 1914.26 344.88 104.98 2035.67 30.19 17.61 1969.09 374.37 114.51 2095.91 30.14 17.89 2021.17 403.20 123.74 2159.30 31.02 17.36 2075.75 433.94 133.50 2221.68 30.75 17.48 2129.28 464.49 143.09 2283.50 30.33 16.94 2182. 53 494. 50 152.39 2345.31 30. 58 16.75 2235.81 524.48 161.46 2407.20 30.99 16.09 2288.98 554.87 170.42 2469.28 30.63 16.46 2342.30 585.39 179.33 2532.12 31.30 15.78 2396.18 616.45 188.30 Page 1 s . KBU 42-06Y Definitive Surveys 2593.49 31.43 16.01 2448.58 647.17 197.05 2655.72 30.98 15.85 2501.81 678.17 205.90 2717.60 30.40 15.98 2555.02 708.55 214.56 2779.25 31.31 16.48 2607.95 738.90 223.40 2841.05 31.66 16.67 2660.65 769.84 232.61 2903.97 31.13 17.08 2714.36 801.20 242.12 2966.21 30.55 16. 55 2767.79 831.75 251.35 3028.27 30.65 16.28 2821.21 862.05 260.28 3090.20 31.89 15.45 2874.14 892.97 269.06 3152.09 32.52 14.67 2926.51 924.82 277.63 3214.25 32.11 14.94 2979.05 956.95 286.12 3276.49 31.88 14.62 3031.83 988.83 294. 53 3338.84 31.43 14.81 3084.90 1020.48 302.85 3400.50 31.03 14. 53 3137.63 1051.41 310.94 3462.59 30. 54 14. 53 3190.97 1082.17 318.92 3524.62 30.02 14.64 3244. 54 1112.44 326.79 3586.72 29.65 15.04 3298.41 1142.31 334.70 3648.72 30.05 15.42 3352.18 1172.08 342.81 3710.23 30.00 15.39 3405.44 1201.75 350.99 3772.41 29.73 15.69 3459.36 1231.58 359.28 3834.53 29.50 15. 51 3513.36 1261.15 367. 54 3896.80 29.99 17.37 3567.43 1290.78 376.28 3959.07 30.18 18.08 3621.31 1320. 51 385.79 4020.67 30.90 16.66 3674.37 1350.38 395.13 4082.55 31.36 16.23 3727.34 1381.07 404.18 4144.55 31.07 16.70 3780.36 1411.88 413.29 4205.65 30.70 16. 59 3832.80 1441.93 422.27 4268.63 30.33 15.93 3887.05 1472.63 431.23 4330.79 30.03 15.87 3940.79 1502.68 439.79 4392.80 29.72 15.83 3994. 56 1532.40 448.22 4454.98 29. 51 16.22 4048.61 1561.93 456.71 4516.84 30. 50 16.45 4102.18 1591.61 465.41 4578.69 30.84 16.67 4155.38 1621.85 474.40 4641.29 30. 56 16.74 4209.21 1652.47 483. 59 4703.17 30.39 16.96 4262. 54 1682. 50 492.68 4765.40 30.07 16.94 4316.31 1712.47 501.82 4827.59 29.89 16.90 4370.18 1742.20 510.86 4889.67 30.72 17.82 4423.77 1772.10 520.21 4951.40 31.62 17.65 4476. 59 1802. 53 529.94 5013.68 31.24 17.83 4529.73 1833.46 539.84 5075.64 31.19 17.73 4582.72 1864.04 549.64 5137.44 30.81 17. 52 4635.70 1894.37 559.28 5199.44 30.46 17.46 4689.04 1924. 51 568.78 5261.65 30.29 18.37 4742.71 1954.44 578.45 5324.09 30.03 18.09 4796.70 1984.23 588.27 5385.28 29.60 17.69 4849.79 2013.19 597.61 5447.51 30.06 18.01 4903.78 2042.65 607.10 5508.25 30.62 18.18 4956.20 2071.82 616.63 5571.88 30.30 18.07 5011.04 2102.47 626.67 5633.76 30.15 17.96 5064. 51 2132.09 636.30 5696.13 29.93 18.33 5118. 50 2161.76 646.02 5756.90 29.73 18.19 5171.22 2190.47 655.50 5819.82 29. 57 18.49 5225.90 2220.02 665.29 5881.51 29.71 18.51 5279.52 2248.95 674.97 5943.76 30.51 16.19 5333.37 2278.75 684.27 6006.44 30. 55 15.45 5387.36 2309.39 692.95 6068.36 30.18 15.45 5440.79 2339. 56 701.29 6129.47 29.96 15.13 5493.68 2369.09 709.37 6191.67 29.97 15.14 5547.56 2399.08 717.48 6254.15 29.83 15.48 5601.73 2429.12 725.70 6315.93 29.73 15.30 5655.35 2458.71 733.84 6377.79 29.46 16.06 5709.14 2488.12 742.10 6449.72 29.24 15.73 5771.83 2522.03 751.76 Page 2 KBU 42-06Y Definitive Surveys 6506.58 29.97 17.31 5821.27 2548.95 759.75 6568.79 31.01 17.30 5874.88 2579.09 769.14 6630.74 31.29 17.36 5927.90 2609.68 778.68 6693.02 31.12 16.89 5981.16 2640.52 788.18 6755.20 30.66 16.07 6034. 52 2671.13 797.24 6816.23 30.91 15.84 6086.96 2701.16 805.83 6877.10 31.00 15.72 6139.16 2731.29 814.34 6939.49 31.30 15.69 6192.55 2762.36 823.08 7003.09 31.23 15.61 6246.91 2794.14 831.98 7064.88 30.70 16.04 6299.90 2824.73 840.65 7127.13 30.42 16.03 6353.50 2855.15 849.39 7189.02 30.00 15.73 6406.99 2885.10 857.91 7251.14 27.43 14.89 6461.46 2913.88 865.80 7313.26 26.16 13.70 6516.91 2941.01 872.72 7374.77 24. 51 14.68 6572.50 2966. 53 879.17 7437.42 23.09 16.13 6629.82 2990.91 885.87 7498.68 22.87 15.58 6686.22 3013.91 892.41 7561.10 22.07 15.33 6743.90 3036.91 898.77 7621.41 21.12 15.00 6799.98 3058.33 904.57 7684.81 19.72 14.73 6859.39 3079.71 910.25 7747.13 19.13 15.26 6918.17 3099.73 915.61 7809.13 16.73 18.48 6977.15 3118.00 921.12 7871.57 16.62 18.27 7036.97 3135.00 926.76 7929.20 16.24 17.43 7092.24 3150.51 931.76 7994.75 15.87 16.86 7155.24 3167.84 937.11 8056.79 15. 50 17.49 7214.97 3183.86 942.06 8119.54 14.99 18.06 7275. 51 3199.57 947.09 8181.83 15.02 17.92 7335.67 3214.91 952.07 8244.00 14.78 17.67 7395.75 3230.13 956.96 8305.33 14.50 17.54 7455.09 3244.91 961.65 8368.78 14.38 17.30 7516.54 3260.00 966.39 8429.68 12.50 16.86 7575.77 3273.53 970.55 8491.48 11.71 16.28 7636.19 3285.95 974.24 8553.38 9.16 17.44 7697.06 3296.68 977.48 8613.15 7.14 19.39 7756.23 3304.73 980.14 8678.61 7.20 19.35 7821.18 3312.44 982.85 8740.58 6.87 18.16 7882.68 3319.62 985.29 8802.57 6.85 15.63 7944.23 3326.71 987.44 8864.97 6.56 15.37 8006.20 3333.73 989.39 8925.67 6.53 14.86 8066.50 3340.40 991.20 8988.04 6.21 12.77 8128.49 3347.12 992.85 9050.13 6.06 12.47 8190.22 3353.60 994.30 9112.03 5.92 12.41 8251.78 3359.91 995.69 9174.80 5.58 11.51 8314.24 3366.06 997.00 9237.17 5.72 10.71 8376.31 3372.08 998.18 9299.39 5.69 9.96 8438.22 3378.17 999.29 9361.25 5.39 7.89 8499.79 3384.07 1000.22 9423. 50 5.39 7.81 8561.76 3389.86 1001.02 9483.77 5.15 6.76 8621.78 3395.35 1001.72 9545.33 5.30 7.76 8683.08 3400.91 1002.43 9609.37 5. 50 7.06 8746.84 3406.89 1003.21 9670. 53 5.23 6.05 8807.73 3412.57 1003.86 9732.97 5.16 5.67 8869.91 3418.19 1004.44 9795.66 4.90 4.67 8932.36 3423.66 1004.93 9857.00 4.89 5.27 8993.48 3428.88 1005.39 9919.09 4.68 4.98 9055.35 3434.04 1005.85 9980.94 4.41 5. 52 9117.01 3438.92 1006.30 10042.29 4.26 5.94 9178.18 3443.53 1006.76 10104.37 3.84 6.12 9240.11 3447.89 1007.22 10166.92 3.61 4.14 9302. 52 3451.94 1007.59 10229.19 3.40 2.98 9364.68 3455.74 1007.82 10291.04 3.58 4.44 9426.41 3459.50 1008.07 10353.12 3.67 3.80 9488.37 3463.41 1008.35 Page 3 KBU 42-06Y Definitive surveys 10415.40 3.41 3.20 9550.53 3467.25 1008.59 10476.96 3.58 3.44 9611.98 3471.00 1008.80 10539.73 3.54 1.64 9674.62 3474.89 1008.98 10601.39 3.06 1.38 9736.18 3478.44 1009.07 10663.46 2.94 1.44 9798.17 3481.68 1009.15 10725.82 2.66 359.38 9860.45 3484.73 1009.18 10787.68 2.41 359.68 9922.25 3487.47 1009.15 10856.69 2.09 358.65 9991.21 3490.17 1009.12 10895.00 2.09 358.65 10029.49 3491.57 1009.08 Page 4 Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. KBU 42-06Y Date 28-Jul-14 County KPB State Alaska Supv. Mike Leslie/Shane Barber to CASING RECORD 5`C" "r"."- TD 1603.00 Shoe Depth: 1595.00 PBTD: 1595.00 Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top SHOE 10 3/4" 45.5 _ BTC Weatherford 1.90 1,595.25 _ 1,593.35 2 10 3/4" 45.5 L-80 BTC US STEEL 83.33 1,593.35 _ 1,510.02 Float collar 10 3/4" 45.5 BTC Weatherford 1.45 1,510.02 1,508.57 36 10 3/4" 45.5 L-80 BTC US STEEL 1,482.82 1,508.57 25.75 Pup 10 3/4" 45.5 L-80 BTC US STEEL 2.15 25.75 23.60 Hgr 0.65 23.60 22.95 RKB 22.95 22.95 0.00 Totals Csg Wt.On Hook: 72 Type Float Collar: Weatherford No.Hrs to Run: 6 Csg Wt.On Slips: 54 Type of Shoe: Weatherford Casing Crew: Weatherford Fluid Description: Spud Mud 9.1 Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: 19 AT 80' CEMENTING REPORT Preflush(Spacer) — Type: SEAL BOND Density(ppg) 10 Volume pumped(BBLs) C 1 Lead Slurry Type: TYPE 1 Density(ppg) 12.5 Volume pumped(BBLs) 98 Mixing/Pumping Rate(bpm): 3.4 Tail Slurry Type: TYPE 1 Density(ppg) 15.2 Volume pumped(BBLs) 67 Mixing/Pumping Rate(bpm): 3.6 11 Post Flush(Spacer) N Type: Density(ppg) Rate(bpm): Volume: o: IL Displacement: Type: Spud Mud Density(ppg) 9.1 Rate(bpm): 5 Volume(actual/calculated): 145/145 FCP(psi): 525 Pump used for disp: MP#1/Rig Plug Bumped? X Yes No Bump press 1175 Casing Rotated? Yes X No Reciprocated? Yes x No %Retums during job 100 Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf: 37 SPACER CEMENT) Cement In Place At: 15:40 Date: 7/28/2014 Estimated TOC: SURFACE Method Used To Determine TOC: VISUAL/Wt Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry w Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): N 0 Post Flush(Spacer) o Type: Density(ppg) Rate(bpm): Volume: ru Displacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes _No Reciprocated? _Yes_No %Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0%excess: 118 Total Volume cmt Pumped: 98(lead)+67(tail)=165 bbls / Cmt returned to surface: 43 Calculated cement left in wellbore: 165-43=122 bbls_ OH volume Calculated: 94 OH volume actual: 100 Actual%Washout: 5 Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. KBU 42-06Y Date 8-Aug-13 County KPB State Alaska Supv. James Lott/Doug Yessak CASING RECORD i e- c 4.,/ti`) TD 6493.00 Shoe Depth: 6483.00 PBTD: 6400.00 Casing(Or Liner)Detail _ Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top SHOE 75/8 BTC Weatherford 1.61 _ 6,483.15 6,481.54 2 7 5/8 29.7 L-80 BTC _ US STEEL 80.40 6,481.54 6,401.14 Float collar 7 5/8 29.7 BTC Weatherford 1.31 _ 6,401.14 6,399.83 154 7 5/8 29.7 L-80 BTC US STEEL 6,375.77 6,399.83 24.06 PUP JT 7 5/8 29.7 L-80 BTC _ US STEEL 2.30 24.06 21.76 HANGER 75/8 BTC SEA BOARD 0.40 21.76 21.36 RKB 21.36 21.36 0.00 Totals Csg Wt.On Hook: 120,000 Type Float Collar: Weatherford No.Hrs to Run: 16 Csg Wt.On Slips: 75,000 Type of Shoe: Weatherford Casing Crew: Weatherford Fluid Description: 9.0 PPG Kla Shield Mud Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: 60 AT 80' CEMENTING REPORT Preflush(Spacer) Type: SEAL BOND Density(ppg) 10 Volume pumped(BBLs) 80 Lead Slurry Type: Class G Density(ppg) 10.5 Volume pumped(BBLs) 170 Mixing/Pumping Rate(bpm): 4 Tail Slurry Type: Class G Density(ppg) 13.5 Volume pumped(BBLs) 27 Mixing/Pumping Rate(bpm): 4 w Post Flush(Spacer) y Type: Density(ppg) Rate(bpm): Volume: ce LL Displacement: Type: Kla Sheild Mud Density(ppg) 9 Rate(bpm): 4.5 Volume(actual/calculated): 295/298 FCP(psi): 570 Pump used for disp: Rig Pump Plug Bumped? X Yes No Bump press ,_ 1070 Casing Rotated? Yes X No Reciprocated? Yes x No %Returns during job 75 Cement returns to surface? Yes x No Spacer returns? Yes x No Vol to Surf: Cement In Place At: 17:15 Date: 8/8/2014 Estimated TOC: 1,575 Method Used To Determine TOC: Calculation Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry w Type: a Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): w Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: Displacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? _Yes No Bump press Casing Rotated? Yes _No Reciprocated? _Yes_No %Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0%excess: 133 Total Volume cmt Pumped: 170(lead)+27(tail)=197 bbls Cmt returned to surface: 0 Calculated cement left in wellbore: 197 OH volume Calculated: 186 OH volume actual: 186 Actual%Washout: • Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. KBU 42-06Y Date 20-Aug-14 County KPB State Alaska Supv. Mike Leslie/Shane Barber CASING RECORD l rp J- C.,---;---) TD 10895.00 Shoe Depth: 10891.80 PBTD: 10805.00 Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top SHOE 5" L-80 DWC Davis Lynch 2.34 10,891.80 10,889.46 2 5" 18 L-80 DWC US STEEL 81.48 10,889.46 10,807.98 Float collar5"_ _ L-80 DWC Davis Lynch 1.84 10,807.98 10,806.14 15 5" 18 L-80 DWC US STEEL 601.89 10,806.14 10,204.25 PUP w/RA 5" 18 L-80 DWC US STEEL 4.76 10,204.25 10,199.49 14 5" 18 L-80 DWC US STEEL 563.51 10,199.49 9,635.98 PUP w/RA 5" 18 L-80 DWC US STEEL 4.75 9,635.98 9,631.23 5 5" 18 L-80 DWC US STEEL 201.13 9,631.23 9,430.10 PUP w/RA 5" 18 L-80 DWC US STEEL 4.64 9,430.10 9,425.46 85 5" 18 L-80 DWC US STEEL 3405.13 9,425.46 6,020.33 Pup 5" 18 L-80 DWC US STEEL 2.84 6,020.33 6,017.49 Swell Packer 5x8 18 DWC Baker 11.93 6,017.49 6,005.56 Pup 5" 18 L-80 DWC US Steel 6.2 6,005.56 5,999.36 Pup 5" 18 L-80 DWC US Steel 19.67 5,999.36 5,979.69 148 5" 18 L-80 DWC US Steel 5946.83 5,979.69 32.86_ Cut Jt 5" 18 L-80 DWC US Steel 14.36 32.86 18.50 RKB 18.5 18.50 0.00 Totals Csg Wt.On Hook: 160,000 Type Float Collar: Davis Lynch No.Hrs to Run: 15 Csg Wt.On Slips: 140,000 Type of Shoe: Reamer Casing Crew: Weatherford Fluid Description: 12.0 ppg Kla-Shield Liner hanger Info(Make/Model): NA Liner top Packer?: _Yes X No Liner hanger test pressure: NA Centralizer Placement: 61 AT 80' CEMENTING REPORT Preflush(Spacer) Type: SEAL BOND Density(ppg) 13 Volume pumped(BBLs) 43..7 Lead Slurry Type: Class G Density(ppg) 15.7 Volume pumped(BBLs) 145 Mixing/Pumping Rate(bpm): 4.5 Tail Slurry Type: ) Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): (7, Post Flush(Spacer) w ',,71 Type: Density(ppg) Rate(bpm): Volume: iL Displacement: Type: 6%KCL Density(ppg) 8.6 ppg Rate(bpm): 6 Volume(actual/calculated): 192/193 FCP(psi): 3100 Pump used for disp: Baker Plug Bumped? X Yes No Bump press 3600 Casing Rotated? Yes X No Reciprocated? Yes x No %Retums during job 87d Cement returns to surface? Yes x No Spacer retums? Yes x No Vol to Surf c t!' Cement In Place At: 2:55 Date: 8/20/2014 Estimated TOC: 4,150 Method Used To Determine TOC: Calculation of lift pressure 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): E,� Post Flush(Spacer) 0 z Type: Density(ppg) Rate(bpm): Volume: ty Displacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? _Yes No Bump press Casing Rotated? Yes _No Reciprocated? _Yes_No %Returns during job Cement retums to surface? _Yes_No Spacer retums? Yes_No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0%excess: 89.7 Total Volume cmt Pumped: 145 Cmt returned to surface: 0 Calculated cement left in wellbore: 145 OH volume Calculated: 88 OH volume actual: 95.3 Actual%Washout: 0.06 F-' Oa rn� F_Li O O p u )-0 Q 0 271- 0 co co > co L., >,- - +N-+ O C o [•iGI o n r 0 < -OO c W - - aC Vs_ N> >, a) c 0O U •a' 0 3 `O N N' o 0 Q) C .0 C CU _ Q) N ° a) (6 ° - EO .- L CD -0 cn w ` ._. co .. e- _ 0 o-g di N m N Q _ 0 Z a)-= ..• 0 1 7 0 -e N '_ _ >.= L. L r. lA m d r c 2 `40 a, m4 m '6 t a L r ,,n N — _ cc co O o N o 0 N No 11l•• ani, t- r- C -0 _ O N� n a) Cl m70 Lrl p) a o - N 0 0- U �13 - c O U 0 O N en NNc ti T t0 a) m _ o o U o 0)-- N Q) t. 0 m= 0 0 N• T -C2) CD -(H-Ek O U i. ° N L U Z y a N o ZCI v —�-- �3 a 1:52 5( I- W 0 co co 3 o m o IX 2 co 0 = C N • r p a my I- v • laQ DoUwo.m D _ in I i -0_0 m -1 Q Y o 0 0 °o0 0 0 0 °o JO � Qs 0 0 0 0 0 0 0 r U Q o 0 CO (0 (N N _o 0 co I • o2 KBU 42-06Y MW Vs Depth o - — iMW vs Depth 1000 - - 2000 — --- ——— — 3000 —— — 4000 — 5000 — -c /. 0. v 6000 v, co m 7000 — — 8000 ------- - 9000 — 10000 11000 — — 12000 - 8 9 10 11 12 13 14 Mud Density(ppg) KBU 42-06Y Days Vs Depth 0 , �KBU 42-06Y 1000 �KBU 42 06Y Plan 2000 . 3000 4000 5000 Q d 0 v 6000 - d L a VI 03 d 7000 1444 , 8000 9000 10000 11000 12000 0 5 10 15 20 25 30 35 Days .2_‘z_k-0(6. L ra Oudean Hilcorp Alaska, L. 2.24613`) GeoTech II 3800 Centerpoint Drive, Suite 100 2 �,t Anchorage, AK 99503 `�, Tele: 907 777-8337 lli61191 u:t.kii.1.1.i Fax: 907 777-8510 i >r d. " ,"°`° E-mail: doudean@hilcorp.com DATA LOGGED OCT 0 o CU14 "'i01 /201 K BENDER DATE 10/07/14 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 42-06Y MUDLOG DATA Prints: Final Well Report 5" Formation Log MD 5" Formation Log TVD 2" Formation Log MD 2" Formation Log TVD 2" LWD Combo Log MD 2" LWD Combo Log TVD 2" Drilling Dynamics MD 2" Drilling Dynamics TVD 2" Gas Ratio Log MD 2" Gas Ratio Log TVD CD 1 : Digital Log Data A Files Currently on the Disc (7) Ai DAILY REPORTS 10/4/2014 12:40 PM File folder 1. DML DATA 10/4/2014 12:40 PM File folder A FINAL WELL REPORT 10/4/2014 12:40 PM File folder A LAS FILE 10/4/2014 12:40 PM File folder 1 LOG PDF FILES 10/4/2014 12:40 PM File folder A LOG TIFF FILES 10/4/2014 12:40 PM File folder SHOW REPORTS 10/4/2014 12:40 PM File folder CD 2: Definitive Survey Data 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: v O—e4ate: 1/4°(1104 LA" 01S1 11 L .ra Oudean Hilcorp Alaska, L. 2-24°1 3� GeoTech Ii 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 Hilrarp Alaskn,LL(: Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATA LOGGED / /201 K.BENDER DATE 10/07/14 To: Alaska Oil & Gas Conservation Commission Vi ra L.4:0 Makana Bender OCT 0 8 2014 Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 AO G CC DATA TRANSMITTAL KBU 42-06Y E log data Prints: DGR EWR-Phase 4 ALD CTN TVD ROP DGR EWR-Phase 4 ALD CTN MD BAT DGR EWR-Phase 4 ALD CTN MD BAT DGR EWR-Phase 4 ALD CTN TVD CD 1 : Digital Log Data CGM 4/25/2014 2:43 PM File folder DLIS+LAS 4/25/2014 2:43 PM File folder EMF 4/25/2014 2:43 PM File folder PDF 4/25/2014 2:44 PM File folder TIFF 4/25/2014 2:45 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 tt ✓fi ‹.-5-75 ...e.414", Date: 2 i q- of5c1 1 11 Debra Oudean Hilcorp Alaska, LLC GeoTech II 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 lEul.iiip Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 9/15/2013 RECEIVED To: Alaska Oil & Gas Conservation Commission SEP 15 2014 Makana Bender, Natural Resource Technician AOGCC 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL Transmitted herewith are cuttings WELL BOX # SAMPLE INTERVAL KBY 42-06Y BOX 1 6493'- 7500' KBY 42-06Y BOX 2 7500'- 8720' -- KBY 42-06Y BOX 3 8720'- 9800' KBY 42-06Y BOX 4 9800'- 10895' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Receivelvt Date: RECEIVED SEP 1 5 2014 AOGCC ®F Tie ly,�w \�\1'// 1, \ THE STATE h_£a@; a 1 i_ tat._�c; ,,6 - ter.v\ i I / \ / ._ _- _ _ lits tt= =- 333 west Seventh Avenue Ut-- _-_:may `y"� �F GOVERNOR SEAN PAR N1;T_!_ Anchorage, Alaska 99501-3572 -�" -_,t," Min. 907 279 143' ��;:.k.sFa; 907 2/6 7522 A 1 42 T-- act Paul Chan Senior Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Field, Beluga/Upper Tyonek and Tyonek Gas Pool, KBU 42-06Y Sundry Number: 314-482 Dear Mr. Chan: 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, 014-- 7 Daniel T. Seamount, Jr. Commissioner DATED thisV day of August, 2014. Encl. RECEIVED STATE OF ALASKA AUG 2 2 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION � " $1�1 J�� APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate 2. Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other. Complete Q. 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development E. 214-089 . 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20634-00 7.If perforating: 8.Well Name end Number: What Regulation or Conservation Ordergoverns well spacing in thispool? CL7 5/u " 9 P 9 Y-45-/t/ Kenai Beulga Unit(KBU)42-06Y - Will planned perforations require a spacing exception? Yes ❑ No R 9.Property Designation(Lease Number): 10.Field/Pool(s): FEE A028142 Kenai/Beluga/Upper Tyonek Gas and Tyonek Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,895 10,029 10,805 9,940 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16" 135' 135' Surface 1,595' 10-3/4" 1,595' 1,570' 5,210psi 2,470psi Intermediate 6,483' 7-5/8" 6,483' 5,801' 6,890psi 4,790psi Production 10,895' 5" 10,892' 10,026' 10,140psi 10,490psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal Q . 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑� Service ❑ 14.Estimated Date for 115.Well Status after proposed work: 08/2�p/14 ( Commencing Operations: �/ 4j4� Oil 0 Gas Q WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan Phone: 907-777-8333 Email pchanphilcor•.c Printed Name Paul Chan Title Senior Operations Engine- / CfSignature Phone 907-777-8333 Date g(2'z1"i COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 2\R.-Lk%2 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ^ )- Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /G,. 44-6 APPROVED BY ��JZ 1 Approved by: ` / COMMISSIONER THE COMMISSION Date: J / / �� 2. �/'� Submit Form and �DM§rm A Ug3IR ised 1 /2 2) Appro�e�dll©o1 NI o�12 months from the date of approval. /Zf/ gttachme sin Duplicate H •�2 �� t ' v L , l tI L te." Well Prognosis • Well: KBU 42-06Y AFE: 1411969C Elilcorp Alaska,LL Well Name: KBU 42-06Y API Number: 50-133-20634-00-00 Current Status: New Gas Well • Leg: N/A Estimated Start Date: 8/29/2014 Rig: N/A Reg.Approval Req'd? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-089 First Call Engineer: Paul Chan (907) 777-8333 (0) (907) 345-3161 (H) (907)444-2881 (C) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907)331-8228 (C) Estimated Bottom Hole Pressure: —4,279 psi at 9,110'TVD (Assumed 0.45 psi/ft gradient) . Max.Anticipated Surface Pressure: —3,453 psi (0.075 psi/ft gas gradient) Brief Well Summary: KBU 42-06Y was drilled and cased/cemented in August 2014. Objective: • Initial perforations in the Tyonek D sands S - .11 E-Line Procedure UZ t" F "1 P 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/4,000 psi high. Note that the well is pressurized with nitrogen. 2. If necessary, bleed nitrogen pressure down as requested by the RE to establish a drawdown on the formation. RA markers are at 9,425',9,631', 10,199' MD as per the Casing and Cementing Report dated 8/20/2014. 3. Perforate the Tyonek D sands with 2-7/8" 6 SPF 60 deg phased GEODynamics Connex gun. Depths are • from the Halliburton quad combo composite run while drilling the well. The perforated interval will be adjusted once the GR/CCL jewelry log has been. Send the correlation pass to Paul Chan and Sarah Rittenhouse for confirmation. Gross Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Tyonek D-5 10,340' 10,430' 90 Tyonek D-4 10,280' 10,335 55 Tyonek D-3 10,045 10,330 285 Tyonek D-2 9,810' 10,325' 515 4. POOH. 5. Flow well through test separator and record water and gas rates 6. If any of the Tyonek D sands are not commercial,then the zone will either: a. Be plugged back with a CIBP set above a non-commercial Tyonek D sand or b. Covered with a tubing/casing patch if there are productive intervals below 7. RD a-line. 8. Turn well over to production. Attachments:As-built Well Schematic and Proposed Well Schematic Kenai Gas Field • Jell: KBU 42-06Y SCHEMATIC PTD: 214-089 Mears'Alaska,LLC C API: 50-133-20634-00 RKB:MSL=18.5' CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 16" Conductor 109/X-56/Weld Surf 135' 16" 10-3/4" _ Surface 45.5/L-80/BTC 9.950 Surf 1,595' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,483' 5" Production 18/L-80/DWC/C-HT 4.276 Surf 10,892' JEWELRY DETAIL 10-3/4" No Depth Item 1 6,006' 5"Swell Packer 2 9,425' RA Pup 3 9,631' RA Pup 4 10,199' RA Pup OPEN HOLE/CEMENT DETAIL 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface 7-5/8" 197BBL's of cement in 9-7/8"Hole.TOC 1,575'Calculated 5" 145BBL's of cement in 6-3/4"Hole. TOC 4,150'Calculated o �y� 7-5/8" A ��(a3 MD 0 2 33 4 5" A PBTD=10,805'MD/9,940'TVD TD=10,895'MD/10,029'TVD Updated by DMA 08-22-14 Kenai Gas Field VeII: KBU 42-O6Y PROPOSED PTD: 214-089 Mean)Alaska,LLC API: 50-133-20634-00 RKB:MSL=18.5' CASING DETAIL iSize Type Wt/Grade/Conn ID Top Btm 1 16" Conductor 109/X-56/Weld Surf 135'950 Surf 1,595' 16" 10-3/4" Surface 45.5/L-80/BTC 9. 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,483' 5" Production 18/L-80/DWC/C-HT 4.276 Surf 10,892' .1 JEWELRY DETAIL 10-3/4".4 , No Depth Item 1 6,006' 5"Swell Packer 2 9,425' RA Pup 3 9,631' RA Pup 4 10,199' RA Pup OPEN HOLE/CEMENT DETAIL 10-3/4" 165BBL's of cement in 13.5"Hole.Returns to Surface i, 7-5/8" 197BBL's of cement in 9-7/8"Hole.TOC 1,575'Calculated 5" 145BBL's of cement in 6-3/4"Hole. TOC 4,150'Calculated PERFORATION DETAIL • Sands Top(MD) Btm(MD) Top(ND) (Np) FT Date Status D-2 ±9,810' ±10,325' ±8,947' ±9,460' ±515' TBD Proposed D-3 ±10,045' ±10,330' ±9,181' ±9,465' ±285' TBD Proposed D-4 ±10,280' ±10,335' ±9,415' ±9,470' ±55' TBD Proposed D-5 ±10,340' ±10,430' ±9,475' ±9,565' ±90' TBD Proposed 7-5/8" 42 !t 3 e =D -2 W r. r: -4 Cia I 0.s � ' 05 4e1 PBTD=10,805'MD/9,940'1VD TD=10,895'M)/10,029'TVD Updated by DMA 08-22-14 Hilcorp Alaska, LLC Post Office Box 244027 Anchorage,AK 99524-4027 RECEIVED 3800 Centerpoint Drive Suite 1400 AUG 2 2 2014 Anchorage,AK 99503 Phone: 907/777-8412 AOGCC Fax: 907/777-8310 August 22, 2014 Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Additional Coiled Tubing Work at Kenai Gas Field Well KBU 42-06Y (PTD 214-089) Dear Commissioner Foerster: Attached for your information are additional wells that Hilcorp AK has identified that require coiled tubing operations but do not require sundry approval. The wells listed below in bold print are in addition to the original wells requested in our letters dated June 17, May 28, May 7, 2014 and February 12, 2014. Our company supervision will give notice during the initial rig up of the Coiled Tubing BOPE for the initial 250 psi low/ 4500 psi high BOPE test. Below is a list of the wells and the proposed coiled tubing work: SD-07 (PTD 211-050) Fill Cleanout+Ad Perfs SD-08 (PTD 213-051) Fill Cleanout+ Blow well down SD-02A (PTD 213-153) Fill Cleanout KBU 11-08Z (PTD 214-044) Blow well down KBU 33-6X (PTD 203-183) Fill Cleanout KBU 23-05 (PTD 214-061) Blow well down r--) KBU 42-06Y (PTD 214-089) Blow well downTh If you need any additional information, you can contact me at-'907-777-8333. Sincerely, HILCORP ALASKA, C 0 C Paul Chan Senior Operations Engineer pc „�\\I %s THE STATE almLaa(7LC. � L' rt, ., off_ /, % % 333 1.,vie t Seventn Avenue GO\'LR\OR SEAN PA RNILL Afchoacge, Alaska 99501-3572 v.oin 907 279 1/3? i f _ c=, _, Luke Keller Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Kenai Field, Beluga/Upper Tyonek Gas and Tyonek Gas Pool, KBU 42-06Y Hilcorp Alaska, LLC Permit No: 214-089 (revised) Surface Location: 83' FNL, 1009' FEL, Sec. 7, T4N, R11 W, SM, AK Bottomhole Location: 2146' FNL, 100' FEL, Sec. 6, T4N, R11 W, SM, AK Dear Mr. Keller: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy Foerster Chair Lk DATED this GO day of July,2014. C.CIVCiJ STATE OF ALASKA JUL 15 2014 �7 AL1 0'6 A A OIL AND GAS CONSERVATION COMM )N L \ PERMIT TO DRILL `(�. 44, AOGCC 20 AAC 25.005 1 a.Type of Work: 1 b. Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑ 1 c.Specify if well is proposed for: Drill ❑., - Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑✓ - Service-Supply ❑ Multiple Zone 2• 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 ' Kenai Beluga Unit(KBU)42-06Y - 3.Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive,Ste. 1400 Anchorage,AK 99503 MD: 10,593' TVD: 9,750' Kenai 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Up Tyonek Beluga Gas - Surface: 83'FNL, 1009'FEL,Sec 7,T4N,R11 W,SM,AK FEE A028142 - Tyonek Gas - Top of Productive Horizon: 8. Land Use Permit: 13.Approximate Spud Date: 2207'FSL,400'FEL,Sec 6,T4N, R11 W,SM,AK - NA(located entirely within unit) 7/19/2014 Total Depth: 9.Acres in Property: 14. Distance to Nearest Property: 2146'FNL, 100'FEL,Sec 6,T4N, R11 W,SM,AK ' 2494 acres 10,798'(unit boundary) 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: -84.8 feet 15. Distance to Nearest Well Open Surface: x-274899.4 ' y-2361930.7 - Zone-4 GL Elevation above MSL: 66.2 feet to Same Pool: 595' 16. Deviated wells: Kickoff depth: 500 feet - 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) 32(0 5' Vr-A Maximum Hole Angle: 30.31 degrees Downhole: 4214 psig - Surface: 1.937 pig(Surface—Drilling) 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) Gond 16" 109 X-56 Weld 150' Surf Surf 150' 150' Driven 13-1/2" 10-3/4" 45.5 L-80 BTC 1,600' Surf Surf 1,600' 1,488' 928.8ft3/165.4bbl 9-7/8" 7-5/8" 29.7 L-80 BTC 6,342' Surf Surf 6,342' 5,800' 916ft3/163.1 bbl 6-3/4" 5" 18 L-80 DWC/C 10,448' Surf Surf 10,593 . 9,750' 764ft3/136bb1 HT 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect. Depth MD(ft): Effect. Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat E BOP Sketch ❑✓ Drilling Program ❑✓ Time v. Depth Plot ❑✓ Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program E 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Janise Barrett Email jbarrett@hilcorp.com Printed Name L ke eller Title Drilling Engineer ez.,Signature / Phone 907-777-8369 Date 7/15/2014 Commission Use Only Permit to Drill API Number: Permit Approval , See cover letter for other Number: 214-089 '(g\/T,rj(a) 50- 133-20634-00-00 Date: /3//L/ requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: 12/n Other: 5G 7- 57)< t 7,u 3� c y 5 r Samples req'd: Yes LI Nog Mud log req'd:Yes El No/ c 25 '035-4) 35 i H2S measures: Yes ii No 3 Directional svy req'd:Yes g No❑ D/'t/(r fr✓ W 4 l'1"-of 1�t✓ 071)/1/4 Spacing ezdeption req'd: Yes 11] NoEl Inclination-only svy req'd:Yes❑ No® e B L r-rvl'ri 09 r ' - APPROVED BY Approved by. COMMISSIONER THE COMMISSION Date: 7 Z 3-/ / aunmit corm ana Form 10-401(--vised 10/2012) ThisO1ItfAL r is v f r 4 hom the date of approval(20 AAC 25.005(g)) Attachments in Duplicate VL 7/z z /14- 2.r5� � 7-4, i Hilcorp Alaska, LLC P.O. Box 244027 Luke Keller Anchorage, AK 99524-4027 Drilling Engineer Tel 907 777 8395 Hilcorp Email Ikeller@hilcorp.com Energy Company July 15th, 2014 RECEIVED Commissioner JUL 1 5 2014 Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue ^O^�^ Anchorage, Alaska 99501 !'1 VI v Re: Kenai Beluga Unit(KBU)42-06Y 10-401 Permit to Drill Application (Change to Surface Location) Dear Commissioner, v/ Enclosed for review and approval is a revision to the surface location for KBU 42-06Y Development Gas well. There is a difference of 10' from the surface location in the approved PTD, and the "As Built" survey that was conducted after the conductor was driven. The following documents are enclosed with this revision to the approved PTD: 1. Revised 10-401 (Differences in approved PTD are highlighted for easy reference) 2. Revised directional plan. 3. "As Built" Surface plat. All other items remain the same as on original submission. Please contact myself at 777-8395 or Ikeller@hilcorp.com if additional information is required. Sincerely, i Luke Keller Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 to—— .-T—..1 I MT u _. LIMR2 .00TPRINT KBU 42-06YI EDGE OF PAD ---'–j ! r AS-BUILT NAD 27 ASP ZONE 4 K.B.U.34-6 1 NORTH • N: 2361930.67 0 vuiiimo„ E: 274899.43 �ISI LAT: 60° 27' 33.449"N K.B.U. 11-8Y \ LON: 151° 14'49.324"W FEL: 1009' K.B.U.33-6X K.B.U. 11-8X FNL: 83' K.B.U.12-5 W °w u^w w w • ELEV: 66.2' W K.B.U.41-6 K.B.U.43-7X K.B.U.42-6 • — a SECTION LINE6 5 K.B.U.33-6 K.B.U.24-6H I f 7 8 83' FNL (W)* C- 0 e K.B.U.44-6 • I N 2361999.63 K.B.U.42-7 K.B.U.32-7 1 E 275909.61 . K.T.U.32-7H 1009' FEL (NTS) 0) 20"Conductor K.U. 13-5 \ ® ................. r._... \ K.D.U.9 1,./f- x,.1.... I I 101 • 14-4::::.-11„.] K.B.U.41-7 1 0 Li , I K.U.43-6 RD I I ---\- \ W 1 K.U.43-6X` K.B.U.41-7X it Y 0 / SITE EMERGENCY K.D.U.4 K.U.43-6A 1 O - SHUT DOW;SWITCH SECTION 7, T4N, R11W, S.M., AK 11 0 - TO 14-6 Z PL PL - K.D.U.2 K.U.24-5 RD 1 W ._ 1 Ti 1----' Z 10, Lw.J ) JUNCTION BOX '. Z w/GUARD yIPE O ..._ :` L.•:.:..`: Ks"K.U.11-8 / I— , E.;:,''. U � .� ' K.U.43-7 UTION* KENAI GAS L �.. r � ..-_ HI H PRESSURE FIELD L TERAL GAS PIPELINE TO 41-18 PAD41-7 PL PL I `.0,\11.1X1 1.BASIS OF HORIZONTAL COORDINATES ARE KDU 10 Q• S i, ALASKA STATE PLANE NAD27 ZONE 4 As Staked G7`.. ��i .'T DETERMINED BY A DIRECT TIE TO USC&GS TRI KBU 11-08Z . * • :.49TH �� •..' / STA AUDRY HAVING A PUBLISHED POSITION OF O ® I ..... / LAT.60°30'50.559"N LONG.151°16'37.445"W sib N:2382045.42 E:269866.75 2)BASIS OF VERTICAL DATUM IS MEAN SEA / ' M. SCOTT McLANE: f - LEVEL. l /� sT... 07/10/2014 .�,' 3)NORTHEAST CORNER SEC.7 COORDINATE 1 I 1 / c' ••. 4928—S •• J � DETERMINED FROM DIRECT SURVEY TIE TO THE \ �� a ••' •••• •�P• � AND WC 3TO /4 CORNER SEG BLM WC CTIONS S 6C0&7 RECOVERED RNER SEC.7 �� I 1 1 -13 ,''I 11‘N.NN`` AND NOT THE PROTRACTED SECTION CORNER j 'j I II 0 100 200 VALUES. , I I I 1 1 FEET / PROJECT _REVISION: 1 ,(4\-- /// HILCORP ALASKA LLC DATE: 7/10114 Consulting Inc KBU 42-06Y AS-BUILT DRAWN BY: MSM Mcg LANE/ KENAI GAS FIELD PAD 41-7 SCALE: 1"=100' `�� SURFACE LOCATION DIAGRAM NAD27 PROJECT NO. 143079 ENGINEERING/MAPPING/SURVEYING/TESTING BOOK NO. 14-08 P.O.BOX 468 SOLDOTNA,AK.99669 LOCATION VOICE:(907)283-4218 FAX:(907)283-3265 SHEET EMAIL:SAMCLANE©MCLANECG.COM Hilc.orp Alaska. LLC S7 T4N R11 W SEWARD MERIDIAN, ALASKA 1 OF 1 a 3 Hilcorp Energy Company Kenai Gas Field KGF 41-7 Pad F Plan: KBU 42-06Y KBU 42-06Y Plan: KBU 42-06Y wp3.0 Standard Proposal Report 15 July, 2014 J a i FEW: HALLIBURTON awn - Sperry Drilling Services HAL„ ct: Kenai Gas Field WELL DETAILS: Plan; 2-06Y NAD 1927(NADCON CONUS) AlaskaZone04 cite: KGF 41-7 Pad Ground Level: 66.20 Well: Plan: KBU 42-06Y +N/-S +E/-W Northing Easting Latittude Longitude Slot Wellbore: KBU 42-06Y 0.00 0.00 2361930.67 274899.43 60.4592913 -151.2470343 Design: KBU 42-06Y wp3.0 -500- _ ANNOTATIONS o- d 16" TVD MD Inc Azi +N/-S +E/-W VSect Departure Annotation 500.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 Start Dir 2°/100':500'MD,500'TVD 1945.81 2015.51 30.31 16.46 375.54 110.98 391.60 391.60 End Dir :2016'MD,1946'TVD 6536.13 7332.66 30.31 16.46 2948.98 871.51 3075.06 3075.06 Start Dir 3°/100':7333'MD,6536'TVD 500- 500 7500.00 8343.00 0.00 16.25 3199.34 945.50 3336.13 3336.13 End Dir :8343'MD,7500'TVD 9750.00 10593.00 0.00 16.25 3199.34 945.50 3336.13 3336.13 Total Depth:10593'MD,9750'TVD 1000- 1000 Start Dir 2°/100':500'MD,500'TVD y00 1500- End Dir :2016'MD, 1946'TVD - 10 3/4" - 2Q0- 2000- FORMATION TOP DETAILS 2500 TVDPath TVDssPath MDPath Formation 2500- 3589.50 3505.00 3919.46 Sterling 4191.50 4107.00 4616.78 Sterling 5.2 3000 4698.50 4614.00 5204.06 Upper Beluga 5377.50 5293.00 5990.57 Middle Beluga 3000- 6107.50 6023.00 6836.16 Lower Beluga "OP 8765.50 7102.00 8028.07 Upper Tyonek 8765.50 8681.00 9608.50 Tyonek D1 8848.50 8764.00 9691.50 Tyonek D2 3500_ _Sterling A000 9109.50 9025.00 9952.50 Tyonek D3 9314.50 9230.00 10157.50 Tyonek D4 9438.50 9354.00 10281.50 Tyonek D5 00 9491.50 9407.00 10334.50 Tyonek D6 $ 4000- p5 -Sterling 5.2 0 CASING DETAILS: KBU 42-06Y wp3.0 CV 4500- 500 - TVD TVDSS MD Size Name L -- Upper Beluga- 130.00 45.50 130.00 16 16" a = 5p0 1479.82 1395.32 1500.00 10-3/4 10 3/4" 5000- 6 5487.51 5403.01 6118.00 7-5/8 7 5/8" 9750.00 9665.50 10593.00 5 5" To0 r - Middle Beluga- A 0 a) 5500- cu 7 5/8" 6yp0 H - 6000- _Lower Beluga 1000 Start Dir 3°/100':7333'MD,6536'TVD 6500- - 150" 0 7000- --Upper Tyonek $000 End Dir :8343'MD,7500'TVD 7500- 8500 8000- 9000 8500- Tyonek D1 .Tyonek D2 9500 9000- -Tyonek D3. 10000 -Tyonek D4 9500 -_ Tyonek D5 10500 KBU 42-06YBHL-- .1. -___ Tyonek D6 Total Depth: 10593'MD,9750'TVD 10000- 5" KBU 42-06Y wp3.0 10500- -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 Vertical Section at 16.46° (1250 usft/in) Hilcorp HALLIBURTON Project: Kenai Gas Field WELL DETAILS: Plan:KBU 42-06Y Sporry Drilling B.rvrwa Site: KGF 41-7 Pad Ground Level' 66.20 Well: Plan: KBU 42-06Y +N/-S +E/-W Northing Fasting Latittude Longitude Slot Wellbore: KBU 42-06Y 0.00 0.00 2361930.67 274899.43 60.4592913 -151.2470343 Plan: KBU 42-06Y wp3.0 REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well Plan:KBU 42-06Y,True North Vertical(TVD)Reference: KBU 42-06Y:Prelim 84.50usft(147) Measured Depth Reference: KBU 42-06Y:Prelim©84.50usft(147) Calculation Method: Minimum Curvature 4000- SECTION DETAILS Sec MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLeg TFace VSec Target 1 18.10 0.00 0.00 18.10 -66.40 0.00 0.00 2361930.67 274899.43 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 415.50 0.00 0.00 2361930.67 274899.43 0.00 0.00 0.00 3750- 3 2015.51 30.31 16.46 1945.80 1861.30 375.54 110.98 2362304.03 275017.50 2.00 16.46 391.60 4 7332.66 30.31 16.46 6536.13 6451.63 2948.98 871.51 2364862.49 275826.59 0.00 0.00 3075.06 5 8343.00 0.00 16.25 7500.00 7415.50 3199.34 945.50 2365111.40 275905.30 3.00 180.00 3336.13 6 10593.00 0.00 16.25 9750.00 9665.50 3199.34 945.50 2365111.40 275905.30 0.00 0.00 3336.13 KBU 42-06Y BHL 3500- - IKBU42-06YB111} k0U4206y IDD Polygon 95%cont.] WP3.0 3250- - 5"- Vv' --__ Total Depth:10593'MD,9750'TVD End Dir :8343'MD,7500'TVD 3000- 6750 6500 2750- 6250 6000 2500- 575p 75/8"-- '`6500 C - w 2250- 5230 O 5000 + 2000- 4250 O _ 1750- 4500 4250 1500- 4000 3750 1250- 3500 3250 1000- 3000 2750 750- 2500 CASING DETAILS 500- 2250 TVD TVDSS MD Size Name 130.00 45.50 130.00 16 16" 1479.82 1395.32 1500.00 10-3/4 10 3/4" 2-000-____ 5487.51 5403.01 6118.00 7-5/8 7 5/8" 9750.00 9665.50 10593.00 5 5" / End Dir :2016'MD,1946'TVD 250- 10 3/4" 75p T M Azimuths to True North /1500 Magnetic North:16.86° Magnetic Field 0- 16' -- ;1000__ _ Strength:55357.6snT ----_ Dip Angie:73.44° Start Dir 2°/100':500'MD,500TVD Date:7/19/2014 Model:BGGM2014 -250 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 -500 -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 West(-)/East(+)(500 usft/in) Ililc )F ) HALLIBURTON Project: Kenai Gas Field WELL DETAILS: Plan:KBU42-06Y Site: KGF 41-7 Pad Ground Level 66.20 iOP+erry Ctrilhnq Well: Plan: KBU 42-06Y +N/-S +E/-W Northing Easting Latittude Longitude Slot Wellbore: KBU 42-06Y 0.00 0.00 2361930.67 274899.43 60.4592913 -151.2470343 Plan: KBU 42-06Y wp3.0 REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well Plan:KBU 42-06Y,True North Vertical(TVD)Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Measured Depth Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Calculation Method:Minimum Curvature 37s0 p T M Azimuths to True North – G Magnetic North:16.86° A – 1' Magnetic Field – Strength:55357.6snT 3500— Dip Angle:73.44° ICP U42,42.06 Date:7/19/2014 – , YWP3.0 Model:BGGM2014 – / 4-,9& / 3250— z-6- /,5" r0\ 3000— 4-g 3 Ali" I KBU 42-06Y BHL – 6500 – KTU 43.6XRD G 2750— 9 6250 ar ogfi KU 43 6 A'S 6000 – KC 2500— 43..4•i o ( 7 5/8" 47 2250 06* – ^)- KU 43- A 5p00 2000— T cct – 4750 G7'7S 7 – 4S o� 1750— 00 + '25p t O – `Z 1500— 40„ s – O – 37.50 O – • 1250— G'... 3500 ,tia – `J 3250 1000- - 3000 _ '>SO / a 750— 500— fr/00 � 250— ('f� _ r 10 3 f� 4 Or C Ci – ,fy C1 Cf = o 0— J 7� -250— r. , z d G — 4-TG en n en – co ".?� ',/`'PI Y -500 Olt 1ii1 i IIIIIIIiiiH1 iliririiiiiillmili -1000 -750 -500 -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 West(-)/East(+)(500 usft/in) Halliburton HAL LI B U RTO lt Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 42-06Y Company: Hilcorp Energy Company TVD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) - Project: Kenai Gas Field MD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) - Site: KGF 41-7 Pad North Reference: True ' Well• Plan:KBU 42-06Y Survey Calculation Method: Minimum Curvature - Wellbore: KBU 42-06Y Design: KBU 42-06Y wp3.0 Project Kenai Gas Field Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site KGF 41-7 Pad Site Position: Northing: 2,361,462.42 usft Latitude: 60.4580082 From: Lat/Long Easting: 274,852.80usft Longitude: -151.2472434 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.09 ° Well Plan:KBU 42-06Y Well Position +N/-S 0.00 usft Northing: 2,361,930.67 usft ' Latitude: 60.4592913 +El-W 0.00 usft Easting: 274,899.43 usft - Longitude: -151.2470343 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: - 66.20 usft Wellbore KBU 42-06Y Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 7/19/2014 16.86 73.44 55,358 Design KBU 42-06Y wp3.0 r Audit Notes: Version: Phase: PLAN Tie On Depth: 18.10 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 18.10 0.00 0.00 16.46 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°1100usft) (°) 18.10 0.00 0.00 18.10 -66.40 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 415.50 0.00 0.00 0.00 0.00 0.00 0.00 2,015.51 30.31 16.46 1,945.80 1,861.30 375.54 110.98 2.00 2.00 0.00 16.46 7,332.66 30.31 16.46 6,536.13 6,451.63 2,948.98 871.51 0.00 0.00 0.00 0.00 8,343.00 0.00 16.25 7,500.00 7,415.50 3,199.34 945.50 3.00 -3.00 0.00 180.00 10,593.00 0.00 16.25 9,750.00 9,665.50 3,199.34 945.50 0.00 0.00 0.00 0.00 7/15/2014 1:30:32PM Page 2 COMPASS 5000.1 Build 70 Halliburton HALLIBURTOR Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 42-06Y Company: Hilcorp Energy Company TVD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Project: Kenai Gas Field MD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Site: KGF 41-7 Pad North Reference: True Well: Plan:KBU 42-06Y Survey Calculation Method: Minimum Curvature Wellbore: KBU 42-06Y Design: KBU 42-06Y wp3.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting, DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -66.40 18.10 0.00 0.00 18.10 -66.40 0.00 0.00 2,361,930.67 274,899.43 0.00 0.00 100.00 0.00 0.00 100.00 15.50 0.00 0.00 2,361,930.67 274,899.43 0.00 0.00 130.00 0.00 0.00 130.00 45.50 0.00 0.00 2,361,930.67 274,899.43 0.00 0.00 16" 200.00 0.00 0.00 200.00 115.50 0.00 0.00 2,361,930.67 274,899.43 0.00 0.00 300.00 0.00 0.00 300.00 215.50 0.00 0.00 2,361,930.67 274,899.43 0.00 0.00 400.00 0.00 0.00 400.00 315.50 0.00 0.00 2,361,930.67 274,899.43 0.00 0.00 500.00 0.00 0.00 500.00 415.50 0.00 0.00 2,361,930.67 274,899.43 0.00 0.00 Start Dir 2°/100':500'MD,500'TVD 600.00 2.00 16.46 599.98 515.48 1.67 0.49 2,361,932.33 274,899.96 2.00 1.75 700.00 4.00 16.46 699.84 615.34 6.69 1.98 2,361,937.32 274,901.53 2.00 6.98 800.00 6.00 16.46 799.45 714.95 15.05 4.45 2,361,945.63 274,904.16 2.00 15.69 900.00 8.00 16.46 898.70 814.20 26.74 7.90 2,361,957.25 274,907.84 2.00 27.88 1,000.00 10.00 16.46 997.47 912.97 41.74 12.33 2,361,972.17 274,912.55 2.00 43.52 1,100.00 12.00 16.46 1,095.62 1,011.12 60.04 17.74 2,361,990.36 274,918.31 2.00 62.60 1,200.00 14.00 16.46 1,193.06 1,108.56 81.61 24.12 2,362,011.80 274,925.09 2.00 85.10 1,300.00 16.00 16.46 1,289.64 1,205.14 106.43 31.45 2,362,036.48 274,932.89 2.00 110.98 1,400.00 18.00 16.46 1,385.27 1,300.77 134.46 39.74 2,362,064.35 274,941.71 2.00 140.21 1,500.00 20.00 16.46 1,479.82 1,395.32 165.68 48.96 2,362,095.39 274,951.52 2.00 172.77 10 3/4" 1,600.00 22.00 16.46 1,573.17 1,488.67 200.05 59.12 2,362,129.56 274,962.33 2.00 208.60 1,700.00 24.00 16.46 1,665.21 1,580.71 237.52 70.19 2,362,166.81 274,974.11 2.00 247.67 1,800.00 26.00 16.46 1,755.84 1,671.34 278.05 82.17 2,362,207.10 274,986.85 2.00 289.93 1,900.00 28.00 16.46 1,844.94 1,760.44 321.58 95.04 2,362,250.38 275,000.53 2.00 335.33 2,000.00 30.00 16.46 1,932.39 1,847.89 368.07 108.78 2,362,296.60 275,015.15 2.00 383.81 2,015.51 30.31 16.46 1,945.81 1,861.31 375.54 110.98 2,362,304.03 275,017.50 2.00 391.60 End Dir :2016'MD,1946'TVD 2,100.00 30.31 16.46 2,018.75 1,934.25 416.44 123.07 2,362,344.68 275,030.36 0.00 434.24 2,200.00 30.31 16.46 2,105.08 2,020.58 464.83 137.37 2,362,392.80 275,045.57 0.00 484.71 2,300.00 30.31 16.46 2,191.41 2,106.91 513.23 151.68 2,362,440.92 275,060.79 0.00 535.18 2,400.00 30.31 16.46 2,277.74 2,193.24 561.63 165.98 2,362,489.04 275,076.01 0.00 585.65 2,500.00 30.31 16.46 2,364.07 2,279.57 610.03 180.28 2,362,537.15 275,091.22 0.00 636.11 2,600.00 30.31 16.46 2,450.40 2,365.90 658.43 194.59 2,362,585.27 275,106.44 0.00 686.58 2,700.00 30.31 16.46 2,536.73 2,452.23 706.83 208.89 2,362,633.39 275,121.66 0.00 737.05 2,800.00 30.31 16.46 2,623.06 2,538.56 755.23 223.19 2,362,681.50 275,136.87 0.00 787.52 2,900.00 30.31 16.46 2,709.39 2,624.89 803.63 237.50 2,362,729.62 275,152.09 0.00 837.99 3,000.00 30.31 16.46 2,795.72 2,711.22 852.03 251.80 2,362,777.74 275,167.31 0.00 888.45 3,100.00 30.31 16.46 2,882.05 2,797.55 900.42 266.10 2,362,825.86 275,182.52 0.00 938.92 3,200.00 30.31 16.46 2,968.38 2,883.88 948.82 280.41 2,362,873.97 275,197.74 0.00 989.39 3,300.00 30.31 16.46 3,054.71 2,970.21 997.22 294.71 2,362,922.09 275,212.96 0.00 1,039.86 3,400.00 30.31 16.46 3,141.04 3,056.54 1,045.62 309.01 2,362,970.21 275,228.17 0.00 1,090.33 3,500.00 30.31 16.46 3,227.37 3,142.87 1,094.02 323.32 2,363,018.32 275,243.39 0.00 1,140.79 3,600.00 30.31 16.46 3,313.71 3,229.21 1,142.42 337.62 2,363,066.44 275,258.61 0.00 1,191.26 3,700.00 30.31 16.46 3,400.04 3,315.54 1,190.82 351.92 2,363,114.56 275,273.82 0.00 1,241.73 3,800.00 30.31 16.46 3,486.37 3,401.87 1,239.22 366.23 2,363,162.68 275,289.04 0.00 1,292.20 7/15/2014 1:30:32PM Page 3 COMPASS 5000.1 Build 70 Halliburton HALLIBURTOR Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 42-06Y Company: Hilcorp Energy Company TVD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Project: Kenai Gas Field MD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Site: KGF 41-7 Pad North Reference: True Well: Plan:KBU 42-06Y Survey Calculation Method: Minimum Curvature Wellbore: KBU 42-06Y Design: KBU 42-06Y wp3.0 I 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) 3,488.20 3,900.00 30.31 16.46 3,572.70 3,488.20 1,287.61 380.53 2,363,210.79 275,304.25 0.00 1,342.67 3,919.46 30.31 16.46 3,589.50 3,505.00 1,297.03 383.31 2,363,220.16 275,307.22 0.00 1,352.49 Sterling 4,000.00 30.31 16.46 3,659.03 3,574.53 1,336.01 394.83 2,363,258.91 275,319.47 0.00 1,393.13 4,100.00 30.31 16.46 3,745.36 3,660.86 1,384.41 409.13 2,363,307.03 275,334.69 0.00 1,443.60 4,200.00 30.31 16.46 3,831.69 3,747.19 1,432.81 423.44 2,363,355.15 275,349.90 0.00 1,494.07 4,300.00 30.31 16.46 3,918.02 3,833.52 1,481.21 437.74 2,363,403.26 275,365.12 0.00 1,544.54 4,400.00 30.31 16.46 4,004.35 3,919.85 1,529.61 452.04 2,363,451.38 275,380.34 0.00 1,595.01 4,500.00 30.31 16.46 4,090.68 4,006.18 1,578.01 466.35 2,363,499.50 275,395.55 0.00 1,645.47 4,600.00 30.31 16.46 4,177.01 4,092.51 1,626.41 480.65 2,363,547.61 275,410.77 0.00 1,695.94 4,616.78 30.31 16.46 4,191.50 4,107.00 1,634.53 483.05 2,363,555.69 275,413.32 0.00 1,704.41 Sterling 5.2 4,700.00 30.31 16.46 4,263.34 4,178.84 1,674.81 494.95 2,363,595.73 275,425.99 0.00 1,746.41 4,800.00 30.31 16.46 4,349.67 4,265.17 1,723.20 509.26 2,363,643.85 275,441.20 0.00 1,796.88 4,900.00 30.31 16.46 4,436.00 4,351.50 1,771.60 523.56 2,363,691.97 275,456.42 0.00 1,847.35 5,000.00 30.31 16.46 4,522.33 4,437.83 1,820.00 537.86 2,363,740.08 275,471.64 0.00 1,897.82 5,100.00 30.31 16.46 4,608.66 4,524.16 1,868.40 552.17 2,363,788.20 275,486.85 0.00 1,948.28 5,200.00 30.31 16.46 4,694.99 4,610.49 1,916.80 566.47 2,363,836.32 275,502.07 0.00 1,998.75 5,204.06 30.31 16.46 4,698.50 4,614.00 1,918.76 567.05 2,363,838.27 275,502.69 0.00 2,000.80 Upper Beluga 5,300.00 30.31 16.46 4,781.33 4,696.83 1,965.20 580.77 2,363,884.44 275,517.29 0.00 2,049.22 I 5,400.00 30.31 16.46 4,867.66 4,783.16 2,013.60 595.08 2,363,932.55 275,532.50 0.00 2,099.69 5,500.00 30.31 16.46 4,953.99 4,869.49 2,062.00 609.38 2,363,980.67 275,547.72 0.00 2,150.16 5,600.00 30.31 16.46 5,040.32 4,955.82 2,110.39 623.68 2,364,028.79 275,562.94 0.00 2,200.62 5,700.00 30.31 16.46 5,126.65 5,042.15 2,158.79 637.99 2,364,076.90 275,578.15 0.00 2,251.09 5,800.00 30.31 16.46 5,212.98 5,128.48 2,207.19 652.29 2,364,125.02 275,593.37 0.00 2,301.56 5,900.00 30.31 16.46 5,299.31 5,214.81 2,255.59 666.59 2,364,173.14 275,608.59 0.00 2,352.03 5,990.57 30.31 16.46 5,377.50 5,293.00 2,299.43 679.55 2,364,216.72 275,622.37 0.00 2,397.74 Middle Beluga 6,000.00 30.31 16.46 5,385.64 5,301.14 2,303.99 680.90 2,364,221.26 275,623.80 0.00 2,402.50 6,100.00 30.31 16.46 5,471.97 5,387.47 2,352.39 695.20 2,364,269.37 275,639.02 0.00 2,452.96 6,118.00 30.31 16.46 5,487.51 5,403.01 2,361.10 697.78 2,364,278.03 275,641.76 0.00 2,462.05 7 5/8" 6,200.00 30.31 16.46 5,558.30 5,473.80 2,400.79 709.50 2,364,317.49 275,654.24 0.00 2,503.43 6,300.00 30.31 16.46 5,644.63 5,560.13 2,449.19 723.81 2,364,365.61 275,669.45 0.00 2,553.90 6,400.00 30.31 16.46 5,730.96 5,646.46 2,497.58 738.11 2,364,413.73 275,684.67 0.00 2,604.37 6,500.00 30.31 16.46 5,817.29 5,732.79 2,545.98 752.41 2,364,461.84 275,699.88 0.00 2,654.84 6,600.00 30.31 16.46 5,903.62 5,819.12 2,594.38 766.72 2,364,509.96 275,715.10 0.00 2,705.30 6,700.00 30.31 16.46 5,989.95 5,905.45 2,642.78 781.02 2,364,558.08 275,730.32 0.00 2,755.77 6,800.00 30.31 16.46 6,076.28 5,991.78 2,691.18 795.32 2,364,606.19 275,745.53 0.00 2,806.24 6,836.16 30.31 16.46 6,107.50 6,023.00 2,708.68 800.50 2,364,623.59 275,751.04 0.00 2,824.49 Lower Beluga 6,900.00 30.31 16.46 6,162.61 6,078.11 2,739.58 809.63 2,364,654.31 275,760.75 0.00 2,856.71 7,000.00 30.31 16.46 6,248.95 6,164.45 2,787.98 823.93 2,364,702.43 275,775.97 0.00 2,907.18 7,100.00 30.31 16.46 6,335.28 6,250.78 2,836.38 838.23 2,364,750.55 275,791.18 0.00 2,957.65 7/15/2014 1:30:32PM Page 4 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 42-06Y Company: Hilcorp Energy Company TVD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Project: Kenai Gas Field MD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Site: KGF 41-7 Pad North Reference: True Well: Plan:KBU 42-06Y Survey Calculation Method: Minimum Curvature Wellbore: KBU 42-06Y Design: KBU 42-06Y wp3.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,337.11 7,200.00 30.31 16.46 6,421.61 6,337.11 2,884.78 852.54 2,364,798.66 275,806.40 0.00 3,008.11 7,300.00 30.31 16.46 6,507.94 6,423.44 2,933.17 866.84 2,364,846.78 275,821.62 0.00 3,058.58 7,332.66 30.31 16.46 6,536.13 6,451.63 2,948.98 871.51 2,364,862.50 275,826.59 0.00 3,075.06 Start Dir 3°/100':7333'MD,6536'TVD 7,400.00 28.29 16.46 6,594.85 6,510.35 2,980.58 880.85 2,364,893.91 275,836.52 3.00 3,108.02 7,500.00 25.29 16.46 6,684.11 6,599.61 3,023.80 893.62 2,364,936.88 275,850.11 3.00 3,153.08 7,600.00 22.29 16.46 6,775.60 6,691.10 3,062.48 905.05 2,364,975.34 275,862.27 3.00 3,193.42 7,700.00 19.29 16.46 6,869.08 6,784.58 3,096.52 915.11 2,365,009.17 275,872.97 3.00 3,228.91 7,800.00 16.29 16.46 6,964.29 6,879.79 3,125.81 923.77 2,365,038.30 275,882.18 3.00 3,259.46 7,900.00 13.29 16.46 7,060.97 6,976.47 3,150.29 931.00 2,365,062.64 275,889.88 3.00 3,284.98 8,000.00 10.29 16.46 7,158.84 7,074.34 3,169.88 936.79 2,365,082.11 275,896.04 3.00 3,305.41 8,028.07 9.45 16.46 7,186.50 7,102.00 3,174.50 938.16 2,365,086.70 275,897.49 3.00 3,310.22 Upper Tyonek 8,100.00 7.29 16.46 7,257.66 7,173.16 3,184.54 941.13 2,365,096.68 275,900.65 3.00 3,320.69 8,200.00 4.29 16.46 7,357.14 7,272.64 3,194.21 943.98 2,365,106.30 275,903.69 3.00 3,330.78 8,300.00 1.29 16.46 7,457.01 7,372.51 3,198.88 945.36 2,365,110.94 275,905.15 3.00 3,335.65 8,343.00 0.00 16.25 7,500.00 7,415.50 3,199.34 945.50 2,365,111.40 275,905.30 3.00 3,336.13 End Dir :8343'MD,7500'TVD 8,400.00 0.00 16.25 7,557.00 7,472.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 8,500.00 0.00 16.25 7,657.00 7,572.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 8,600.00 0.00 16.25 7,757.00 7,672.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 8,700.00 0.00 16.25 7,857.00 7,772.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 8,800.00 0.00 16.25 7,957.00 7,872.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 8,900.00 0.00 16.25 8,057.00 7,972.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 9,000.00 0.00 16.25 8,157.00 8,072.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 9,100.00 0.00 16.25 8,257.00 8,172.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 9,200.00 0.00 16.25 8,357.00 8,272.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 9,300.00 0.00 16.25 8,457.00 8,372.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 9,400.00 0.00 16.25 8,557.00 8,472.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 9,500.00 0.00 16.25 8,657.00 8,572.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 9,600.00 0.00 16.25 8,757.00 8,672.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 9,608.50 0.00 16.25 8,765.50 8,681.00 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 Tyonek D1 9,691.50 0.00 16.25 8,848.50 8,764.00 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 Tyonek D2 9,700.00 0.00 16.25 8,857.00 8,772.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 9,800.00 0.00 16.25 8,957.00 8,872.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 9,900.00 0.00 16.25 9,057.00 8,972.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 9,952.50 0.00 16.25 9,109.50 9,025.00 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 Tyonek D3 10,000.00 0.00 16.25 9,157.00 9,072.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 10,100.00 0.00 16.25 9,257.00 9,172.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 10,157.50 0.00 16.25 9,314.50 9,230.00 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 Tyonek D4 10,200.00 0.00 16.25 9,357.00 9,272.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 7/15/2014 1:30:32PM Page 5 COMPASS 5000.1 Build 70 Halliburton HALLIBURTDN Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 42-06Y Company: Hilcorp Energy Company TVD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Project: Kenai Gas Field MD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Site: KGF 41-7 Pad North Reference: True Well: Plan:KBU 42-06Y Survey Calculation Method: Minimum Curvature Wellbore: KBU 42-06Y Design: KBU 42-06Y wp3.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 9,354.00 10,281.50 0.00 16.25 9,438.50 9,354.00 3,199.34 945.50 2,365,111.40 - 275,905.30 0.00 3,336.13 Tyonek D5 10,300.00 0.00 16.25 9,457.00 9,372.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 10,334.50 0.00 16.25 9,491.50 9,407.00 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 Tyonek D6 10,400.00 0.00 16.25 9,557.00 9,472.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 10,500.00 0.00 16.25 9,657.00 9,572.50 3,199.34 945.50 2,365,111.40 275,905.30 0.00 3,336.13 .! 10,593.00 0.00 16.25 9,750.00 ., 9,665.50 , 3,199.34 945.50 2,365,111.40 ./ 275,905.30/ 0.00 3,336.13 Total Depth:10593'MD,9750'TVD-5" Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +El-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) KBU 42-06Y BHL 0.00 0.00 9,750.00 3,199.34 945.50 2,365,111.40 275,905.30 -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") ( ) 130.00 130.00 16" 16 22 1,500.00 1,479.82 10 3/4" 10-3/4 13-1/2 6,118.00 5,487.51 7 5/8" 7-5/8 9-7/8 10,593.00 9,750.00 5" 5 6-3/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (°) (1 4,616.78 4,191.50 Sterling 5.2 5,204.06 4,698.50 Upper Beluga 10,157.50 9,314.50 Tyonek D4 10,334.50 9,491.50 Tyonek D6 9,608.50 8,765.50 Tyonek D1 9,952.50 9,109.50 Tyonek D3 9,691.50 8,848.50 Tyonek D2 10,281.50 9,438.50 Tyonek D5 3,919.46 3,589.50 Sterling 6,836.16 6,107.50 Lower Beluga 8,028.07 7,186.50 Upper Tyonek 5,990.57 5,377.50 Middle Beluga 7/15/2014 1:30:32PM Page 6 COMPASS 5000.1 Build 70 Halliburton HALLI B U RTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 42-06Y Company: Hilcorp Energy Company TVD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Project: Kenai Gas Field MD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Site: KGF 41-7 Pad North Reference: True Well: Plan:KBU 42-06Y Survey Calculation Method: Minimum Curvature Wellbore: KBU 42-06Y Design: KBU 42-06Y wp3.0 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-5 +E/-W (usft) (usft) (usft) (usft) Comment 500.00 500.00 0.00 0.00 Start Dir 2°/100':500'MD,500'TVD 2,015.51 1,945.81 375.54 110.98 End Dir :2016'MD,1946'TVD 7,332.66 6,536.13 2,948.98 871.51 Start Dir 3°/100':7333'MD,6536'TVD 8,343.00 7,500.00 3,199.34 945.50 End Dir :8343'MD,7500'TVD 10,593.00 9,750.00 3,199.34 945.50 Total Depth:10593'MD,9750'TVD 7/15/2014 1:30:32PM Page 7 COMPASS 5000.1 Build 70 Z N 0L L m a M3 2 W 0 t m a I IIZ m o o Mco 2 • 33 d r, N wN O m• 0 CO O UJ O A o /V NY a O N • Z o E c � t N w CI• m M O O ' } N L_ OG f' L 2 N •m Wc v w = 0 `0 3 >1 LE ce 13:1 > ; 7s ii U Y g ci 1i L 0 o co d U o ♦/1 a �+� v w E x d C >- p U— ,,. nD10. n .` m Q Ce) W 8 . w Wp Q x " M M v, a) O ■— o v °' `° n r J N a 0Ma g4. < .aQ CL LL A Tr >- >- L Nt 0 YND 2i tzi =- a O (a N. p p co O r a c i Y o 1 m 0 N co i v N o •� ,, .. 62a� o LI r Y N N al ■ n c C L m 0 c1Oi o d' , a 'v °' w ? v) 1n ci ei EL Y/ �� >' a � R m c v c c •C LL C n M � , N y U E Qom' R' y 0 FT FT MINN YYaY Y fin C� Q iic � ococo0 > 0co ! kBBBBBBBINBBUBB1 l i '.IMPOl'. a 8(NllaII , , n« l I NBlliiilPI411B41BB8MI8I IIBBIII2BIBBIIIIIBBI i. . ,, 4, rMk -? 4 vet 't aAll MINIM-Karl n ":0'11 1l1V1" 11411 I IINIMMIN i I0'"'.E 41'IF %WIN 4 TAIIIIIII N 7.--T4P,,urArrior 1 it co • 4-6 a o `� 12) o U C7 '= U CO ea nen ' 0 c 0 C e W CO O. 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WM WPWrill __ r-- I p111._ ___.,. , e /WRri � k . d V• _ O , 5 0961rwiliaL f4 I L �. L Q 0 k CO ' �! - O ii,_ , i - i 7_, ! I-; Z 0- Po. ct - O O do °' c o U CA O as yO O - r It: _ • Q/ O 6 N .... —o <r M 0 a V cov Iii O o \ isoll .N I.I. I I I I I I I I II I I I I r I 1 I I 1 1 1 l i i i i I I I l I I I T O in J — O V OLo N N 0 ti N O QuC O O n O to M N .- O _ a (u!/os Z)_loped uo!;ejedes a TRANSMITTAL LETTER CHECKLIST , yZ WELL NAME: IL.,S1 ��t-c:. � `' �`� /t f i1 PTD: •14-/ v�J / Development Service _Exploratory StratigraphicTest Non-Conventional • FIELD: esZA/Nzl--t_, POOL: Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well(name on permit). The permit is approved subject to full compliance with 20 MC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 MC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Logging also required for this well: Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 MC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 ❑❑ 0 0 To o a a a) a to NU .a N � 0 - 7 O C1. . m • Q N N. _o 3. 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U V V 7 C) C w N CD 0'-' (---1 - N U 0 rt 0 0 Q c N 0.N C N O N C•1 N W c) Es n c n T-.) 0 J N E a) a) O o J i• I.- a0 c 8_ LL 0 Qo 0 w o E a LL Q) a J o a LL 5. a Q Q U w Q > 0 Q U ( ----- sS E STATE� %ms ,]._c,' .i_ iii:: E Jar = ___ y — _ 33 Viost Se/cnth f, e iuc �'' z —" Anchorage, Alaska 9950 1-3572 i Main 907 279 1 433 Luke Keller Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Kenai Field, Beluga/Upper Tyonek Gas and Tyonek Gas Pool, KBU 42-06Y Hilcorp Alaska, LLC Permit No: 214-089 Surface Location: 92' FNL, 1008' FEL, Sec. 7, T4N, R11 W, SM, AK Bottomhole Location: 2146' FNL, 100' FEL, Sec. 6, T4N, R11 W, SM, AK Dear Mr. Keller: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, ey%„ p_3,,,:),4.4 4,_...._ Cathy P. Foerster Chair DATED this e7.,,,-4- aof July, 2014. RECEIVED STATE OF ALASKA P ,A OIL AND GAS CONSERVATION COMM, )N JUN 0 6 2014 PERMIT TO DRILL � 20 AAC 25.005 AO�-�VC 1 a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑ 1 c.Specify if well is proposed for Drill ❑., ' Lateral ❑ Stratigraphic Test ❑ Development-Gas Q• Service-Supply ❑ Multiple Zone 0 • Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry 0 Exploratory 0 Service- WAG 0 Service-Disp 0 Geothermal ❑ Shale Gas 0 2.Operator Name. 5. Bond. Blanket Q Single Well ❑ 11 Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 Kenai Beluga Unit(KBU)42-06Y ' 3.Address. 6 Proposed Depth:v.fyt�/� 4, ,J3/7/ 12.Field/Pool(s): 3800 Centerpoint Drive,Ste.1400 Anchorage,AK 99503 MD:__10.48131-: TVD: 9,750, • Kenai 4a. Location of Well(Governmental Section): 7 Property Designation(Lease Number): Up Tyonek Beluga Gas - Surface: 92'FNL,1008'FEL,Sec 7,T4N,R11W,SM,AK • FEE A028142 i Tyonek Gas Top of Productive Horizon. 8.Land Use Permit: 13.Approximate Spud Date: 2207'FSL,400'FEL,Sec 6,T4N,R11W,SM,AK NA(located entirely within unit) 7/19/2014 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2146'FNL, 100'FEL,Sec 6,T4N,R11W,SM,AK 2494 acres • 10,798'(unit boundary) 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 85 feet ' 15.Distance to Nearest Well Open Surface: x-274900.25 • y-2361921.54 • Zone-4 GL Elevation above MSL: 66.4 feet • to Same Pool: 595' 16.Deviated wells. Kickoff depth: 500 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 24.62 degrees Downhole: 4214 psig . Surface. 61 psig(Surface—Drilling) - 18 Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 16" 109 X-56 Weld 150' Surf Surf 150' 150' Driven 13-1/2" 10-3/4" 45.5 L-80 BTC 1,600' Surf Surf 1,600' • 1,488' 928.8ft3/165.4bbl 9-7/8" 7-5/8" 29.7 L-80 BTC 6,342' Surf Surf 6,342'_ 5,800' 916ft3/163.1 bbl 6-3/4" 5" 18 L-80 DWC/C 10,448' Surf Surf 10,448 • 9,750' 764ft3/136bb1 HT 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 BOP Sketch 0 Drilling Program ❑✓ Time v.Depth Plot ❑✓ Shallow Hazard Analysis 0 Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements❑Q 21. Verbal Approval. Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Janise Barrett Email jbarrett@hilcorp.com Printed Name //.....Luke Keller Title Drilling Engineer Signature jai Phone 907-777-8369 Date 6/6/2014 Commission Use Only Permit to Drill ^ API Number: Permit Approval See cover letter for other Number: oC(f (Act 50- [33-a2° 631i-OO-00 Date: 7131/4 requirements. - Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbedethane,gas hydrates,or gas contained in shales: Other: AI 3 SdCD s, /SrP ,r Samples req'd: Yes 0 No R' Mud log req'd:Yes 0 No El a('V t 'iiUc4.� 2 e_.,, G C 6k H2S measures. Yes❑ No r Directional svy req'd:Yes11 No❑ Spacing exception req'd: Yes❑ No Inclination-only svy req'd:Yes❑ No 4 Cel- r APPROVED BY .- Approved by: / (� COMMISSIONER THE COMMISSION Date: "I /"�/ ///�� R ///�� • """��' a mit rorm ana� Form 10-401 ev,�ed 10/2012) Thi p+riiv�ljp t �r�from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate •� (/ 7 I (y v ' \ v L Ili O -03-/pi Hilcorp Alaska, LLC P.O. Box 244027 Luke Keller Anchorage,AK 99524-4027 Drilling Engineer Tel 907 777 8395 Hilcorp Email Ikeller@hilcorp.com Energy company June6, 2014 RECEIVED Commissioner Alaska Oil &Gas Conservation Commission JUN 0 6 2014 333 W. 7th Avenue Anchorage, Alaska 99501 AOGCC Re: Kenai Beluga Unit(KBU)42-06Y 10-401 Permit to Drill Application Dear Commissioner, Enclosed for review and approval is the application for the Permit to Drill the KBU 42-06Y Development Gas well. KBU 42-06Y is a 10,448' MD / 9,750' TVD Beluga/Upper Tyonek development well off the 41-18 pad in the Kenai Gas Field. The KBU 42-07Y will target the Mid-Lower Beluga and Upper Tyonek reserves on the western flank of the v field. This well will offset several successful wells including KTU 43-06X, KTU 13-5 and KBU 12-5. The base plan is an "S" shaped well bore, with a shallow kick off(500 ft MD) in the surface hole, then dropping back to vertical in the production hole section. Drilling operations are expected to commence approximately July 19th, 2014. i The Saxon Rig # 147 will be used to drill and complete the wellbore. The well will be perforated after the rig has departed. Pursuant to 20 AAC 25.055(a)(3), a spacing exception is NOT required: 1. KBU 42-06Y does not fall within 500 ft of a property line where ownership or landownership changes. Pursuant to 20 AAC 25.005 (c)&(d), the following is included: 1. Plat identifying the property on which the well will be drilled. 2. Diagram &description of blowout prevention equipment. 3. Information on drilling hazards. a. MASP calculations are attached per 20 AAC 25.005(c)(4)(A) b. Potential target reservoirs and their predicted pore pressures are indicated in attached Drilling Program 4. Formation integrity test procedure. 5. Planned casing &cement program (Drilling Program) 6. Drilling fluid program (Drilling Program) 7. Tabulation of predicted depths with equivalent formation pressures. 8. Requirements of 20 MC 25.025 have been met. a. Blanket state wide bond issued: 22035257 9. Copy of Drilling Program is attached. 10. General description of waste disposal. Operator does not wish to request authorization under 20 AAC 25.080 for an annular disposal operation in the well. a. Drilling waste (cuttings and water based drilling fluids) will be hauled to the Kenai Gas Field G&I facility. At the G&I facility, cuttings will be tested, and either injected or slotted for beneficial reuse. 11. Requirements of 20 MC 25.050(b) have been met. Hilcorp Alaska, LLC Page 1 of 2 a. Plat showing path of proposed wellbore including all adjacent wellbores within 200' is attached. b. All wellbores within 200' of proposed wellbore are owned by Hilcorp. If you have any questions, please don't hesitate to contact myself at 777-8395 or Paul Mazzolini at 777-8369. Sincerely, Luke Keller Drilling Engineer Hilcorp Alaska, LLC Page 2 of 2 Hilcorp Alaska, LLC Kenai Beluga Unit KBU 42-06Y Drilling & Completion Program Kenai Field Revision 0 June 2nd, 2014 KBU 42-06Y Drilling Procedure liilrorp;Ua kn,1.LI Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program: 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 N/U 16-3/4"Conductor Riser 11 11.0 Drill 13-1/2" Hole Section 12 12.0 Run 10-3/4"Surface Casing 16 13.0 Cement 10-3/4"Surface Casing 18 14.0 BOP N/U and Test 21 15.0 Drill 9-7/8"Hole Section 22 16.0 Run 7-5/8"Production Casing 28 17.0 Cement 7-5/8"Cement Procedure 30 18.0 Drill 6-3/4"Hole Section 33 19.0 Run 5"Production Long String 39 20.0 Cement 5" Production Long String 42 21.0 RDMO 44 22.0 Perf and Frac 44 23.0 BOP Schematic 45 24.0 Wellhead Schematic 46 25.0 Days Vs Depth 47 26.0 Formation Tops 48 27.0 Anticipated Drilling Hazards 49 28.0 Saxon Rig 147 Layout 52 29.0 FIT Procedure 53 30.0 Choke Manifold Schematic 54 31.0 Casing Design Information 55 32.0 9-7/8"Hole Section MASP 56 33.0 6-3/4"Hole Section MASP 57 34.0 Spider Plot(NAD 27)(Governmental Sections) 59 35.0 Surface Plat(As Built)(NAD 27) 60 36.0 Offset MW vs TVD Chart 61 37.0 Drill Pipe Information 62 KBU 42-06Y Drilling & Completion Procedure Hilrorh I,I A 1.0 Well Summary Well Kenai Beluga Unit(KBU)42-06Y Pad&Old Well Designation KBU 42-06Y is a grass roots well on the existing 41-18 pad Planned Completion Type 5"production tubing Target Reservoir(s) Tyonek/Beluga Planned Well TD,MD/TVD 10,448' MD/9,750' TVD PBTD,MD/TVD 10,400' MD/9,701' TVD Surface Location(Governmental) 92'FNL, 1008' FEL, Sec 7, T4N,R11 W, SM,AK • Surface Location(NAD 27) X=274900.25,Y=2361921.54 • Surface Location(NAD 83) Top of Productive Horizon (Governmental) 2207'FSL, 400'FEL, Sec 6,T4N, Rl 1 W, SM,AK TPH Location(NAD 27) X=275588.059,Y=2364094.942 TPH Location(NAD 83) BHL(Governmental) 2146'FNL, 100'FEL, Sec 6,T4N, R11 W, SM,AK BHL(NAD 27) X=275905.3,Y=2365111.4 BILL(NAD 83) Maximum Anticipated Pressure in psig(Downhole) 4214 psig(Downhole) Maximum Anticipated Pressure in psig(Surface) 1937 psig(Surface—Drilling) AFE Number 1411969D AFE Drilling Days 26 AFE Completion Days 0 AFE Drilling Amount $4.99 MM Work String 4-1/2" 16.6# S-135 CDS-40(Rental Saxon String) KB Elevation above MSL 85 • GL Elevation above MSL 66.4 • BOP Equipment 11" 5M T3-Energy Annular BOP 11" 5M T3-Energy Double Ram 11" 5M T3-Energy Single Ram Page 2 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hltcorp Masten.LLC 2.0 Management of Change Information Hilcorp Alaska, LLC Changes to Approved Permit to Drill Date: 6-2-2014 Subject: Changes to Approved Permit to Drill for KBU 42-06Y File#: KBU 42-06Y Drilling and Completion Program Any modifications to KBU 42-06Y Drilling& Completion Program will be documented and approved below. Changes to an approved APD will be eiatifwgress the BLM.rndcz--sh AOGCC.� 1� '1 .� �c Date Procedure Change Approved Approved BY BY Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure H�Irorp.tIa9kn.1.LC 3.0 Tubular Program: Holen) Drift Conn Wt Grade Conn Burst Collapse Tension Section `, (in) OD (in) (#/ft) (psi) (psi) (k-lbs) Cond 16" 15" - - 109 X-56 Weld 13-1/2" 10-3/4" 9.95" 9.875" 11.75" 45.5 L-80 BTC 5210 2480 1040 9-7/8" 7-5/8" 6.875" 6.75" 8.5" 29.7 L-80 BTC 6890 4790 683 6-3/4" 5" 4.276" 4.151" 5.563" 18 L-80 DWC/C 9910 10500 422 HT 4.0 Drill Pipe Information: Hole OD (in) ID (in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension Section (in) (in) (#/ft) (psi) (psi) (k-lbs) All 4.5" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16.769 468k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hileorp;Ua,kn.LLC 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. • Ensure to enter daily mud info, BHA info,directional surveys, depths. 5.2 Afternoon Updates • Submit a short operations update each work day to jbarrett@hilcorp.com and lkeller@hilcorp.com by 3pm. 5.3 Morning Updates: • Update Intranet homepage"Enter Drilling Comment"each morning before 7 am(Before 5 am on weekends and Holidays). 5.4 EHS Incident Reporting • Notify EHS field coordinator. 1. This could be one of(3) individuals as they rotate around. Know who your EHS field coordinator is at all times,don't wait until an emergency to have to call around and figure it out!!!! a. John Coston: 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 • Notify Drlg Manager 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally 1. Send final"As-Run"Casing tally to lkeller@hilcorp.com and jbarrett@hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to lkeller@hilcorp.com and jbarrett@hilcorp.com Page 5 Revision 0 Jun,2014 KBU 42-06Y Drilling & Completion Procedure n iI,.,ri,,u:,.,h,,.I,LC 6.0 Planned Wellbore Schematic Kenai Gas Field PROPOSEDII Well:KB1142-(16` PTD: ape-ono A '- 30-000-00000 3n, ""-t.sr.a.,1.1 e CASING DETAIL _ :e T;re '.t Grade Conn. ID Too Rt" ( Y Dr 1 Canductor— G 25" Driven to Set 279 X-15 Weld 16" Surf .33' I' Depth 10-3/4 Surf. Csg 45.5 L-33 Buttress 9.95" Surf 1600' 10-3 1-'f. 7-5/S" 7-5/S" Intermediate 2? L-S3 ETC 6.175" Surf 6,342' Ia ^.;� TOC=3900' _ 1�1 5" Production ,S L-S0 D.":C,C HT 4.276" Surf 10,448' / O. :1"y Ho'e Sect o' _ 5"1Rrk5Crilla ;;- 13-1/2„ 20-314" 1.5—9.3 ppg 4-1/2" 9-7/6" 7-5;5" 9—9.5 ppg 4-1/2" {,' 6-3/4" 5" 13-12.5 ppg 4-1/2" "f *,. JE',^JELF:' DETAIL ` " , •s.. Depth ID OD Item %y 18' .275" 11" Tubing Hanger 2 5,842' 4.276" 6.675" 10 ft Swell Packer(WeterSwell) PERFORATIONS = _- _. _ Btm To-p Etm 5r ' . • r" 2. :VD.; IT',D! ITvvo Middle Beluga 5,377 1 Lower Beluga_ 6,107 I- Upper Tyone-k 7,186 I" Tyanek D1 1,765 1 Tyy.ek D2 8,145 L .,1 Tyunek D3 9,109 Tyanek D4 9,212- TyQne1 D5 9,435 Tyanek D6 5,492 PBTD=10,400'111D;9,701'TVD TD=10,448'MD/9,750'TVD Page 6 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hilmrp Ala«ka.IJ.0 7.0 Drilling / Completion Summary V KBU 42-06Y is a 10,448' MD/9,750' TVD Beluga/Upper Tyonek development well off the 41-18 pad in the Kenai Gas Field. The KBU 42-07Y will target the Mid-Lower Beluga and Upper Tyonek reserves on • the western flank of the field. This well will offset several successful wells including KTU 43-06X, KTU 13-5 and KBU 12-5. • The base plan is an"S"shaped well bore,with a shallow kick off(500 ft MD)in the surface hole,then dropping back to vertical in the production hole section. • Drilling operations are expected to commence approximately July 1911', 2014. The Saxon Rig # 147 will be used to drill and complete the wellbore. The well will be perforated after the rig has departed. The closest industrial water well to the drill wells on pad 41-18 in the Kenai Gas Field is the Kenai B-4. The hole depth is 100' with the water level at 96', and the chlorides are around 1200 ppm. Arsenic levels came in at 11.8 parts per billion,which is over the EPA limit for the naturally occurring substance. Total gas levels from offset mud logs begin to register at depths as shallow as 175'. The closest domestic water well is the Kenai B-4 KS01,located on the eastern flank of the field,which draws its water from a depth of 268' and has chlorides around 2000 ppm. Casing for the drill wells will be placed well below the fresh water table at 1500' to isolate any useable ground water. • ✓ ✓ Surface casing will be run to 1600' MD and cemented to surface to ensure protection of these resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 — 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field / G&I facility for disposal /beneficial reuse depending on test results. This facility is on the same pad as the drill well. General sequence of operations: 1. MOB Saxon Rig# 147 to well site. 2. N/U 16"diverter riser (No diverter, diverter waiver requested) 3. Drill 13-1/2"hole to 1600' MD. Run and cmt 10-3/4" surface casing. 4. N/D conductor riser,N/U : 1"x 5M T3-Energy BOP. 5. Drill 9-7/8"hole section t, 6,118' ► D. Run and cmt 7-5/8" intermediate casing. / 6. Drill (and LWD log) 6-3/4" pro. ction hole section to well TD. Run and cmt 5"production casing. 7. N/D BOP,N/U tree, RDMO. 434(2 A 4 ,25' (r Page 7 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hitrarp%laska.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 and completion of KBU 42-06Y Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 5/5 min (annular to 50%rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: • Diverter waiver request requested due to the recent drilling of KBU 43-07Y & KBU 23-05 on the same pad. No issues were experienced while drilling surface holes on either well. Surface casing will be set at the same depth as these recent offsets. Page 8 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hilrorp AIa.kn.ILC Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 13-1/2" • 21-1/4"x 2M Hydril MSP diverter Function Test Only • 11"x 5M T3-Energy(Model 7082)Annular BOP • 11"x 5M T3-Energy Double Ram Initial Test:250/3500 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 9-7/8"&6-3/4" • 11"x 5M T-3 Energy Single Ram • 3-1/8"5M Choke Line Subsequent Tests: • 2-1/16"x 5M Kill line 250/3500 • 3-1/8"x 2-1/16"5M Choke manifold (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon (12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event(BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email:guy.schwartz@alaska.gov Victoria Ferguson/Petroleum Engineer/(0): 907-793-1247/Email: Victoria.ferguson@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/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 Jun, 2014 ...... .. .... .. . 14KBU 42-06Y Drilling & Completion Procedure Hilrorp Ala An,I.I.C. 9.0 R/U and Preparatory Work 9.1 Set 16" conductor at a minimum of 111' below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 16-3/4" 3M "A" section& 20" adapter bushing. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Saxon Rig# 147, spot service company shacks, spot & R/U company man& toolpusher offices. 9.7 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.8 Mix mud for 13-1/2"hole section. 9.9 Set test plug in wellhead prior to N/U conductor riser to ensure nothing is accidentally dropped into the wellbore. 9.10 Mud loggers not required in surface hole section. 9.11 Install 5-1/2" liners in mud pumps. • TSM 1000 mud pumps are rated at 3633 psi (85%) /333 gpm (100%) with 5-1/2" liners. Page 10 Revision 0 Jun, 2014 14KBU 42-06Y Drilling & Completion Procedure IIiI.orp:,i..1,a.LL f. 10.0 N/U 16-3/4" Conductor Riser 10.1 N/U 16-3/4" Conductor Riser • Ensure line does not direct flow from trip tank straight down the flowline. Fill up line and flowline should be oriented 90 degrees to each other at approx. the same height. • Ensure flowline outlet installed so that enough slope exists to carry cuttings to the shakers. • Consider adding additional drainage points at the bottom of the conductor riser if deemed necessary. • R/U fill up line to conductor riser. 10.2 Set 15.375" ID wear bushing in wellhead. 10.3 Rig Orientation on 41-18 Pad: I/III N 2361810.350E, '') 1415233.6 ac= N 2361706_587 8414943.884 236180$_521 El 2361809.628E N 23618.9- ( ' 1414577.697 1415024.569 1415133.011 1415183,50D K B.6 42-6K.B. 42-6 K_B.U. 12-5 i►ni �0 Cr) OKB.U. 113X SnF K B . 41-6 K.B.U. 43-7X KB.U. 33-6X P --:'Ats‘ 121 . K_B.0. 24-6H ISU_ 33-6 K.E H 32-- L. W, K_B.11.4- � '` gig. 6 ' ^ .,!' \ K.B_U. 42-7 l � .\ '.N;1* K Tr, SB 0705 CONTROL POINT 3 . fi\,.., a ' - 0 2"ALCAP ;;i: ,. �•'>.. N = 2361610.70 `� `.�t E = 1415109.70 `F c ELEV. = 66.40' SB 070$ ~lK K_U_ 43-6 RD --- 1�� U. 43-6, d`---j trl JL�li�i/IJ Page 11 Revision 0 Jun, 2014 14KBU 42-06Y Drilling & Completion Procedure Hdeorp:11n.+kn.!IC 11.0 Drill 13-1/2" Hole Section 11.1 P/U below 13-1/2" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Bit TFA should be-0.7 in2. We need to pump at 500 to 510 gpm to clean the hole effectively. • Workstring will be 4.5" 16.6# S-135 CDS40. HALLCBURTON ''` d ' I WELL INFORMATION Created On;Jan 09 2014 BHA Tally Custer 1 HBcorp Well Name : KBU 32-08 DritlstNeg Job Number :AK-XX- Rig Name : Saxon Rig#147 IADC Rig SHAD 0100 Country : USA Runt 100 State 1 Province : Alaska COMPONENT DATA Item Description Serial Number OD ID Gauge Weight Top Length Cumulative s (In) (in) (In) (Ibpf) Connection (ft) Length Ott) Ell HDBS OHCIGRC 13450 3000 13.500 46012 P E.58'REG 1.00 1.00 © 8'SperryDr91 Labe 4+5.5.3 atg 8.000 5.000 121.08 B t-SB'REG 31.13 32.83 _ Stabilizer -__ 13375 _ ® 8'Drecbonal Coltor 7.850 3.500 147.40 8 6-58'REG 8.88 41.71 0 a'Inline Stabiliser(MLS)12 1+8'gauge 8 000 2,830 12 125 149 87 8 6-58'REG 3 80 45 51 ® 8'1nl HOC(Pulser) 8.150 4.000 _EMI B 6-58'REG 940 54.91 ® 8'Non Mug Flex Collar 760CEMI Eso B 6,58"REG 30.00 84.91 ® 8'Non Marl Flex Collar 7 670 2 675 _IEEI B 6-5+6'REG 3000 114 91 0 X-0 6-5or Reg P X 4-12'IF 8 -®ECM_BEM B 4.1,2 IF 2.25 5 5.75'Non Mug Flax Color 8.710 Emig_ 49.11 8 4.112 IF 30.00 147."6 ® 6.75'Non Map Flex Coaar 6.700 3.000 96.06 8 4.112'IF 30.00 177.16 iiilim X-O 4412'IF P X CDS-40 Ii 8.520 2.750 _En B 4.5 CDS 40 2.75 179.91 ® 6 Jcxnts 4-1.2'HWDP CDS-40 4.500 2.750 41,00 185.00 364 01 WI X-0 CDS-40 P X 4 1.+7'IFS no 2.750 93.54 USSR 2.75 367.66 Es 6 114'Weatherford DAH Jar 6 250 2.250 91 Al 8 4.112'IF 32 00 39966 EN X-0 4-112 IF P X COS-40 a 6.520 2.750 _S0 B 4 5-CDS-40 2 75 18 13 Jaime 4-1.7 HWDP CDS-40 4.500 2.750 41.00 400.00 802 41 Total: 6'J2 41 BIT DATA Bit Numb.. Nozzles :1.14 3.18 Bit Size (lel : 13.500 TFA (in2) :0.7394 Manufacturer :HD8S Dult Grade In . Model :OHCIGRC DullQradsOut . Serial Number . MOTOR DATA Motor Number Bend (deg) : 1.15 OD(In) :8.000 Nazda. (32nd) : 0.0 Manufacturer :Sperry Ortnng Avg DM Press . Model :SherryDAl Cumul Or Mrs - Serial'Number . Page 12 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hileorp Alaska,LLC 11.2 Hydraulics Summary: Depth- Hole Size Pump Rate Standpipe Est Openhole MW ECD TFA MD (ft) (in) (gpm) Pressure (psi) AV(fpm) (ppg) (ppg) (in2) BHA MM + MWD+25 0- 1600 13-1/2" 500 1848 76 9.0 9.2 0.70 HWDP 11.3 Primary bit will be the Security 13-1/2" QHC1GRC Milled Tooth Bit. These are available from Halliburton. 13-1/2" (343mm) QHCIGRC PRODUCT SPECIFICATIONS IADC Code 117W Total Tooth Count 64 Cage Row Tooth Count 36 Journal Angle 33` Offset(1 16") 6 Jet Nozzle Types "^ Standard 83244 Extended 311306 _. Center Jet (If Center Jetted)501 413 Ti.Connection 6-4+8"(API Reg.) Recommended Make-Up Torque' 2:390002000 Ft*lbs.. Bit Weight(Boxed) 264 Lbs.(1 I8 Kg.) Bit Breaker(Mat.treGegacylr) 183777,64498 PRODUCT FEATURES • New patented OianutndTM Clawlir tooth bit design_ • Pnrprscua) Diamond`I FCf1200094 full tooth harrlfacmg on cutting structure and gage. • Tungsten carbide'surf inserts in gage teeth for added gage :64 protection. " • Premium bearing and seal configuration suitable for both rotary and motor applications. re. • Innovative mechanical pressure compensating system protides reliable pressure equalization and relief for maximum bearing and seal life. • Raised tungsten carbide inserts and proprietary Nadi-acing provides maximum arm protection in abrasn'e and directional applications while minimizing drill string torque. • QuadPackA Plus Series incorporates its successful`longevity" features and patented engineered hydraulics system for optimal cleaning efficiency. • Center jet feature to prevent bit balling problems Material#540030 *Calculation.,bayed on rrrommendativtn from API and tool-iorni manufacturers. C 2014 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Flalliburton and the customer that is applicable to the sale. www.halllburton.com Page 13 Revision 0 Jun, 2014 14KBU 42-06Y Drilling & Completion Procedure Hilrnrp Alnekn,[AC 11.4 4-1/2" Workstring & HWDP will come from Saxon. Jars will come from Weatherford. 11.5 No LWD tools will be run on the 13-1/2"hole section. 11.6 Begin drilling out from 16" conductor at reduced flow rates to avoid broaching the conductor. 11.7 Drill 13-1/2"hole section to 1600' MD / 1488' TVD. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 510 gpm. This gives us an annular velocity of 77 fpm, which is borderline for effective hole cleaning. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep API fluid loss < 10. • TD the hole section in a good shale btwn 1450' & 1550' MD. • Take MWD surveys every stand drilled (60' intervals) Page 14 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hileorp Aln.,kn,LLC 11.8 13-1/2" hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel +FW spud mud at 8.8 ppg. MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 8.8—9.3 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density / Viscosity Plastic Viscosity Yield Point API FL LGS 80-1600' '7 8.8-9.385-150 20-40 25-45 <10 <15% System Formulation: M-1 Gel + FW spud mud Product Concentration Fresh Water 0.905 bbl M-I Gel Export 20 ppb M-I Wate As needed Soda Ash 0.5 ppb Caustic Soda 0.1 ppb Busan 1060 0.04ppb 11.9 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. 11.10 TOH with the drilling assy, handle BHA as appropriate. Page 15 Revision 0 Jun, 2014 1 KBU 42-06Y Drilling & Completion Procedure II a,orp I.t.c 12.0 Run 10-3/4" Surface Casing 12.1 R/U and pull 15.375" wearbushing. 12.2 R/U Weatherford 10-3/4" casing running equipment. • Ensure 10-3/4"BTC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill-up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on (thread locked). • (1)Joint with coupling thread locked. • (1) Joint with float collar bucked on pin end &thread locked. • Install (2) centralizers on shoe joint over a stop collar. 10' from each end. • Install (1) centralizer, mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 10-3/4" surface casing • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. Estimated torque to reach base of triangle: 10,750 ft-lbs. • After making up several connections,use the torque required to M/U to base of triangle as the M/U torque and continue running string. • Install (1) centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 10-3/4" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 10-3/4" 10,750 ft-lbs Page 16 Revision 0 Jun, 2014 14KBU 42-06Y Drilling & Completion Procedure Tenaris Casing and Tubing Performance Data Choose pipe size.wall thickness and steel grade to view API connection options and performance data. Size Wall Grade " Connection v Unit Pipe Body Data GEOMETRY • I Nominal OD 10.750 in Wall Thickness 0.400 in API Drift Diameter 9.794 in Nominal Weight 45.50 lbs./ft Nominal ID 9.950 in Alternate Drift Diameter 9.875 in !Plain End Weight 44.26 lbslft Nominal Cross Section 13.006 sq in PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi €- 1 Body Yield Strength 1,040,000 Ibs Internal Yield Pressure 5,210 psi Collapse Pressure 2,470 psi a'I r Connection Data GEOMETRY Regular OD 11.750 in Threads Per Inch 5 Make-Up Thread Tums 1 PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi !Joint Strength 1,063,000 lbs Internal Pressure 5,210 psi Resistance TenarisHvdril Premium Connections Print I Contact Us Ver 8.6 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. Page 17 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure 11 ilrorp Alaska,Id.0 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. 13.0 Cement 10-3/4" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 13.2 R/U cmt head(if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.3 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.4 Pump remaining 35 bbls 10 ppg spacer. 13.5 Drop bottom plug. Mix and pump cmt per below recipe. 13.6 Cement volume based on annular volume+ 50% open hole excess. Job will consist of lead& tail, TOC brought to surface. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) LEAD: 80' x .106 bpf= 8.5 47.8 16" Conductor x 10-3/4" casing annulus: LEAD: (1000' —80')x .065 bpf x 1.5 = 89.7 504 13-1/2" OH x 10-3/4" Casing annulus: Total LEAD: 98.2 552 TAIL: (1600'-1000')x .065 bpf x 1.5 = 58.5 328 13-1/2" OH x 10-3/4" Casing annulus: TAIL: 90 x .096 bpf = 8.7 48.8 10-3/4" Shoe track: Total TAIL: 67.2 376.8 1' s '_- Page 18 Revision 0 Jun,2014 KBU 42-06Y Drilling & Completion Procedure Hilrorp Alarka,LLC Cement Slurry Design: Lead Slurry (1000' MD to surface) Tail Slurry (1600' to 1000' MD) System Extended Conventional Density 12.5 lb/gal 15.2 lb/gal Yield 2.13ft3/sk ✓ 1.25 ft3/sk ✓ Mixed Water 12.02 gal/sk 5.70 gal/sk Mixed Fluid 12.03 gal/sk 5.71 gal/sk Expecteds 5:00 HR:MIN 3:30 HR:MIN Thickening Code Description Concentration Code Description Concentration Type1 Cement 94 lb/sk Type1 Cement 94 lb/sk A-7 CaCl2 2% BWOC FP-6I Anti Foam 1 gal/ 100sks CD-32 Dispersent 0.4% BWOC CD-32 Dispersant 0.5% BWOC Additives FI-52 Fluid Loss 0.3% BWOC A-7 CaCl2 0.25% BWOC A-2 Extender 2% BWOC FL-52 Fluid Loss 0.2% BWOC FP-61 Anti Foam 1 gal/100sks Static Free Anti-Static 0.005 lbs/sk static Free Anti-Static 0.005 lbs/sk 13.7 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.8 After pumping cement, drop top plug and displace cement with mud. 13.9 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. Be lined up to displace with rig pumps as well, in the event there is an issue during the displacement with the rig pumps. 13.10 Displacement calculation: 1511' x .0962 bpf= 145 bbls 13.11 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.12 Do not overdisplace by more than 1/2 shoe track volume. Total volume in shoe track is 8.7 bbls. Page 19 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hilrorp Alnekn,LLC 13.13 Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log btwn 6— 18 hours after CIP. 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold,pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: 1 • Pre flush type, volume (bbls) &weight(ppg) • Cement slurry type, lead or tail,volume &weight • Pump rate while mixing, bpm,note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to lkeller@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 20 Revision 0 Jun, 2014 14KBU 42-06Y Drilling & Completion Procedure Hilmrp Aln.kn,GI.0 14.0 BOP N/U and Test 14.1 N/D the conductor riser. 14.2 N/U Seaboard multibowl wellhead assy. Install packoff 10-3/4" P-seals. Test to 3000 psi. 14.3 N/U 11" x 5M T3-Energy BOP as follows: • BOP configuration from Top down: 11"x 5M T3-Energy annular BOP/11"x 5M T3-Energy Model 6011i double ram/11"x 5M mud cross/11"x 5M T3-Energy Model 6011i single ram • Double ram should be dressed with 2-7/8 x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5" VBRs • N/U bell nipple, install flowline. • Install (1) manual valves & (1) HCR on kill side of mud cross. Manual valve used as inside or"master valve". • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 4-1/2"BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3500 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9 ppg 6%KC1/Kla-Shield drilling fluid for 9-7/8"hole section. 14.8 Set 10"ID wearbushing in wellhead. 14.9 Mud loggers not required in the intermediate hole section. R/U Canrig infrared mud gas detector and tie into the Pason PVT (if possible). This will allow gas units to be measured while drilling. • 14.10 Rack back as much 4-1/2"DP in derrick as possible to be used while drilling the hole section. 14.11 Install 5" liners in mud pumps. • TSM 1000 mud pumps are rated at 4250 psi (85%)/275 gpm (100%)with 5" liners. Page 21 Revision 0 Jun,2014 111 KBU 42-06Y Drilling & Completion Procedure Hilrnrp:11nkn,LLC. 15.0 Drill 9-7/8" Hole Section 15.1 Prior to P/U 9-7/8" directional BHA-test casing against blind rams to 2600 psi / 30 min. 15.2 P/U below 9-7/8" directional drilling assembly. I-CAI-LIBUPT'ON ,,.'0.-` WELL INFORMATION Created On:•Jan 10 2014 BHA TallyCustomer : Hllcrsrp Weil Name : KBU 32-08 t�r€i etNng Job Number : Alf-XX- R€g Name = Saxon Rig#147 !ADC Rig BHA Country : USA Runs 200 Stade 1 Province . Alaska ,..: at Tap Length p I Cartxrectfrm 111 LCurrrrtgEh Atilt: ill HI:85 MW65 FOC:tilt 6.0G0 t.Eau 9.875 79.63 E=II 0 90 0.90 Nal 7'SperryDrii Lobe 7,93-6.0 sig 7.000 4:952 ! 93.13 B 4.112.'1F 27iX1 27.90 11111 Sliilxlizer -__ 3.525 _---: am 6 314'''torr Mag Ftoa1 Sub 11110111111116.500 2.675 _ 90.9610=111.11333. 3135 Q 6 314'integral etade 9 516'gaugrr 6.770 2..75 9,6255 100 65 9 4.1 `1F 7.00 37.35 Ea 6 3.4"Dl1!Cotler 111111111111111111 6.6'90Emil i 103.40 11=011 9 25 46.60 Eli 6 3W EWR-P4 Collar 8.720 2.400 ® 104.30 8 4=1171F 14.00 E0.90 lel 5 3'4"DOR c.441car 6 760 1920 ® 971t> P 4-174F 9>40 ta't 00 ION Inlhe Stabilizer{ILS} 111111111111116.754 EMI 9.750112MMin 3.50 72.50 En 6,3,4`P'.4 D Collar 6.730 1 905 ® %I. 9 4.112`IF 4,00 77.50 Kill 6 34'1f IM Collar 6.840 1 920 101:70 B 4-112'IF 7.00 64.50 1111 6 31'4•TM Collar 6.893 3.250 103.60 8 4.17 it 9.80 94.:30 MEI 6-3,4r 11k^i1 Mel F1gx Collar 6 764 2:610 ® 100 82 a 4-1,7 IF 31;00 125.30 MI 6-3,'4"Nen Meg FF.ni Cellar M 6.7541131311111111110082 113MOMIEMIN 15614 MI 6-3.'4"Nbn Mag Flex Collar 6.754 2.1110 ® 10r'i 82 8 4.1'IF 30 03 19.34 EIIIIIIIIESUMESEEMMIIIIIIIIIIIIIIIIII 6.750 2.810 Milli 1°4)82 111111= 3000 21630 El X-O 4.112`IF P X CDS-40 8 6.520 2.730 93.54 B 4.5"CDS 40 2.75 219.05 En 6 Joints 4-117 HVitOP COS-40 4 500 2 RI? ® 36.81 165.06 40455 En X-O CDS-40 P X 4 1D7'IF 8 IIIIIIIIIal 6.524 2 750 - 993.54 1103EIMMIEEM 406:80 19 G-1'4"Wodthorfn 1 Hy I Jar 6.250 ?.250 ® 91,01 8 4-17 IF 32.31 439 11 I X-O 4-t,'2'IF P X CDS-4013 ® 6.520 2.750 ® X3.54 8 4.5`CDS-40:MEEMI En 13 Jointer 4-1i2'H','iDP CCS.40 4.500 2.&a7 38.86 400.00 941.138 Yam 841.16 BIT DATA Bit Number Nozzles :6x13 Bit Size iIn€ : 9.875 TFA 0102) :0.7777 Slanu¢acturor : ttDES Dull Grade lo :NEW Model : M4165 Dull Orede Out . Serial Number . Page 22 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hilr»rp Alaskn,Ile 15.3 Ensure BHA components have been inspected previously. 15.4 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.5 Bit TFA should be —0.75 —0.80 in2. We need to pump at—450 - 500 gpm to clean the hole effectively. Have the directional driller run hydraulics calculations to confirm optimum TFA. 15.6 Primary bit will be the Security 9-7/8" MM65. 9-718" (251mm) MM65 PRODUCT SPECIFICATIONS r' Cutter Type SelectCutter IADC Code M323 Body Type MATRIX I Taal Cutter Count 46 Cutter Distribution .Umm las (. �+ Face 0 211 Gauge 12 0 Up Drill 6 0 Number of Large Nozzles 6 Number of Medium Nozzles 9 Number of Small Nozzles tt Number of Micro Nozzles 0 • x r Number of Pons(Sire) 1111 - {I t Number of Replaceable Ports{Size) tt Junk Slot Areal sa in) l611 Nonnakred Face Volume 45.49% API Connection 4-1fi2 REG.PIN Rctottiuu'ttdstil Make•L°p Torque* 12.461—12.766 Ft'lbs. Nominal Dinscnsions" Make-Up Face to None 10.81 in-275 sten ie eiauge Length 2.5 in-64 mon Sleeve Length 0 in-0 inn Shank Diameter 6 in-152 nm Break d)ut Plate tMat.tuLegacyb) 111195.4144040 Approximate Shipping Weight 250111s.-113Kg. SPECIAL FEATURES Up-Drill Curers on Gage Pati.1±16 Relieved Gage Material#771827 'Bit specific recommended makeup torque is a function addle bit LD.and actual bit sub O.D.utilited as specified in AN RP7G Section A.8.2. "•tkugn dimensions arc nominal and nny vary slightly on manufactured produca.Halliburton Drill Ritz and Services models are continuously m.rcaed and refined.. Product specifications may change without notice. C 2013 Hal libation.All rights reserved_Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.halliburton.com Page 23 Revision 0 Jun, 2014 II KBU 42-06Y Drilling & Completion Procedure Ilileorp Alnnka,1.1.0 15.7 9-7/8"hole section hydraulic summary: security cos BIT HYDRAULIC PROGRAM Prepared For-Hticarp K9U 32.08 �^ By-Alarm 9roulllet Dste prepared'-119114 Operator:-48tct rp Well NametNo.-KBU 3245 B=t Type:- PDC - - Contractor:- County-Kona+ i Bit Diameter:- 9.875:n. SurveyfAbetract:R StateiCountry:-AIWsA J MD Out:- 8400 ft Mud Nhiphl- 94 ppg COMPONENTS IO(In.) to in) 1 13 PV. 22 cp acing 8 951 1500 2 13 VP, Zea Ibt100111 n Hole 9.875' 6400 3 13 Fluid Model M."rr #++ VQ,KaasatR OC- +i 4 13 Ftow Rate, 5013 gpm 5 13 Max.Pump Press.;.____-.g00ps1 6 13 Surface equip.?-' 7 Motor bypass,' 8 TVD"', 5455 M 9 AofNozzle(110)`• . t rr=cuM.. .1 10 Min.TFA 0-3634 ire Brill String 1281.30 psi 47.62% Total TFA. It''r-Ire Annette 78.10 psi 2.89% Jet Velocity 206.37 His Surface 77.46 psi 2.88% Press.Drop 361.62 psi Special' 900.00 psi 33.27% Brt Hyd.Power 105.49 hp Bit 361.62 psi 13.3?% H,5.I, ' 377 hpllnr Impect Force 507.37 Ibf j (CD 9.78 ppg I ToIa9ISPP. 2705.49 psi 1 100.00% 00 ID Tool Joint Length) Cap. Pressure Loss DRILL STRING COMPONENTS In, In. DDI ID 11' bills .e, _ Drill Pipe(S1(CDS 40 Connections 4.5 3.826 6,375 3.5 55551 78.65 593.35 HWOP(CDS 40 connections,13 Mel 4.5 2.68 6.25 2.55, 403 2.80 199.60 Weatherford Hyd Jar COO 40) 6 2.25 6 2_25` 31 0.15 32,50 141NDP(CDS 40 connections,.6 Jts# 4.5 2.83 6.25 2.55, 166 1.20 92.12 X-O Sub PDS 40 Box X 4-112"1F Pin) 6,5 2.75 6.5 2.75' 4 0.03 1,76 4 Joints 9.314"NM Fla Drib Collars 8.75 2,613 6.75 2.813 120 0.92 47.95 Integral 91adeStabitizer 1'9.75'Gauge) 6.75 - 2.75 8.75 2.75 5 0.04 2.20 MWD TM HOC[Pulsar) 8.75 """"•"' 8.75 •"""`"' 18 450.00 MWD HCIM Collar 6.75 1,42 6.75 1.42`, 5 0.01 38.46 MWD-PWD Collar 6,75 5.42 6,75 1.421 5 0.01 38.46 MWD EWRP4 r Gamma Collar 6.15 1,42 6.75 1.42' 22 0.04 199,24 MWD Directional Collar 6.75 1.42 6-75 142 0 0.02 99.23 Integral BladeSlabitizer 49.75'Gauge) 6.75 2.75 6-75 275: 5 0.04 2.20 Floes Sub 6.75 2.75 8:75 275 3 0.02 1.32 7-Sperr Drtll Lobe 758 b.0 51g. 7 `^•^`^'•' 7 ^"`^'^ 281 450.00 ANNULAR: Hole ID.- Pepe OD Length Cum. Cap. Annular, Cr6Scel Type of Pressure Loss SECTIONSi in. in.. ft Depth Ws ftMnin• ftfmin Flow _1058_ Casing 9.95 4.5' 1500 1500 114.75 155.61 303.43 L 16.62 Open Ho1ep 9.875 (5 4058 5555 304.59 155.61, 305.05 L 46,43 Open Hole; 9.875 4.5 403 5981 38.25 158-61 305.95 L 4.61 Open Holai 9.875, 8.25 31 6992 1.76 209.66 154.73 L 0.77 Open Halal 9.87+5' 4-S 186 6173 13.96 158.41 305.05 L 2.13 Open Holai 9.87'S 6-5- 4 6182 0.21 221.75, 364.58 L 0.11 Open Hole, 9.8751 6.73 120 6302 6.05 235.89' 375 49 L 4.00 Open Holes 9.8151 6.75 5 6307 0-25 235 89, 375 49 I. 0.17 Open H0le; 9.8751 6.75 16 6323 0.81 235.89: 375 49 L 0.53 Open Hole! 9.875 6,75 5 6328 0.25 235,89, 375 49 1 0.17 Open Hole1 9.875 6.75' 5 6333 0.25 235.89. 375 49 1 0.17 Open Hole' 9.875 6.75 22 6355 1.11 235.89; 375 49 L 0,73 Open Hole 9.875 6.75. 9 6384 0.45 235-89' 375.19 L 0.30 Open Hole 9.875 6.75 5 6309 0.25 235.89, 375.49 L 057 Open Hole 9.875 6.75 3 6372 0.15 235.89 375.49 L 010 Open Hole 9.875 7 28 6400 1.32 252.80. 387.87 L 1.10 Page 24 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hilmrp Aln.kn,LLC 15.8 9-7/8"hole section mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1)ppg above highest anticipated MW. MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0—9.5 ppg 6%KCl/Kla-Shield fresh water based drilling fluid. Properties: Depths Density Plastic Viscosity Yield Point HTHP FL CL— LGS(%) (mg/I) 1600' 6,342' 9—9.5 15 30 20 30 <10 20,000— <6% 32,000 System Formulation: M-1 Swaco "Kla-Shield" Drilling Fluid Product Concentration Water 0.905 bbl Flowzan 1 ppb (Viscosity) PolyPac Supreme UL 1 ppb (API Fluid loss) M-I Wate As needed for density(Weighting Agent) Potassium Chloride(KCL) 21.8 ppb (Inhibition) Busan 1060 0.4 ppb (Biocide) EMI-2009 6 ppb(Shale/Clay Inhibition) DF-9065 0.05 ppb (Anti-foaming agent) Asphasol Supreme 4 ppb (Shale/Coal Stabilizer) Sack Black 3 ppb(Gilsonite Shale/Coal Stabilizer) Caustic Soda 0.2 ppb(pH controller) Page 25 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hilrorp Aln.kn,LLC 15.9 TIH, Conduct shallow hole test of MWD and confirm Gamma Ray LWD functioning properly. 15.10 Continue in hole and tag TOC. Note depth tagged on AM report. 15.11 Drill out plugs and shoe track. Clean out rat hole and drill an additional 20' of new formation. 15.12 CBU and condition mud for FIT. 15.13 Conduct FIT to 12 ppg EMW. ,/ 15.14 Drill 9-7/8"hole section to 6,342' MD/ 5,800' TVD. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. If tight hole is encountered, screw in and begin backreaming connections until hole conditions improve. Shales in the Beluga formations are notorious for swelling and causing tight hole. Most of the time, backreaming them on a short trip is the only solution. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. • Take MWD surveys every other stand drld. Surveys can be taken more frequently if deemed necessary. • Ensure to pre-treat the active system with 10 ppg Calcium carbonate. Have additional fibrous and other bridging material on location in the event lost returns is encountered. There are many stacked sands that are severely depleted that will be penetrated in the 9-7/8"hole section. Page 26 Revision 0 Jun, 2014 Drilling & CoKBmpletionU42-06Y Procedure 1 E4 Hilmrp Alxuka,LLC 15.15 Casing Point selection • KBU 11-08X is the closest offset to use for correlation to pick casing point. Below is the annotated GR+gas +resistivity log. / • We want to set the 7-5/8" shoe 10 - 20' into the MB3A shale. Me2e r . : , X-- spoil: : E _ - f `"" MB2C T ii - s �'= f 4- J :F 4 } o ,s. _ o � �wd82C Brr�raYrxc r � �- • . I,, • #: i -. a. :: IT.; t .` fF53AA T .�:.. ..... 4. "+ hS83AA {9: IIIIII 311111 T frl53A T r 9 6t „ rO _ t ! 7-5/8" Casing Point. lt ,. - _ -+ 'n M83A shale from z_ s •'' _:Sift ' = 5790'.o 5840'TVD. • ? ', .. .. . = .r ._ ` FAM a. - p.r ,_:::........... • � - —'ai183,ra 8 '� . ,r B"6 T n «�....� aas� ts- - a R ,_: ; ;.;.;;; 7:::: :;: - .. :;; 4..._41113111M 1 Ai 8 '°` u�esegall _B 111 4E1 lair '1493C_T -_ istir.„, • � a mB3CB) �_ < t-- ---_s + .4 :' d8C__Ts; . : ; :.._� .o':; ., -71. f3C > i9rt Page 27 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hilrorp Alaska,LLC 15.16 At TD; pump sweeps, CBU, and pull a wiper trip back to the 10-3/4" shoe. 15.17 TOH with the drilling assy, handle BHA as appropriate. 16.0 Run 7-5/8" Production Casing 16.1 R/U and pull 10" ID wear bushing. Install and test 7-5/8" casing ram in top ram cavity. Test to 250/3500 psi. ,/ 16.2 R/U Weatherford 7-5/8" casing running equipment. • Ensure 7-5/8"BTC x CDS-40 XO on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 16.3 P/U 7-5/8" 29.7# L-80 BTC shoe joint, visually verify no debris inside joint. 16.4 Continue M/U&thread locking the shoe track assy consisting of: • (1) Float shoe joint w/float shoe bucked on. Install (2)bow spring centralizers at 10' from each end over a stop collar. • (1) Baker locked joint. Install (1) centralizer mid tube over a stop collar. • (1) Float collar joint w/float collar bucked on pin end. Install (1) centralizer mid tube over a stop collar. • Ensure proper operation of float shoe and float collar. 16.5 Run 7-5/8" 29.7# L-80 BTC casing. • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Install centralizers over couplings on every other joint to 1550' MD. 16.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.7 Slow in and out of slips. 16.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe approx 10—20' above TD. Strap the landing joint Page 28 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Flilror1,Alaska,LLC while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. Casing and Tubing Performance Data PIPE BODY DATA GEOMETRY Outside Diameter 7.625 in Wall Thickness 0.375 in API Drift Diameter 6.750 in Nominal Weight 29.70 lbs/ft Nominal ID 6.875 in Alternative Drift Diameter n.a. Plain End Weight 29.06 lbs/It Nominal cross section 8.541 in PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Tension Yield 683,000 in Internal Pressure Yield 6,890 psi Collapse Pressure 4,790 psi Available Seamless Yes Available Welded No CONNECTION DATA TYPE:BTC GEOMETRY Coupling Reg OD 8.500 in Threads per in 5 Thread turns make up 1 PERFORMANCE Steel Grade L80 Coupling Min Yield 80,000 psi Coupling Min Ultimate 95,000 psi Joint Strength 721,000 lbs Internal Pressure Resistance 6,890 psi 7-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 7-5/8" 7,630 ft-lbs 16.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 16.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat(slightly) to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 16.11 Continue circulating until required properties achieved for cmt operations. 16.12 After circulating, lower string and land hanger in wellhead again. Page 29 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hilror1,Alnska.LLC 17.0 Cement 7-5/8" Cement Procedure 17.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 17.2 R/U cmt head (if not already done so). Ensure top and bottom plugs are loaded correctly. 17.3 Pump 5 bbls 10 ppg spacer. Close low torque on plug dropping head, test surface cmt lines to 4000 psi. 17.4 Pump remaining 35 bbls 10 ppg spacer and drop bottom plug. 17.5 Mix and pump slurry per below calculations: Section: Calculation: Vol(BBLS) Vol(ft3) LEAD: 9-7/8" OH x 7-5/8" csg: (5,842'- 3,000') x .038 bpf x 1.25 = 135 758 Total Lead: 135 bbls 758 ft3 2- sz TAIL: 500' x .038 bpf x 1.25 = 24 135 9-7/8" OH x 7-5/8" csg: TAIL: 90' x .046 bpf= 4.1 23 7-5/8" Shoe Track: r7 S 4 Total Tail: 28.1 bbls 158 ft3 Page 30 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hi!rorp:Unskn. Slurry Information Lead Tail System Light Weight Conventional Density 10.5 lb/gal 13.5 lb/gal ✓ Yield 3.32 ft3/sk 1.81 ft3/sk Mixed Water 12.67 gal/sk 9.26 gal/sk Mixed Fluid 12.67 gal/sk 9.27 gal/sk Expected 5:30 HR:MIN 5:00 HR:MIN Thickening Expected ISO/API Fluid 48cc/20min 24 cc/30min Loss Code Description Concentration Code Description Concentration G Cement 94 lb/sk G Cement 94 lb/sk BA 90 Bonding 15% BWOC BA-90 Bonding Agent 10% BWOC Agent FP-61 Anti Foam 1 gal/100sks Static Free Anti-Static 0.005 lbs/sk Static Free Anti-Static 0.005 lbs/sk FP-61 Anti Foam 1 gal/100 sks Additives Lost- Cello Flake Circulation 0.251bs/sk R-3 Retarder 0.4% BWOC material CD-32 Dispersant 1% BWOC FL-62 Fluid Loss 1.25% BWOC FL-52 Fluid Loss 1% BWOC ASA-301 Anti Settling 0.2% BWOC Agent A-2 Extender 0.5% BWOC A-2 Extender 0.5% BWOC LW-6 Extender 47% BWOC 17.7 After pumping cement, drop flexible shut-off plug and displace cement with mud. Use the cement unit to displace with as volumes can be tracked much more accurately. Displacement calcs: • 6,252' x .0459 bpf=287 bbls. • Displace with 10 ppg 6% KC1/Kla-Guard drilling fluid out of mud pits. 17.8 Monitor returns closely while displacing cement. Adjust pump rate if necessary. 17.9 Do not overdisplace by more than '/2 shoe track volume. Total volume in shoe track is 4.1 bbls Page 31 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure llilrorp Aln.kn.LI.0 17.10 There should be no cmt returns to surface. TOC is planned to be at 3000' MD. 17.11 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold,pressure up string to final circulating pressure and hold until cement is set. • If this is the case, monitor the pressure on the casing and do not let it exceed 500 psi over the final pump pressure. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement,actual displacement volume,whether plug bumped&bump pressure,do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to lkeller(,,hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. 17.1 R/D cement equipment. Flush out wellhead with FW. 17.2 Back out and L/D landing joint, flush out wellhead with FW. 17.3 M/U pack-off running tool and pack-off to bottom of landing joint. Set casing hanger pack-off. Run in lock downs and inject plastic packing element. Test void to 250/3000 psi for 10 min. 17.4 Lay down landing joint and pack-off running tool. Page 32 Revision 0 Jun,2014 KBU 42-06Y Drilling & Completion Procedure EIilrnrp AIn.lca.LLC 18.0 Drill 6-3/4" Hole Section 18.1 Remove 7-5/8" casing rams from BOP. Install 2-7/8" x 5" VBRs in top cavity. BOP configuration should be (from top down): Annular/VBR/Blind/Mud cross/VBR. 18.2 Test BOPs on 4-1/2" and 5"test joints. 18.3 R/U Mud loggers for the 6-3/4"production hole section. They need to be set up to generate mud log, pixler plots, and collect(3) sets of samples every 20 ft. 18.4 Pull test plug, run and set wear bushing. 18.5 Run CBL on 7-5/8" casing. 18.6 Ensure BHA Components have been inspected previously. Ensure to have enough 4" DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. 18.7 Drift& caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 18.8 Ensure TF offset is measured accurately and entered correctly into the MWD software. 18.9 Confirm that the bit is dressed with a TFA of 0.46 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 270 gpm. 18.10 Motor AKO should be set at 1.22 deg to allow maximum rotation. Max DLS in the 6-3/4"hole is planned at 1 deg/100. 18.11 Quad combo LWD will be run in 6-3/4" hole section: • Gamma Ray (DGR: Combined Gamma Ray) • Resistivity(EWR: Shallow/Med/Deep) • Density(DEN: Bulk Density) • Neutron (NEU: Thermal neutron porosity) • Sonic (XBAT: Compressional slowness) Page 33 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hitemp Alaska,LLC 18.12 P/U below 6-3/4" directional drilling assy: I1ALLIBURTONI i ear".".,,o",, WELL INFORMATION 41111WCreated On r Jarn, t4 BHA Tali Customer : Hilcorp 7 Well Name : KBU 32-08 Job Number : AK-XX- Drillstring Rig Name : Saxon Rig#147 IADC Rig BI-44# Country : USA Run# 300 State 1 Province : Alaska MPONENT DATA em 00 II) Gauge Weight Top Length Cumulative Description Serial Number lint (in) OM (Ibpl) Connection lft) Length lft) ® HUBS EM65D POC bit 4.504 7.563 6.750 47.67 GMMEII 0.75 0.75 Es 5'Sperry-Drill_obe 137-8.0 vg ® 5.000 3.12:7 48.00 B 3-1T IF 24.00 24.75 - Stab!:2er -_- 5.5'LI ---- 1 Flna1 Sub 41=0 7.750 ME S1,114 E3 3.112"IF 2 25 27.(X) © Woldod Bade Slahilirrr 4 544 2.{x30 5 571 52 00 B 3-1/2"IF 5.00 32.00 ® 4 3W DM Collar 4 73" 1.25'3 47 00 9 3-1/2"IF 9.20 41.20 6 4 314'Slim Phase 4 Colla- 4.750 1.250 48.20 B 3-1,2"IF 24.50 65.70 7 Inline S1abik er I:ILS: 4.740 1.9923 6. 0 50 27 B 3-112"IF 3.50 69.20 a 43W ALD Collar - 4.750 1.250 5.675 45 511 13 3.117"IF 14.00 53.20 _ S14F1,9.0 -_� 557.5 ® 4 3+'4"CTN Collar 4.750 1.253 50 50 B 3-112"IF 11.00 64.20 10 4 1.4"PWD 4.750 1_250 47.90 B 3-112"IF 9.20 103.40 ® 4 3/4'TM HOC(Pulser) 4.790 1.250 40 90 8 3-10"IF 11.00 114 40 Ea 4 314"BAT Collar111111111111 4.75() 1.250 1111111111331111 B NC 31i 75 42 140 112 ® 4 75"Flex Collar 4.750 2.250 45 S4 n 3-1,2"IF 31.00 171 52 ® 4,75"Flex Collar 4.750 2.250 40 84 9 3-1.2'IF 31.00 202.82 ® K-0 3-1./2"IF Pin X 4-11'2"CDS 40 Box 5.250 2.250 00.22 B 4.5'CDS-43 2.75 205.57 ICI 6 Joints 4-112'NWDP 4.500 2.750 41 00 185.00 390.57 ® X.0 4 117'CDS-40 Pin X 3 112'11 hnx 5 100 2.753 h1 54 9"1 '12"IF 7 75 :193 32 ICI 4 3/4"Weatherford Hyd Jar 4 750 2250 46 54 =Ea 30 00 423 32 ® X-O 3-1'2"IF Pir X 4-112"CDS-40 Box 5.300 2.750 54 04 8 4.5'CDS-40 2.75 420.07 ® 13 Joints 4-1!T HWDP 4.500 2.75 41.00 400.00 826.07 ToIaL 826.07 BIT DATA tilt Number Nozzles : 6x1 d Bit SIze (In) : 6.750 TFA (In2) : 0.4602 Menuteeturer : HOBS Dull Grade In . Model : Eld65D Dull Grade Out - Serial Number . Page 34 Revision 0 Jun, 2014 fill KBU 42-06Y Drilling & Completion Procedure IIih•orp Aln.hn.1.1.1 18.13 Hydraulics Summary: security DBS BIT HYDRAULIC PROGRAM Prepared For.Hncorp KBU 32.08 •�.:�' By-Mark Broulnal Date prepared:-119114 °mam a/ I# I Well NamelNo-KBU 32.08 BitT pe:- PDC Itwap y Contractor: � County•Kann. Bit Diameter:- 6.75 in. SuneyIAbatract: SletelCountry-AKIUHA MO Out:- 9350't Mud Walgta, 10:3 ppg COMPONENTS 10(In.) To(try 1 10 ..... Pli113 00 'Caning 6.875 6400 2 1l0 yP 191bf100ttz �� pen Hale 6?5g 9350 3 10 Fluid Model' i4Ma 55s5d Fuc 4 10 Flow Rate! 275 gpm 5 10 Max,Pump Press. m 4000 pet 6 10 Surface equip.?2 -i 7 Motor bypass?! 6 TVD717$531! 0 4o1Nozzle(s10)6 •'45.a 's,.ta&n Ca •1 3 L 10 Min.TFA 0.1974 in` OralSiring 613.90 psi 35.40% Total TFA 0 4,.,02 inn 399.97 psi 14.99% Jet Velocity 191.62 his SnAeee 29.19 psi 1.18% Press.Drop 345.31 psi Speelai' 050.00 p l 34.44% Bit Hyd.Power 55.40 hp 345.31 psi 13.09% H.5,1. 'r.192 hplln' Impact Force. 286.69 Ibt ECD 11.41 ppq TeesifSPP1 2468.37 pal I 100.00% 0D ID Tool Joint Length Cap. Pressure Loss DRILL STRING COMPONENTS In. In OD 0 It bbls psi Drill Pipe(S)(CDS 40 Connections 4.5 3.626 6.375 15 6517.5, 120.53 319.99 11WDP(CDS 40 connections.13 JIs1 1 43 2.08 6.25 2.55 403 2.80 68.47 4-314'Weelherford WO Jar wI X-0's 5 2.25 5 2.25 35 0.17 12,43 ItWDP(CDS 40 connections,6 As) 4,5 2.66 5.25 2 55 186 1.29 31.60 X-0 Sub(CDS 40 Boa X 3-112"IF Pin) 4,7 2,5 5 2,3 4 0.02 0.92 `2 Joints NM Pies Drill Collars 4.75 2.5 4.73 2.5 60 0.36 13.61 MWD lBat Sonic 4.75 1.25 4.75 1.25 26 0.04 112.82 51W135 TM HOC(Pulsar) 4.75 4.75 ******••••"' 11 400.00 MWD fFWD 4,75 1.25 4.75 1.25 9 0.05 99.05 MWD IALOLTN INukee4 1I 4.75 1.25 4.75 1,25 25 0.04 108,45 inline Stabilizer HLS 6"Gauge) + 4.75 1.25 4.73 1.25 3.5 0.01 15,15 MWD!DlrocLanaltSlim Phase 4 4.75 1.25 4.75 1.25 34 0.05 147.54 NM String Stabilizer(8.625Gauge) 4.75 2 4.75 2 5.5 0.02 3.23 Float Sub 4.75 2.5 4.75 2.5 2.5 0.02 0.57 5"5perryVrtll Lobe 617.6.0 MgIW(AB8I 5 """"'""'" 5 """*'"-' 28 """""""' 450.00 ANNULAR Hole ID Pcpe OD Length Cum. Cep. Annular! Critical Type of Pressure Lass SECTIONS in., in., ft Depth bbl, flitalni 51,httln Flow _Piz_. Casing 6.875 4.5, 6400 6400 187.96 249.49i 310.59 1. 242,12 Open Hole 6.75 4.5 2117.5 8517.5 52.07 268_281 314.12 L 89.68 Open Hale 6.15 4.5 401 8920.5 9.91 260.261 316.12 L 17.07 Open Hale 6.75 4.7 35 8955.5 0.80 287.561 325.86 L 1.77 Open Hale 6.75 4.S 186 9141.5 4.57 266.381 316.12 L 7.88 Open Hale 6.75 4.7 4 9145.5 0.09 287.141 320.66 L 0.20 Open Hale 6.75 4.75 60 9205.5 1.34 293 05! 325.50 L 3.18 Open Hole 6.75 4.75 26 9231,5 0.56 293 05i 328 50, 1 1.38 Open Hole 6.75 4.75 11 9242,5 0.25 293 051 32e SO! 1. 0.58 Open Hole 6 75 4.75 9 9251.5 0.20 293 051 328 501 L 0.46 Open Hole 6.75 415 25 9276,5 0.56 293.05> 328 501 L 1.32 Open Hole 6.75 4.751 3.5 9280 0.06 293.05' 328 501 L 0,19 Open Hole 6.75 4.75. 34 9314 0.76 29305 320.501 L 1.80 Open Hole 6.75 4.751 5.5 9319.5 0.12 293.05. 320.501 L 0.29 Open Hole 6.75 4.75` 2.5 9322 0.06 293.05 320.501 L 6.13 Open Hale6.751 5 28 9350 0.56 327.79;, 343.121 L 1.81 I I_ I Page 35 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hileorp Aln«ka.LLC 18.14 Primary bit will be the Security EM65D. 6-3/4" 1;171 mm} EM65D PRODUCT SPECIFICATIONS Cutter Type X3-Extreme Drilling sr IADC Code M323 �. Body Type MATRIX TcNul Cutler Count 33 rope„,,.. Cutter Distribution J,3oppti .L rl♦► Face 4 Fl 4 Gauge II 0 r Up Drill S 0 Number of Large Nozzles 0 • Number of Medium N mzless 0 Number of Small Nozzles 6 r tr Number of Micro Nozzles 0 Number cit (Site) (l '"a Number of Replaceable Ports(Size) 0 r i Junk Slot Area(sq in) g.68 Nnrrnalrzed Face Volume 34.69'% API Connection 3-It2 REG.PIN „ar Recommended Make-Up Torque* 5,173—7.665 Ribs. 1 Nominal Dimmnsions'• Make-Up Face to Nose 9.42 in-239 nun Gauge Length 2 in.5!mon Sleeve Length 0 in-0 nun Shank Diameter 4-5 in-114 nm Break Out Plate(Mat#4,egacy ) 161953,'4.11341 Approximate Shipping Weight 90Lbs.-41 Kg. SPECIAL FEATURES Up-Drill Cutters on Gage Pads,I,'16"Stepped Gage,Optimized Dual Row-"D"Feature Material 4761302 "Bit specific i mended make-up torque is*function of the hit F.D.and actual hit nib O.D.utitirrd ns specified in All Rro Sects.n A2, "Design dimeneinns are nominal rid may very slightly on nunufacrurrd product.Hnitihurrcan Drill Bice and Services needels dee enminu.iu ly reviewed and refined. Product specifications may ctiunar. irhuut nosier, t 2013 Halliburton.All rights reserved_Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.haltiburton.com Page 36 Revision 0 Jun, 2014 14KBU 42-06Y Drilling & Completion Procedure Hilrnrp Alaska,LI.0 18.15 TIH to TOC. Shallow test MWD on trip in. Note depth TOC tagged at on AM report. 18.16 Conduct casing test to 3500 psi/30 min. 18.17 Drill out shoe track and additional 20' new formation. CBU and prep for FIT. 18.18 Conduct FIT to 13.5 ppg EMW. 18.19 Drill 6-3/4"hole to 10,448' MD / 9,750' TVD • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • See attached mud program for hole cleaning and LCM strategies. Ensure adequate LCM is available on location in the event returns are lost. • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain HTHP fluid loss <9. • Take MWD surveys every other stand drilled. • Pull wiper trips every 500— 1000 ft drilled. If tight hole is encountered, screw in and begin backreaming connections until hole conditions improve. Page 37 Revision 0 Jun,2014 KBU 42-06Y Drilling & Completion Procedure Hibor,,11o4ka.LLC 18.20 6-3/4"hole section mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 10— 12.5 ppg 6%KC1/Kla-Shield fresh water based drilling fluid. Properties: Depths Den ' Plastic Viscosity Yield Point HTHP FL CI LGS(%) (mg/I) 6,342— 10— 12 10 16 15 23 <9 20,000— < 6 410,448 N 32,000 ,r,7 System Formulation: M-1 Swaco "Kla-Shield" Drilling Fluid Product Concentration Water 0.905 bbl Flowzan 1 ppb (Viscosity) PolyPac Supreme UL 1 ppb(API Fluid loss) M-I Wate As needed for density(Weighting Agent) Potassium Chloride (KCL) 21.8 ppb(Inhibition) Busan 1060 0.4 ppb(Biocide) EMI-2009 6 ppb(Shale/Clay Inhibition) DF-9065 0.05 ppb(Anti-foaming agent) Asphasol Supreme 4 ppb (Shale/Coal Stabilizer) Sack Black 3 ppb (Gilsonite Shale/Coal Stabilizer) Caustic Soda 0.2 ppb (pH controller) 18.21 Hilcorp Geologists will follow LWD log closely to determine exact TD. 18.22 At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8" shoe. 18.23 TOH with drilling assy. 18.24 No open hole logs are planned. Page 38 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure LI.korp Aln.kn.LLC 19.0 Run 5" Production Long String 19.1 R/U Weatherford 5" casing running equipment. • Ensure 5"DWC/C HT x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure to R/U Tesco or Weatherford CRT so that string can be rotated if necessary while running. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 19.2 P/U shoe joint, visually verify no debris inside joint. 19.3 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/shoe bucked on&threadlocked(coupling also thread locked). • (1) Joint with float collar bucked on pin end &threadlocked (coupling also thread locked). • (1)Joint with landing collar installed INSIDE pin end. • Solid body centralizers will be pre-installed on shoe joint&FC joint. • Install a solid body centralizer on landing collar joint. Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe. 19.4 Continue running 5"prod casing. • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every joint to 6,118' MD. Leave the centralizers free J J J\ floating. 5`' rttN • Ensure to install swell packer joint so that it is 500' from the 7-5/8" shoe when landed out. • Utilize a collar clamp until weight is sufficient to keep slips set properly. `�� 5" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 5" 10,700 ft-lbs 12,100 ft-lbs 16,000 ft-lbs Page 39 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure ',i,.r,,.TIE Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWC!C-HT Casing 5 in 18.00 Ib/ft(0.362 in) L-80 ..atanja- Material L-80 Grade 80.000 Minimum Yield Strength(psi) IMINENIIilimirUSA 95.000 Minimum Ultimate Strength(psi( VA),4-USA Pipe Dimensions 4424 W.Sam r'eustrn Rory.SU*153 Houston,Tx 77041 5.000 NominalPipeBodyO.D.(in) Puma: 713-479-3203 4.276 NominalPipeBodyl.D.(in) Far.71&4`}3234 0.362 NominalWallThickness(in) Eanatt:VAkli3sAsa am-usa.cxn 18.00 Nominal Weight(lbs/ft) 17.95 Plain End Weight(I bs,`ft) 5.275 MominalPipeBodyArea(sq in) Pipe Body Performance Properties 422.000 Minimum Pipe Body Yield Strength(lbs) 10.490 Minimum Collapse Pressure(psi) 10.140 Minimum Internal Yield Pressure(psi) 9.300 Hy d ro static Test Pressure(psi) Connection Dimensions 5.563 Connection O.C.(in) 4.276 Connection I.D.(in) 4.151 Connedion Drift Diameter(in 4.06 Make-up Loss(in) 5.275 Critical Area(s_q in) 100.0 Joint Efficiency(%) Connection Performance Properties 422.000 Joint Strength(Ibs) 16.750 Reference String Length(ft) 1.4 Design Factor 457.000 API Joint Strength(Ibs) 422.000 Compression Rating(lbs) 10.490 API Collapse Pressure Rating(psi) 9.910 API Internal Pressure Resistance(psi) 73.3 Maximum Uniaxial Bend Rating[degreesd100ft] A.ppQxirrlated.Field End Torque Values 10.700 Minimum Final Torque(ft-I bs) 12.100 Maximum Final Torque(ft-Ibs) 16.000 ConnedionYieldTorque(ft-lbs) For detailed information on performance properties,refer to DWC Connection Data Notes on following page(s). 0 Connection specifications within the control of VAM-USA were correct as of the date printed.Specif eat ions are s ut>tect to charge without notice.Certain comeebn specifications are dependent on the mecharical properties of the pipe.Mechanical properties of mil proprietary pipe grades were obtained from mill publications and are subject to change.Pr perties of mill proprietary grades shaid be ccnfirmed rah the mill.Users are advised to obtain current correct brspecifications andverifypipemechanicaIpropertiesfcreachappliation. Page 40 Revision 0 Jun, 2014 14KBU 42-06Y Drilling & Completion Procedure Hilrorp Alaska,LI.0 19.5 M/U casing hanger joint to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe approx 10—20' above TD. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 19.6 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 19.7 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat(slightly)to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 19.8 After circulating, lower string and land hanger in wellhead again. Page 41 Revision 0 Jun, 2014 S 14KBU 42-06Y Drilling& Completion Procedure Hilrorp LLC 20.0 Cement 5" Production Long String 20.1 Hold a pre job safety meeting over the upcoming cmt operations. Ensure the below is covered during the meeting: • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 20.2 Attempt to reciprocate the long string during cmt operations. 20.3 Pump 5 bbls 12 ppg MUDPUSH II spacer. 20.4 Test surface cmt lines to 4500 psi. 20.5 Pump remaining 15 bbls 12 ppg MUDPUSH II spacer. 20.6 Mix and pump 15.7 ppg class "G" cmt per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump 100% OH excess. Section: Calculation: (BSLS) Vol(ft3) 7-5/8"x 5" long string Overlap: 500' x 0.022 = 11 61.8 6-3/4" OH x 5" Longstring: (10,448 —6,342') x 0.020 x 1.5 = 123 690 Shoe Track: 90' x 0.019 = 1.7 9.5 Total Volume: 136 bbls 764 ft37s 5go 1p CG Page 42 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hilror1,Alswka.1.11 Slurry Information: Tail System Conventional Density 15.7 lb/gal Yield 1.18 ft3/sk Mixed Water 4.968 gal/sk Mixed Fluid 4.968 gal/sk Expected 7:00 HR:MIN Thickening Expected ISO/API Fluid 24 cc/30min Loss Code Description Concentration G Cement 941b/sk BA-10 Bonding 1% BWOC Agent Additives Static Free Anti-Static 0.005 lbs/sk FP-6I Anti Foam 1 gal/100 sks R-3 Retarder 0.7% BWOC CD-32 Dispersant 0.6% BWOC A-2 Extender 0.4%BWOC 20.7 Drop top plug and displace with Lease water. 10,358 ft x .01776 = 184 bbls. 20.8 Do not overdisplace by more than '/z shoe track. Shoe track volume is 1.7 bbls. 20.9 Bleed pressure to zero to check float equipment. 20.10 Pressure up again to 3500 psi and hold for 30 min to test production bore. Page 43 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure II Ieorp%inskn,LI.0 Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to lkeller@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. 21.0 RDMO 22.1 Install back pressure valve in hanger neck. N/D BOP. 22.2 N/U tree. 22.3 RDMO Saxon Rig#147. 22.4 After rig has departed,pull BPV &run CBL to determine TOC behind 5"production casing. 22.0 Perf and Frac 23.1 A separate Sundry will be submitted to the AOGCC that will cover the perf& frac operations for KBU 42-06Y. 23.2 Ensure to run a CBL across 5"to determine TOC after rig has departed. Expedite this to AOGCC ASAP. 23.3 Test 5" x 7-5/8" annulus to 2500 psi after swell packer has had sufficient time to inflate. Page 44 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure 11ilvorp;laukn.LLC 23.0 BOP Schematic 121 1111 1.1 I.I III 4 • Saxon Rig 147 11"5M T-3 Energy BOP rii:ill lir mit. 13-Energy Model 60111 _ Manual Manual Manual -' �•`' Vale Valve Valve p r111tat Ili 10t 11111 Kiillla �� IICc;ii' 111LØ ltllil.- 13-Energy Model allica .. (111 Irll�l Irl I>II Spam spool 115MX115M 4 MI III 1/1 "1111 Seaboard-MBS system 16o^,3MX115M .1 k !4EII■ 1• r hJ * . I 714.• I�{ *'{"SII,r• I : ii .rl Page 45 Revision 0 Jun. 2014 KBU 42-06Y Drilling & Completion Procedure Hilrnrp:Unskn,LLC 24.0 Wellhead Schematic KBU 42-06Y _30 evil,ear. 1.0.0.4111 3-1.i5'"14rv+1 i�/ `o4 III41160.011111 to;) s ■rw-milr t3-1115`'1C41 3-1116"I4M 'iia. IlhamrriNI /4,, ..,3-SfSfi"10h4 `ie.i. ISI, ! Adapte•,5M-E-ZCLri """t Li'''SM x 3-11115"1CM III IMMO Mu1CPJR,iM i-t-XL -ii =�, to 5+r 11 x 3-1/2 AS MOD 5i*X181 ■ill ■ x1-1,12eJ!MD110Opp m In . I �l'��li [ Ink 0 �,,` ! � a.11: Ct"J1IO Me eXfi -221I+ 1 11 X 1-5/5 Ir. Irl; 2-1 4 1.4 40/201.x331[141.1r ii s.!!rr� iItF1s • � ,�I,�t 1 10-3/4 S 3 I 4.I tiA91 G II,e,111t%1. Seib-22 2-1/1i,1 15-3/4 x 10-3/4 , 3/4!M I.�I # Ir.. sill�a 106.-.11 r' I . !? t 1$CASIX0 2-1/141 S1 10-3/4 CA51100 - '3/5 COMM r 301/2%Ili D-.........0.-.........0. �0 7- SEAJPOARD 3030 Pei Weetlesa&W000 psi tree assy 36x30-2/4517-312x3-312 4€3 110C1313 oon C DM 00CIANDIT ii. it-__._ ILT4' F' . in rz. I ,.,4-1., i►- : P-�4873 ® Page 46 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hikorp Alaska, 25.0 Days Vs Depth Days Vs Depth 0 ._.\\ -KBU 42-06Y -KBU 11-08Z Actual 2000 4000 a�. C7 -0 6000 \\\\N 8000 1.0000 12000 0 5 10 15 20 25 30 35 Days Page 47 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Mem?Ala,l.a.1.1,1 26.0 Formation Tops ANTICIPATED FORMATION TOPS&GEOHAZARDS FIELD/POOL EXPECTED FLUID Est MD TVD(FT) SUBSEA DEPTH Esr.Pressure Kenai,Sterling Upi Sterling gas(Tie-In KBU 42-6X) 4,943 3,589 (4.856:; 250 Kenai,Sterling 5.2 Sterling 5.2 gas 5,841 4,191 (5,754) 180 Kenai. BelugaiUpper Tyonek Gas Pool (aka UP Tyonek Beluga Gas) Upper Beluga gas 6,408 4,698 (6,321) 900 *same as above Middle Beluga Secondary,Target gas 7.097 5,377 (7.010) __ 1000 "same as above Lower Beluga Secondary Target gas 7.828 6,107 (7,741) 1000 'same as above Upper Tyonek Secondary Target gas 8,960 7.186 (8.873) 2500 'same as above Tyonek Dl Secondary Target gas(Tie-In KTU 43-6XRD) 9.403 8.765 (9,316) 2000 Kenai,Tyonek Gas Tyonek D2 Primary(test) gas(Tie-In KDU 01) 9.929 8.848 (9.842) 1000 'same as above Tyonek03 Primary(test) gas 10.148 9,109 (10,061) 3500 "same as above Tyonek D4 Primary(test) gas 10,415 9.314 (10,328) i 4137 'same as above Tyonek D5 Primo,(test) gas 10.507 9,438 (10,420) 4191 'same as above Tyonek D6 - (# (test) gas 10.647 9,491 (10.560) 4214 Total Depth 10,810 9,750 (10,723) =Possible Geo Hazards I ��rte Y t.*' L O i - �f 15 771/ L� Page 48 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hilcarp Alaska,ILLC 27.0 Anticipated Drilling Hazards 13-1/2" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, & 750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Safe-carb 10 & 20 to the active system at 1 —2 ppb. Hole Cleaning: Maintain rheology w/gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 25 —45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of—50 - -60 lbs/100ft2 to combat this issue. Maintain low flow rates for the intial 200' of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 —30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 49 Revision 0 Jun,2014 KBU 42-06Y Drilling & Completion Procedure FTileorp Alaska,TIC 9-7/8" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, & 750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. Background concentrations of LCM (sized calcium carbonate) should be btwn 5 — 10 ppb while drilling this interval. There is a high probability of lost returns through the many stacked, depleted sands in this hole section. Hole Cleaning: Maintain rheology w/flowzan. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain 1ppb total of PolyPac Supreme UL to maintain a thin/strong wall cake and keep HTHP filtrate below 9 ml/30 min. Maintain MW as necessary using additions of Barite. Maintain 6 ppb EMI-2009 for shale/clay inhibition. Maintain 4 ppb Asphasol Supreme & 3 ppb Sack Black for Shale/Coal stabilizer. Maintain 6%KC1 in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams (Asphasol Supreme, Sack Black). • Increase fluid density as required to control a"running coal". • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb Asphasol Supreme pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss. H2S: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. '/ Page 50 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure Hi'corp Alaska,LLC 6-3/4" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, & 750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Safe-carb 10 & 20 to the active system at 1 —2 ppb. Hole Cleaning: Maintain rheology w/flowzan. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain 1ppb total of PolyPac Supreme UL to maintain a thin/strong wall cake and keep HTHP filtrate below 9 ml/30 min. Maintain MW as necessary using additions of Barite. Maintain 6 ppb EMI-2009 for shale/clay inhibition. Maintain 4 ppb Asphasol Supreme& 3 ppb Sack Black for Shale/Coal stabilizer. Maintain 6%KC1 in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams (Asphasol Supreme, Sack Black). • Increase fluid density as required to control a"running coal". • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb Asphasol Supreme pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss. H2S: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 51 Revision 0 Jun,2014 11 KBU 42-06Y Drilling & Completion Procedure Hilmrp Aln.kn.I I I 28.0 Saxon Rig 147 Layout 123'._7" 26'--C" 55'-6" 30'-0" t=1 ...,I PRE-4TANK!TOTAL Val 396 8HL5'I 1� r�� ' ��!�_'1 Wr.II 7I (Ilf!Illll�lklllll -. '-', 1111. , !— 1 ��Itlarnull, - 11 HK 717 =a' Atnownow I P p,c MUD XA(TQTfw,,YOLv5 9LSl Ni _ 1111:....1- 11 ..--1 ono ---'-- !II r- ..,.-.,' ' 1 ..,711- ma GAS n WI° Ninipir _ 111. '1-- r ,.:-,.... 1 --- r-_-.--th.- -..--t-: E" '--1; - . 3 , rt PI! mimmin - ■"11; 11N1111111111111111111NIN111111111111M1111111111111111111111111111N11I11111111111111I1IIIII111IP1f1I111mNunn'•''" mlll ' 111111IIIIIIIIIII11111IIIIIIIII a1111111NIN1111111111111111111 111111a111111II111111I1lII1I11111IIIIII11II111111IIIIIIIIIIIIIIIIIIIIIIIImmnnunlnlm�t Illnui lr �IININIIIIIIIIIIIIIIIIII''01 -- Pal'■ IHI I I IIIIII 11111111111111111111111111111111111111111111111111111 1"Imlal I nlp"' ,�,. = 1►�IIIIIIIIINI •n141� NNW """""n SII 1 NI a �, I I _._.._1.___.v___ ik. , •.. _I Mai 11 ' V IRSTRSIfTt KW .I ... ..._ .... �� — �F II#1111�1111UI111Pt r IlIIII�1111111111IIII1lI1111111111111lII11111rnlmmrllmumk.. -- E0 141111III1111111mm ` --�� MINIMI 11 IIIIIIIII1111111IIIIIIIIII11111111IIIIIIIII111111111IIIIIL111111II11111I'11f11111I�!iLII!.!!!I IIii91111IIIIIIIII1111111 , 1E1111111o I1111111111111111NI111111111IIII1111111111IIII111I111III1IIIII111111111111115111Nii11111110 I 1 111111111111111111111111111111 111111111111111 LI 11111 -- ' unnnll ra uu nu I II ' 1'1 (! InII:Iainri. ....v 111013 L 1.1301 >:p , °1 ztirssace_uu2sa DQGHODSFJWATFR TANK)OO1fOQit 53'-0" t• 45'_0" ``� 85'-0" I 85'-5" 170'-4- Page 52 Revision 0 Jun,2014 14KBU 42-06Y Drilling & Completion Procedure Hilrarp AIa+La,[.LC 29.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer(ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 53 Revision 0 Jun,2014 14 Drilling & CompletionKBU42-06Y Procedure 11ilrorp Ala•I•n.1.1.1. 30.0 Choke Manifold Schematic j ar � l're 't') ,.1.,,.iif ra — dqN S ♦%• r NL lri 6.4 A a 1 1 I J :c2 I 40.0o -,- 1 ,fi rwue n rr Z ,1114101 l-4 () " me y F iik. ivy��, i ■ a f. Ittr."V.'' .R1 ail it' •i r am-A-4-x--, _�, - . . Icy e ___, ,... e e . ., ,._.... M,,i.�,. R m` y. I, iH Mei rq1�o NM _ ‘...41••' ! yI � i 1 a O it a I' $ et 4 i _ 11 • i i' L L L_ 1?1 �! -_g .�f MTS ,. e R t li Iil qi 1 Page 54Revision 0 Jun. 2014 KBU 42-06Y Drilling & Completion Procedure Hilrorp Ala«ka.LLC 31.0 Casing Design Information Calculation&Casing Design Factors Kenai Beluga Unit DATE:6-3-2014 WELL:KBU 42-06Y FIELD:Kenai Gas Field DESIGN BY:Luke Keller Design Criteria: Hole Size 9-7/8" Mud Density: 9.5 ppg Hole Size 6-314" Mud Density: 12.5 ppg Hole Size Mud Density: Drilling Mode MASP(sec 1): 1244 psi(see attached MASP determination&calculation) MASP(sec 2&3): 1937 psi(see attached MASP determination&calculation) Production Mode MASP: 3265 psi(see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1,2 Max MW gradient external stress and the casing evacuated for the internal stress 3 12.5 ppg MW gradient external stress and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 Casing OD 10-314" 7-518" 5" Top(MD) 0 0 Top(TVD) 0 0 0 Bottom(MD) 1.600 6.342 10,448 Bottom(TVD) 1.488 5.800 9.750 Length 1,600 6.342 10,448 Weight(ppf) 45.5 29.7 18 Grade 1-80 L-80 L-80 Connection BTC BTC DWC/C HT Weight w/o Bouyancy Factor(lbs) 72.800 188.357 188.064 Tension at Top of Section(lbs) 72.800 376,421 188,064 Min strength Tension(1000 lbs) 1040 683 457 Worst Case Safety Factor(Tension) 14.29 1.81 2.43 Collapse Pressure at bottom(Psi) 735 2.865 6.338 Collapse Resistance w/o tension(Psi) 2,480 4.790 10.500 Worst Case Safety Factor(Collapse) 3.37 1.67 1.66 MASP(psi) 1.244 3.265 3.265 Minimum Yield(psi) 5.210 6.890 9.910 Worst case safety factor(Burst) 4.19 2.11 3.04 Page 55 Revision 0 Jun,2014 KBU 42-06Y Drilling & Completion Procedure IIiI,orp AI"rhn.LI 32.0 9-7/8" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 9-7/8"Hole Section KBU 42-06Y Alilmr�.11.4n.IIA Ninilchik Unit MD TVD Planned Top: 1600 1488 Planned TD: 6342 5800 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad S:erling 3,589 250 Gas 13 0.070 Sterling 5.2 4,191 180 Gas 0.8 0,043 Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date KBU 11-17X 9-9.2 1,587 5,464 2009 KBU 14-08 9-9.2 1,510 5,432 2008 KBU 41-18X 9-9.2 1,500 5,391 2008 KBU 24-7X 9-9.7 1,502 5,326 2006 KBU 11-08Z 9.2-9.3 1,613 5,946 2014 KBU 23-05 9.3-9.4 1,520 6,118 2014 Assumptions: 1. Fracture gradient at 1,600'MD/1,488'TVD is estimated at 0.936 psi/ft based on field test data. 2. Maximum planned mud density for the 9-7/8" hole section is 9.5 ppg. 3. Calculations assume"Unknown" reservoir contains 100%gas(worst case). 4. Calculations assume worst case event is 2/3 evacuation of wellbore to gas. Remaining 1/3 volume in wellbore remains drilling fluid density. Fracture Pressure at 10-3/4"shoe considering a full column of gas from shoe to surface: 1488{ft)x 0.936(psi/ft)= 1392 psi 1392(psi)-[0.1{psi/ft)*1488(ft)]= 1244 psi MASP from pore pressure(unknown gas sand at TO,at 9.2 ppg(0.4784 psi/ft) 5,800(ft)x 0.4784(psi/ft)= 2774 psi 2774{psi)-[(2/3)'0.1(psi/ft)`5,800(ft)]-[(1/3)"0.494(psi/ft)=5,800(ft)]= 1433 psi Summary: 1. MASP while drilling 9-7/8"intermediate hole is governed by fracture gradient at the 10-3/4"casing shoe Page 56 Revision 0 Jun, 2014 II KBU 42-06Y Drilling & Completion Procedure 11;1,09v Alaska,1,1.0 33.0 6-3/4" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 111 6-3/4"Hole Section KBU 42-06Y 1�,,•. +„ Cook Inlet,Alaska MD TVD Planned Top: 6,342' 5,800' Planned TD: 10,448' 9,750' Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Lower Beluga 6,107 1000 Gas 3.1 0.164 Upper Tyonek 7,186 2500 Gas 6.7 0.348 Tyonek D1 8,765 2000 Gas 4.4 0.228 Tyonek D2 8,848 1000 Gas 2.2 0.113 Tyonek D3 9,109 3500 Gas 7.4 0.384 Tyonek D4 9,314 4137 Gas 8.5 0.444 Tyonek D5 9,438 4191 Gas 8.5 0.444 Tyonek D6 9,491 4214 Gas 8.5 0.444 Offset Well Mud Densities Well Max Drlg MW Top(TVD) Bottom (TVD) Date KBU 11-17X 10.7 5,464 7,919 2009 KBU 14-08 10.3 5,432 7,746 2008 KBU 41-18X 11.6 5,391 8,651 2008 KBU 24-7X 9.7 5,326 7,550 2006 KBU 32-08 10.7 6,418 9,847 2014 KBU 43-07Y 12.1 6,287 9,853 2014 KBU 11-08Z 12.1 5,946 9,900 2014 Assumptions: 1. Fracture gradient at shoe is estimated at 0.936 psi/ft based on field test data. 2. Maximum planned mud density for the 9-7/8"hole section is 12ppg_ 3. Calculations assume"D"Sand contains 100%gas(worst case). 4. Calculations assume worst case event is 2/3 evacuation of wellbore to gas. Remaining 1/3 volume in wellbore remains drilling fluid density. Fracture Pressure at 7-5/8"shoe considering a full column of gas from shoe to surface: 5,800(ft)x 0.936(psi/ft)= 5429 psi 5,429(psi)-[0.1(psi/ft)'5,800(ft))= 4849 psi Drilling Mode MASP MASP from pore pressure(2/3 wellbore evacuated to gas from"D6"at.444 psi/ft) Page 57 Revision 0 Jun, 2014 KBU 42-06Y Drilling & Completion Procedure HiIcorp Alaska.LI.E 9,491(ft)x 0.444(psi/ft)= 4214 psi 4,214(psi)-[[0.1(psi/ft)`9,491(ft)'2/3]+[0.52(psi/ft)'9,491(ft)*1/3J1= 1937 psi Production Mode MASP MASP from pore pressure(entire wellbore evacuated to gas from Upper Tyonek): 9,491(ft)x 0.444(psi/ft)= 4214 psi 4,214(psi)-[0.1(psi/ft)"9,491(ft)]= 3265 psi Summary: 1. MASP while drilling 6-3/4"production hole is governed by 51BHP minus 2/3 wellbore evacuated to gas from the Upper Tyonek formation. 2. MASP during production mode is governed by SIBHP minus entire wellbore evacuated to gas from the Upper Tyonek formation. Page 58 Revision 0 Jun, 2014 II KBU 42-06Y Drilling & Completion Procedure linearly A lnAin.LI C 34.0 Spider Plot (NAD 27) (Governmentalyy��L.7�� Sections) k:' �� i:-._2 991-11.0GA028'055 € ` K1-L,6R46HL t.i-7, •..�` KU,-.24-GC SHL `.- e KBU 41 WRAP a a r, F0. . Krill 05 BHL e • ~ 0 0. i t !' r 1 # - KDU 011 IKL.,z1-S,EHL b ♦ S r i t 1 KBU 22-36&IL• it i j� KBU 42-0X BHIe 'I KBU 42-06Y BHL *x t ! K&u s2-6 OHL* t i V. I KBU 12-5 BHL► KBU 21-21 42-00Bkli�-„ KJ �-06 BHti I ,.. `- KU 6?-O6RO 8HL' o 43- XR1 Bill_ ., . . KI43-00X E+#. r'.--0 { E _ r KEJI 33-Do B,HLO, - KBU 42-06' TPHI ri KS4�33.oCx eri a ``' KU.S3•4114:BM1L! .�_.,�._ ! I KKU 2j-CCH BHL 1 l s•.. . KI UNIT FEE A028!4 ; KU 24-05 Bike I Kai 01 BHL. r ' I I 1 j� Y- ��• sooariafw ,, i �,' ,�, i, I '`' �_ .,..a t p{)s�jk<• L4 6h�lltr` KU 24-01RD SHL.0 I i KS°.r 2q-O8 �! *"'t E t �� j/�5 I -' a_,yam ' tS 1 I.l'y ,.A +i' .' / , � KU 2�.7X 8i ♦ ? • II KBU 42-06Y Drilling & Completion Procedure Hilt•orp Alnwkn.TIC 35.0 Surface Plat (As Built) (NAD 27) " ii__ KBU 42'06Y CDGLLSPAD t =� AS STAKED POSITION NAD 21 ASP ZONE 4 e ,: 1 \ NOR TI-I N:2361921.54 v E:274906.25' LAT:60'2T 33.359'N ION_151'14'49.304'W FEL: 10408"FNL:92' ELEV_66.4' . . .r ttt ?aEti0.0x ii, Ia .itx 11 ® i s r.i A1x <s e I SECTION LINE 6 5 Ii 1 r,5 I, 7,3 KOU :=., "...I"'� 97 FNL • a • ® S ® ! N 2361999.63 Iit A.',It 47 a.[.L E 275939 61 1006 FEL(NTS) b.u.<, • r 1.3 !I r---F.' 1 1 . - ji . ‘ f _ w J R.1! 41 EX* 4 d K.B..I 4i-7k U rn K•,r , O• KD/ ii a ® i F.., SECTION 7,T4N„ R11W.S.M.,AK o 't:,4.1. Z LI J W -_. »:a a7 r G�LUTIrwr"sv�Mt ON• in KENAI GAS r3 Of FIELD 'e" c` PAD 41-Tut r.T.14,111Pl • r. • 1,p_ r, 1 aria 1ATh62O4TAtGo_rainL41E£APE KDU 10 .7-74'' • I y ALASKA MATE PLANE 11K277 LORD 4 '�. ,�;��,�+r,''•"`��ly- trtERlANEpfn.A1 EGTTr'.T7ucrAcs1Rt As Staked 14*-;t;+°1rata»: ,_.�5'''lf dl9Nsl,�.�: STA AUCCY N4V$C.A PUBUBHEC1 POBirr.N Of LAT.etrursG55f NLC:N0.t61'16'.0 446'W O ♦ACM A.W6/41%/�` N l7R:nan 47 r OtAM1415 4RST- 4{ 2i RAZA;CR uEIrrICAL WIN IS RcA J EA r� f.— Lugs. ,/1 �aaa.►'P: 1. 31 N?P.16tEAST MAZER SEC.7 COOROINtE 1 I I I I%6.06, ECTEnrafgilIRO*LYItrCT SLIM,iC to iter TO EVISTMG Etu wr,FOR Nw f..Da2ER sEG 7 SCALE AND rnC Y.CORKER SECTORS 6 6 7 REGCx£IRE6 I AND ROT TM PpQ1pALTCD srr cra CC:Merl : T.4 ::.0 ti \\, I I • jEET 7 NILCOf2P ALASKA LLC i�muliing Inc KBU 42 06Y AS STAKED ,:v,.,,, , ti,i: I KENAI GAS FIELD PAD 41-7 ,at. •w \ 1 SURFACE LOCATION DIAGRAM NAD27 * rG »• 'f,of. G3W.ilKifawi I4Altwi,iiNvi TL,ti.Ti,ihaY n,Xe4 r.) 4... PO iiP144i 9CLDDOP APC tiiH IIIILTI',d, rte- U M*9-5 ITilrarp Ah.ika.LL* S7 T4N R I 1W SEWARD MERIDIAN,ALASKA 1 . 1 Page 60 Revision 0 Jun, 2014 II KBU 42-06Y Drilling & Completion Procedure Hilmrp Alwikn,LLC 36.0 Offset MW vs TVD Chart MW vs ND Offsets 0 1000 ' —KBU 11-17X(2009) — .a —KU 11-17(1982) 2000 1� — KBU 14.08(GD-1 2008) 3000 I —KBU 13-08(1977) — 4 I KU41-18(KUH1) I — —41-18X GD-1 4000 � � I ( 2008) — ' \i i —KBU 24-7X(2006)f 5000 o { 6 ( `f, 2- 6000 'di . i .1:5. ' 7000 3! I 0 8000 9000 10000 11000 12000 . 13000 7L7 1151e, 14000 �-- '1 15000 16000 8 4 10 11 12 13 14 15 Mud Weight(PPG) Page 61 Revision 0 Jun, 2014 111 KBU 42-06Y Drilling & Completion Procedure mlro,P.\i:,.ka.1,I.0 37.0 Drill Pipe Information SIzE: 4 1/2" gs„ WEIGHT: 16.6 Les/Fr co r�M U GRADE: S-135 RANGE: 11(31.5') DRILL PIPE SPECS CONNECTION: CDS4O TUBE NEW PREMIUM IN MM IN MM OD' 4,500 1 14.3 4.365 1 10.9 WALL THICKNESS 1 0.337 8.6 0.270 6.8 IDI 3.826 97-2 3.826 97.2 FI LBS NqM FT-Les IsHvi TORSIONAL STRENGTH 55.453 75.200 43.451 58.900 80%TORSIONAL STRENGTH 44,362 60.200 34.761 47.100 LBS DAN LBS DAN TENSILE STRENGTH 595.004 265.300 468,297 208.800 PSI KPA PSI KPA INTERNAL PRESSURE CAPACITY 17,693 121.985 16,176 1 1 1,530 COLLAPSE CAPACITY 16.769 1 15.6 15 10.959 75.561 IN2 MM2 1N2- MM2 CROSS SECTIONAL AREA BODY 4,407 2844 3.469 2238 CROSS SECTIONAL AREA OD/ 15.904 10261 14,966 9655 CROSS SECTIONAL AREA ID 11.497 7417 11.497 7417 IN2 MM2 IN2 MM2 SECTION MODULUSS4 4.271 69995 3.347 54845 POLAR SECTION MO Nil I!S 8.543 139989 6.694 109690 TOOL JOINT NEW I PREMIUM I PSI KPA PSI KPA YIELD STRENGTH:, 130,000 896.318 1 30,000 896,318 IN MM IN MM OD' 5.2500 133.4 5.1198 130.0 ID 2.6875 68.3 2.6875 68.3 PIN LENGTH 1 1,0 279.4 1 1.0 279.4 BOX LENGTH 14,0 355.6 14.0 355.6 Friss N•M Fr41.E35 N. M TORSIONAL STRENGTH35,400 48.000 34,700 47.100 MAX MAKEUP TORQUE 22.500 30.500 21.400 29.000 RECOMMENDED MAKEUP TOROUS( 21.200 28.800 20.800 28.200 MIN MAKE-UP TORQUEI 19,600 26.600 19.300 26.200 I LBS DAN LBS DAN TENSILE STRENGTI4I 824,400 367.600 804,900 358,900 TOOL JOINT/DRILL PIPE TORSIONAL RATIO: 0.64 0.80 . s .. a .n DRILL PIPE ASSEMBLY WITH CONNECTION LBS/FT KG/M ADJUSTED WEIGHT 17.87 26.64 Fr M APPROXIMATE LENGTH 31.50 9.60 GAL/FT M2/M FLUID DISPLACEMENT 0,273 0.003394 FLUID CAPACITY 0.577 0.007169 IN MM DRIFT SIZE 2.5625 65 Page 62 Revision 0 Jun, 2014 II KBU 42-06Y Drilling & Completion Procedure IIileorp AInAn,LLC COMBINED LOAD CURVE FOR 4 1/2"S-135 16.6 LBS/FT DRILL PIPE WITH CDS4O CONNECTIONS 4r•:I,11:0 '8 CO. 1 I . a 1 600000 20a 1 3S I F 400,000 an• •ty• % 300,000 '1 0• \ • •• F • 200.000 / I • • P • • 100,000 //9 • • s 11. ft 0 10.000 20,000 30.000 40,000 50,000 G0.0nI; Applied Torqueift-16x) —m NEW TCRF COMBINED L040 ••••PREMI1,M TL:RF COMBINED LOAD —MAKE-UP TORQUE -••••••..SHOULDER SERERATION ---PIN YIELD ^•••••••Box YIELD Page 63 Revision 0 Jun, 2014 s Hilcorp Energy Company Kenai Gas Field KGF 41-7 Pad I Plan: KBU 42-06Y h KBU 42-06Y 11 Plan: KBU 42-06Y wp1.0 Standard Proposal Report 30 May, 2014 rn HALLIBURTON Sperry Drilling Services - 0 _0 M 0 OG _- O N M N kn 9 CV 0C - N r� —o _ N N a o u. ON In w 00 Ln Nr o 5 N /5 _ N O N/t n VD _o O r!,1 I O N d e r7 Pa 'IF u-' v Nrt C IIIIIIII'llIlliIllIlIllt M M O 7 ti a 48>.. V s K- C9�°p 3 Ge5 - v, `�Ym'. 3 .17. a cY`o M - o YY4 ..v - . '3�Y -oinx ' a OC `^ - o —o cn r W - M • + —O x -' N _ 0 - o -- 0 o_ N - O 0 -7 LN11° O 3 CI - MN • NM I. —en Q - NMIE. 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 l I l l l l l I l l l l I l l l l 111( o0 0 00 0Tr 00 0 00 0 00 0 0 0 M M N N N ,�- O^ r M M I 03 (uiisn 00L)(+)poN/(-)iPnos HALLIBURTON IAZIE liP Sperry Drifting 6 o- Li 16" SECTION DETAILS Start Dir 2°/100' :500'MD, 500'TVD Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target - _-- 1 18.10 0.00 0.00 18.10 0.00 0.00 0.00 0.00 0.00 600- 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 3 1730.99 24.62 16.25 1693.45 250.03 72.87 2.00 16.25 260.43 - - 4 8725.77 24.62 16.25 8052.36 3047.62 888.21 0.00 0.00 3174.42 5 9546.43 0.00 16.25 8848.00 3214.31 936.79 3.00 180.00 3348.04 6 10448.43 0.00 16.25 9750.00 3214.31 936.79 0.00 0.00 3348.04 KBU 42-06Y BHL 1200- ,.. 10 3/4" - End Dir : 1730.99'MD, 1693.45 TVD 1800- -- WELL DETAILS: Plan:KBU 42-06Y Ground Level: 66.40 +N/-S +E/-W Northing Easting Latittude Longitude Slot 2400- 0.00 0.00 2361915.54 274907.86 60.4592504 -151.2469860 SURVEY PROGRAM 3000- Date:2014-05-30T00:00:00 Validated:Yes Version: Depth From Depth To Survey/Plan Tool Sterling 18.10 1500.00 KBU 42-06Y wp1.0(KBU 42-06Y) MWD+SC+sag 1500.00 6118.00 KBU 42-06Y wp1.0(KBU 42-06Y) MWD+SC+sag 3600-- - 6118.00 10448.43 KBU 42-06Y wp1.0(KBU 42-06Y) MWD+SC+sag - CASING DETAILS - Sterling 5.2_- 4200- - - - - - - - TVD MD Name Size - _ 130.00 130.00 16" 16 c - Upper Beluga 1479.82 1500.00 10 3/4" 10-3/4 _, _ - _ _ _ _ _ _ 5681.66 6118.00 7 5/8" 7-5/8 4800- 9729.33 10427.76 5" 5 o - N _ - Hilcorp Energy Company Middle Beluga --c..... - - - - - - - - - - - _ I Calculation Method: Minimum Curvature 5400- I Error System: ISCWSA ap 7 5/8" Scan Method: Closest Approach 3D O _ Error Surface: Elliptical Conic TtS - Waming Method: Error Ratio 0_ - f 6000- ) _- - - - Lower Beluga REFERENCE INFORMATION m _ E Co-ordinate(N/E)Reference: Well Plan:KBU 42-06Y,True North I- 6600 Vertical(TVD)Reference: KBU 42-06Y:Prelim @ 84.50usft(147) . Measured Depth Reference: KBU 42-06Y:Prelim©84.50usft(147) . Calculation Method: Minimum Curvature Upper Tyonek 7200- - - - - - - - - - - - - - - - - - - - Start Dir 3°/100':8725.77'MD,8052.36'TVD Project: Kenai Gas Field - Site: KGF 41-7 Pad 7800- - Well: Plan:KBU 42-06Y Wellbore: KBU 42-06Y KBU 42-06Y wp1.0 8400- Tyonek D1 End Dir :9546.43'MD,8848'TVD - - - - - - - - - - - - - - - - - Tyonek D2= 9000- - - _ _ - _ _ - _ Tyonek D3__ FORMATION TOP DETAILS - - - - - - - - - - - - _ TvOnek DzL_ TVDPath MDPath Formation _ _ _ _ _ _ _ _ _ _ _ _ _ _ = Tyonek D5 --- 3589.50 3816.63 Sterling y I4191.50 4478.83 Sterling5.2 9600- Tyonek D6 d ,5" 4698.50 5036.53 Upper Beluga _--� \ 5377.50 5783.43 Middle Beluga KBU 42-06Y BHL 6107.50 6586.43 Lower Beluga \ 7186.50 7773.33 Upper Tyonek 10200- \ 8765.50 9463.91 Tyonek D1 - \ 8848.50 9546.93 Tyonek D2 - 9109.50 9807.93 Tyonek D3 KBU 42-06Y wp1.0 \ 9314.50 10012.93 Tyonek D4 - `\ / 9438.50 10136.93 Tyonek D5 10800- 9491.50 10189.93 Tyonek D6 - Total Depth: 10448.43'MD,9750'TVD 11400- I I I I I l i i i i i I I I I I I I I I I I I I I I i I F F I I I I I I I I I F F F F F I I I -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 Vertical Section at 16.25°(1200 usft/in) HALLI B U RTON -PR Kenai Gas Field � Site: KGF 41-7 Par' rF �a Well: Plan:KBU4: Wellbore: KBU 42-0, Sperry Drilling KBU 42-osrwPl.o SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target 1 18.10 0.00 0.00 18.10 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 - 3 1730.99 24.62 16.25 1693.45 250.03 72.87 2.00 16.25 260.43 - 4 8725.77 24.62 16.25 8052.36 3047.62 888.21 0.00 0.00 3174.42 -3750 5 9546.43 0.00 16.25 8848.00 3214.31 936.79 3.00 180.00 3348.04 6 10448.43 0.00 16.25 9750.00 3214.31 936.79 0.00 0.00 3348.04 KBU 42-06Y BHL _ KBU 42-06Y wp 1.0 KBU 42-06Y BHL -3500 V - COMPANY DETAILS: Hilcorp Energy Company Total Depth: 10448.43'MD,9750'TVDVI/ 5" -3250 Calculation Method: Minimum Curvature -- Error System:ISCWSA --' Scan Method: Closest Approach 3D _..-- - En-or Surface: Elliptical Conic - Waming Method: Error Ratio End Dir :9546.43'MD,8848'TVD -3000 REFERENCE INFORMATION -2750 Co-ordinate(N/E)Reference: Well Plan:KBU 42-06Y,True North Start Dir 3°/100':8725.77'MD,8052.36'TVD Vertical(TVD)Reference: KBU 42-06Y:Prelim @ 84.50usft(147) - Measured Depth Reference: KBU 42-06Y:Prelim @ 84.50usft(147) - Calculation Method: Minimum Curvature -2500 WELL DETAILS: Plan:KBU 42-06Y Ground Level: 66.40 -2250 +N/-S +EI-W Northing Easting Latittude Longitude Slot - .00 0.00 2361915.54 274907.86 60.4592504 -151.2469860 - cn 7 5/8" - = SURVEY PROGRAM Yt" -2000 Date:2014-05-30T00:00:00 Validated:Yes Version: - Depth From Depth To Survey/Plan Tool - S 18.10 1500.00 KBU 42-06Y wp1.0(KBU 42-06Y) MWD+SC+sag -1750 1500.00 6118.00 KBU 42-06Y wp1.0(KBU 42-06Y) MWD+SC+sag 6118.00 10448.43 KBU 42-06Y wp1.0(KBU 42-06Y) MWD+SC+sag c - N -1500 CASING DETAILS - TVD MD Name Size -1250 130.00 130.00 16" 16 - 1479.82 1500.00 10 3/4" 10-3/4 - 5681.66 6118.00 7 5/8" 7-5/8 9729.33 10427.76 5" 5 -1000 -750 End Dir : 1730.99'MD,1693.45'TVD -500 -250 Start Dir 2°/100':500'MD,500'TVD - 10 3/4" 16" - _0 --250 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 - -2250 -2000 -1750 -1500 -1250 -1000 -750 -500 -250 0 250 500 750 1000 1250 West(-)/East(+)(500 usft/in) Halliburton HALL.IBUR I Di Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 42-06Y Company: Hilcorp Energy Company TVD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Project: Kenai Gas Field MD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) • Site: KGF 41-7 Pad North Reference: True ` Well: Plan:KBU 42-06Y Survey Calculation Method: Minimum Curvature , Wellbore: KBU 42-06Y Design: KBU 42-06Y wp1.0 Project Kenai Gas Field Map System: US State Plane 1927(Exact solution) . System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) • Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site KGF 41-7 Pad Site Position: Northing: 2,361,462.42 usft Latitude: 60.4580082 From: Lat/Long Easting: 274,852.80 usft Longitude: -151.2472434 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.09° Well Plan:KBU 42-06Y Well Position +N/-S 0.00 usft Northing: 2,361,915.54 usft ` Latitude: 60.4592504 +El-W 0.00 usft Easting: 274,907.86 usft • Longitude: -151.2469860 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: . 66.40 usft Wellbore KBU 42-06Y Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2013 5/30/2014 16.88 73.45 55,375 Design KBU 42-06Y wp1.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 18.10 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (°) 18.10 0.00 0.00 16.25 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°1100usft) (°/100usft) (°) 18.10 0.00 0.00 18.10 -66.40 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 415.50 0.00 0.00 0.00 0.00 0.00 0.00 1,730.99 24.62 16.25 1,693.45 1,608.95 250.03 72.87 2.00 2.00 0.00 16.25 8,725.77 24.62 16.25 8,052.36 7,967.86 3,047.62 888.21 0.00 0.00 0.00 0.00 9,546.43 0.00 16.25 8,848.00 8,763.50 3,214.31 936.79 3.00 -3.00 0.00 180.00 10,448.43 0.00 16.25 9,750.00 9,665.50 3,214.31 936.79 0.00 0.00 0.00 0.00 5/30/2014 1:49:50PM Page 2 COMPASS 5000.1 Build 70 Halliburton HALLI B U R I D Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 42-06Y Company: Hilcorp Energy Company TVD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Project: Kenai Gas Field MD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Site: KGF 41-7 Pad North Reference: True Well: Plan:KBU 42-06Y Survey Calculation Method: Minimum Curvature Wellbore: KBU 42-06Y Design: KBU 42-06Y wp1.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -66.40 18.10 0.00 0.00 18.10 -66.40 0.00 0.00 2,361,915.54 274,907.86 0.00 0.00 100.00 0.00 0.00 100.00 15.50 0.00 0.00 2,361,915.54 274,907.86 0.00 0.00 130.00 0.00 0.00 130.00 45.50 0.00 0.00 2,361,915.54 274,907.86 0.00 0.00 16" 200.00 0.00 0.00 200.00 115.50 0.00 0.00 2,361,915.54 274,907.86 0.00 0.00 300.00 0.00 0.00 300.00 215.50 0.00 0.00 2,361,915.54 274,907.86 0.00 0.00 400.00 0.00 0.00 400.00 315.50 0.00 0.00 2,361,915.54 274,907.86 0.00 0.00 500.00 0.00 0.00 500.00 415.50 0.00 0.00 2,361,915.54 274,907.86 0.00 0.00 Start Dir 2°/100':500'MD,500'TVD 600.00 2.00 16.25 599.98 515.48 1.68 0.49 2,361,917.21 274,908.38 2.00 1.75 700.00 4.00 16.25 699.84 615.34 6.70 1.95 2,361,922.20 274,909.94 2.00 6.98 800.00 6.00 16.25 799.45 714.95 15.07 4.39 2,361,930.52 274,912.54 2.00 15.69 900.00 8.00 16.25 898.70 814.20 26.77 7.80 2,361,942.15 274,916.17 2.00 27.88 1,000.00 10.00 16.25 997.47 912.97 41.78 12.18 2,361,957.08 274,920.83 2.00 43.52 1,100.00 12.00 16.25 1,095.62 1,011.12 60.10 17.52 2,361,975.30 274,926.51 2.00 62.60 1,200.00 14.00 16.25 1,193.06 1,108.56 81.70 23.81 2,361,996.77 274,933.21 2.00 85.10 1,300.00 16.00 16.25 1,289.64 1,205.14 106.54 31.05 2,362,021.47 274,940.92 2.00 110.98 1,400.00 18.00 16.25 1,385.27 1,300.77 134.61 39.23 2,362,049.38 274,949.63 2.00 140.21 1,500.00 20.00 16.25 1,479.82 1,395.32 165.87 48.34 2,362,080.46 274,959.33 2.00 172.77 10 3/4" 1,600.00 22.00 16.25 1,573.17 1,488.67 200.27 58.37 2,362,114.66 274,970.01 2.00 208.60 1,700.00 24.00 16.25 1,665.21 1,580.71 237.78 69.30 2,362,151.96 274,981.65 2.00 247.67 1,730.99 24.62 16.25 1,693.46 1,608.96 250.03 72.87 2,362,164.13 274,985.45 2.00 260.43 End Dir :1730.99'MD,1693.45'TVD 1,800.00 24.62 16.25 1,756.19 1,671.69 277.63 80.91 2,362,191.58 274,994.01 0.00 289.18 1,900.00 24.62 16.25 1,847.10 1,762.60 317.63 92.57 2,362,231.34 275,006.42 0.00 330.84 2,000.00 24.62 16.25 1,938.01 1,853.51 357.62 104.23 2,362,271.11 275,018.83 0.00 372.50 2,100.00 24.62 16.25 2,028.92 1,944.42 397.62 115.88 2,362,310.87 275,031.25 0.00 414.16 2,200.00 24.62 16.25 2,119.83 2,035.33 437.61 127.54 2,362,350.64 275,043.66 0.00 455.82 2,300.00 24.62 16.25 2,210.74 2,126.24 477.61 139.20 2,362,390.41 275,056.07 0.00 497.48 2,400.00 24.62 16.25 2,301.65 2,217.15 517.60 150.85 2,362,430.17 275,068.48 0.00 539.14 2,500.00 24.62 16.25 2,392.56 2,308.06 557.60 162.51 2,362,469.94 275,080.89 0.00 580.80 2,600.00 24.62 16.25 2,483.47 2,398.97 597.59 174.16 2,362,509.70 275,093.30 0.00 622.46 2,700.00 24.62 16.25 2,574.38 2,489.88 637.59 185.82 2,362,549.47 275,105.71 0.00 664.12 2,800.00 24.62 16.25 2,665.29 2,580.79 677.58 197.48 2,362,589.24 275,118.12 0.00 705.77 2,900.00 24.62 16.25 2,756.20 2,671.70 717.58 209.13 2,362,629.00 275,130.53 0.00 747.43 3,000.00 24.62 16.25 2,847.10 2,762.60 757.58 220.79 2,362,668.77 275,142.95 0.00 789.09 3,100.00 24.62 16.25 2,938.01 2,853.51 797.57 232.45 2,362,708.53 275,155.36 0.00 830.75 3,200.00 24.62 16.25 3,028.92 2,944.42 837.57 244.10 2,362,748.30 275,167.77 0.00 872.41 3,300.00 24.62 16.25 3,119.83 3,035.33 877.56 255.76 2,362,788.06 275,180.18 0.00 914.07 3,400.00 24.62 16.25 3,210.74 3,126.24 917.56 267.42 2,362,827.83 275,192.59 0.00 955.73 3,500.00 24.62 16.25 3,301.65 3,217.15 957.55 279.07 2,362,867.60 275,205.00 0.00 997.39 3,600.00 24.62 16.25 3,392.56 3,308.06 997.55 290.73 2,362,907.36 275,217.41 0.00 1,039.05 3,700.00 24.62 16.25 3,483.47 3,398.97 1,037.54 302.38 2,362,947.13 275,229.82 0.00 1,080.71 3,800.00 24.62 16.25 3,574.38 3,489.88 1,077.54 314.04 2,362,986.89 275,242.23 0.00 1,122.37 5/30/2014 1:49:50PM Page 3 COMPASS 5000.1 Build 70 Halliburton HALL.IBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 42-06Y Company: Hilcorp Energy Company TVD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Project: Kenai Gas Field MD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Site: KGF 41-7 Pad North Reference: True Well: Plan:KBU 42-06Y Survey Calculation Method: Minimum Curvature Wellbore: KBU 42-06Y Design: KBU 42-06Y wp1.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,505.00 3,816.63 24.62 16.25 3,589.50 3,505.00 1,084.19 315.98 2,362,993.51 275,244.30 0.00 1,129.30 Sterling 3,900.00 24.62 16.25 3,665.29 3,580.79 1,117.53 325.70 2,363,026.66 275,254.64 0.00 1,164.03 4,000.00 24.62 16.25 3,756.20 3,671.70 1,157.53 337.35 2,363,066.43 275,267.06 0.00 1,205.69 4,100.00 24.62 16.25 3,847.11 3,762.61 1,197.53 349.01 2,363,106.19 275,279.47 0.00 1,247.35 4,200.00 24.62 16.25 3,938.02 3,853.52 1,237.52 360.67 2,363,145.96 275,291.88 0.00 1,289.01 4,300.00 24.62 16.25 4,028.92 3,944.42 1,277.52 372.32 2,363,185.72 275,304.29 0.00 1,330.67 4,400.00 24.62 16.25 4,119.83 4,035.33 1,317.51 383.98 2,363,225.49 275,316.70 0.00 1,372.33 4,478.83 24.62 16.25 4,191.50 4,107.00 1,349.04 393.17 2,363,256.84 275,326.48 0.00 1,405.17 Sterling 5.2 4,500.00 24.62 16.25 4,210.74 4,126.24 1,357.51 395.64 2,363,265.26 275,329.11 0.00 1,413.98 4,600.00 24.62 16.25 4,301.65 4,217.15 1,397.50 407.29 2,363,305.02 275,341.52 0.00 1,455.64 4,700.00 24.62 16.25 4,392.56 4,308.06 1,437.50 418.95 2,363,344.79 275,353.93 0.00 1,497.30 4,800.00 24.62 16.25 4,483.47 4,398.97 1,477.49 430.60 2,363,384.55 275,366.34 0.00 1,538.96 4,900.00 24.62 16.25 4,574.38 4,489.88 1,517.49 442.26 2,363,424.32 275,378.76 0.00 1,580.62 5,000.00 24.62 16.25 4,665.29 4,580.79 1,557.48 453.92 2,363,464.08 275,391.17 0.00 1,622.28 5,036.53 24.62 16.25 4,698.50 4,614.00 1,572.10 458.18 2,363,478.61 275,395.70 0.00 1,637.50 Upper Beluga 5,100.00 24.62 16.25 4,756.20 4,671.70 1,597.48 465.57 2,363,503.85 275,403.58 0.00 1,663.94 5,200.00 24.62 16.25 4,847.11 4,762.61 1,637.48 477.23 2,363,543.62 275,415.99 0.00 1,705.60 5,300.00 24.62 16.25 4,938.02 4,853.52 1,677.47 488.89 2,363,583.38 275,428.40 0.00 1,747.26 5,400.00 24.62 16.25 5,028.93 4,944.43 1,717.47 500.54 2,363,623.15 275,440.81 0.00 1,788.92 5,500.00 24.62 16.25 5,119.84 5,035.34 1,757.46 512.20 2,363,662.91 275,453.22 0.00 1,830.58 5,600.00 24.62 16.25 5,210.75 5,126.25 1,797.46 523.86 2,363,702.68 275,465.63 0.00 1,872.24 5,700.00 24.62 16.25 5,301.65 5,217.15 1,837.45 535.51 2,363,742.45 275,478.04 0.00 1,913.90 5,783.43 24.62 16.25 5,377.50 5,293.00 1,870.82 545.24 2,363,775.62 275,488.40 0.00 1,948.65 Middle Beluga 5,800.00 24.62 16.25 5,392.56 5,308.06 1,877.45 547.17 2,363,782.21 275,490.46 0.00 1,955.56 5,900.00 24.62 16.25 5,483.47 5,398.97 1,917.44 558.83 2,363,821.98 275,502.87 0.00 1,997.22 6,000.00 24.62 16.25 5,574.38 5,489.88 1,957.44 570.48 2,363,861.74 275,515.28 0.00 2,038.88 6,100.00 24.62 16.25 5,665.29 5,580.79 1,997.43 582.14 2,363,901.51 275,527.69 0.00 2,080.54 6,118.00 24.62 16.25 5,681.66 5,597.16 2,004.63 584.24 2,363,908.67 275,529.92 0.00 2,088.03 7 5/8" 6,200.00 24.62 16.25 5,756.20 5,671.70 2,037.43 593.79 2,363,941.27 275,540.10 0.00 2,122.19 6,300.00 24.62 16.25 5,847.11 5,762.61 2,077.42 605.45 2,363,981.04 275,552.51 0.00 2,163.85 6,400.00 24.62 16.25 5,938.02 5,853.52 2,117.42 617.11 2,364,020.81 275,564.92 0.00 2,205.51 6,500.00 24.62 16.25 6,028.93 5,944.43 2,157.42 628.76 2,364,060.57 275,577.33 0.00 2,247.17 6,586.43 24.62 16.25 6,107.50 6,023.00 2,191.98 638.84 2,364,094.94 275,588.06 0.00 2,283.18 Lower Beluga 6,600.00 24.62 16.25 6,119.84 6,035.34 2,197.41 640.42 2,364,100.34 275,589.74 0.00 2,288.83 6,700.00 24.62 16.25 6,210.75 6,126.25 2,237.41 652.08 2,364,140.10 275,602.15 0.00 2,330.49 6,800.00 24.62 16.25 6,301.66 6,217.16 2,277.40 663.73 2,364,179.87 275,614.57 0.00 2,372.15 6,900.00 24.62 16.25 6,392.57 6,308.07 2,317.40 675.39 2,364,219.64 275,626.98 0.00 2,413.81 7,000.00 24.62 16.25 6,483.47 6,398.97 2,357.39 687.05 2,364,259.40 275,639.39 0.00 2,455.47 7,100.00 24.62 16.25 6,574.38 6,489.88 2,397.39 698.70 2,364,299.17 275,651.80 0.00 2,497.13 5/30/2014 1:49:50PM Page 4 COMPASS 5000.1 Build 70 Halliburton H A L L I B U R T O I V Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 42-06Y Company: Hilcorp Energy Company TVD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Project: Kenai Gas Field MD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Site: KGF 41-7 Pad North Reference: True Well: Plan:KBU 42-06Y Survey Calculation Method: Minimum Curvature Wellbore: KBU 42-06Y Design: KBU 42-06Y wp1.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,580.79 7,200.00 24.62 16.25 6,665.29 6,580.79 2,437.38 710.36 2,364,338.93 275,664.21 0.00 2,538.79 7,300.00 24.62 16.25 6,756.20 6,671.70 2,477.38 722.01 2,364,378.70 275,676.62 0.00 2,580.45 7,400.00 24.62 16.25 6,847.11 6,762.61 2,517.37 733.67 2,364,418.47 275,689.03 0.00 2,622.11 7,500.00 24.62 16.25 6,938.02 6,853.52 2,557.37 745.33 2,364,458.23 275,701.44 0.00 2,663.77 7,600.00 24.62 16.25 7,028.93 6,944.43 2,597.37 756.98 2,364,498.00 275,713.85 0.00 2,705.43 7,700.00 24.62 16.25 7,119.84 7,035.34 2,637.36 768.64 2,364,537.76 275,726.27 0.00 2,747.09 7,773.33 24.62 16.25 7,186.50 7,102.00 2,666.69 777.19 2,364,566.92 275,735.37 0.00 2,777.63 Upper Tyonek 7,800.00 24.62 16.25 7,210.75 7,126.25 2,677.36 780.30 2,364,577.53 275,738.68 0.00 2,788.75 7,900.00 24.62 16.25 7,301.66 7,217.16 2,717.35 791.95 2,364,617.29 275,751.09 0.00 2,830.40 8,000.00 24.62 16.25 7,392.57 7,308.07 2,757.35 803.61 2,364,657.06 275,763.50 0.00 2,872.06 8,100.00 24.62 16.25 7,483.48 7,398.98 2,797.34 815.27 2,364,696.83 275,775.91 0.00 2,913.72 8,200.00 24.62 16.25 7,574.39 7,489.89 2,837.34 826.92 2,364,736.59 275,788.32 0.00 2,955.38 8,300.00 24.62 16.25 7,665.30 7,580.80 2,877.33 838.58 2,364,776.36 275,800.73 0.00 2,997.04 8,400.00 24.62 16.25 7,756.20 7,671.70 2,917.33 850.23 2,364,816.12 275,813.14 0.00 3,038.70 8,500.00 24.62 16.25 7,847.11 7,762.61 2,957.32 861.89 2,364,855.89 275,825.55 0.00 3,080.36 8,600.00 24.62 16.25 7,938.02 7,853.52 2,997.32 873.55 2,364,895.66 275,837.97 0.00 3,122.02 8,700.00 24.62 16.25 8,028.93 7,944.43 3,037.32 885.20 2,364,935.42 275,850.38 0.00 3,163.68 8,725.77 24.62 16.25 8,052.36 7,967.86 3,047.62 888.21 2,364,945.67 275,853.57 0.00 3,174.42 Start Dir 3°/100':8725.77'MD,8052.36'TVD 8,800.00 22.39 16.25 8,120.43 8,035.93 3,076.04 896.49 2,364,973.93 275,862.39 3.00 3,204.02 8,900.00 19.39 16.25 8,213.84 8,129.34 3,110.28 906.47 2,365,007.97 275,873.02 3.00 3,239.68 9,000.00 16.39 16.25 8,308.99 8,224.49 3,139.77 915.06 2,365,037.29 275,882.17 3.00 3,270.40 9,100.00 13.39 16.25 8,405.62 8,321.12 3,164.44 922.25 2,365,061.82 275,889.83 3.00 3,296.10 9,200.00 10.39 16.25 8,503.46 8,418.96 3,184.23 928.02 2,365,081.49 275,895.97 3.00 3,316.70 9,300.00 7.39 16.25 8,602.25 8,517.75 3,199.07 932.35 2,365,096.24 275,900.57 3.00 3,332.16 9,400.00 4.39 16.25 8,701.71 8,617.21 3,208.92 935.22 2,365,106.04 275,903.63 3.00 3,342.43 9,463.91 2.48 16.25 8,765.50 8,681.00 3,212.60 936.29 2,365,109.70 275,904.77 3.00 3,346.26 Tyonek D1 9,500.00 1.39 16.25 8,801.57 8,717.07 3,213.77 936.63 2,365,110.86 275,905.13 3.00 3,347.47 9,546.43 0.00 16.25 8,848.00 8,763.50 3,214.31 936.79 2,365,111.40 275,905.30 3.00 3,348.04 End Dir :9546.43'MD,8848'TVD 9,546.93 0.00 16.25 8,848.50 8,764.00 3,214.31 936.79 2,365,111.40 275,905.30 0.02 3,348.04 Tyonek D2 9,600.00 0.00 16.25 8,901.57 8,817.07 3,214.31 936.79 2,365,111.40 275,905.30 0.00 3,348.04 9,700.00 0.00 16.25 9,001.57 8,917.07 3,214.31 936.79 2,365,111.40 275,905.30 0.00 3,348.04 9,800.00 0.00 16.25 9,101.57 9,017.07 3,214.31 936.79 2,365,111.40 275,905.30 0.00 3,348.04 9,807.93 0.00 16.25 9,109.50 9,025.00 3,214.31 936.79 2,365,111.40 275,905.30 0.00 3,348.04 Tyonek D3 9,900.00 0.00 16.25 9,201.57 9,117.07 3,214.31 936.79 2,365,111.40 275,905.30 0.00 3,348.04 10,000.00 0.00 16.25 9,301.57 9,217.07 3,214.31 936.79 2,365,111.40 275,905.30 0.00 3,348.04 10,012.93 0.00 16.25 9,314.50 9,230.00 3,214.31 936.79 2,365,111.40 275,905.30 0.00 3,348.04 Tyonek D4 10,100.00 0.00 16.25 9,401.57 9,317.07 3,214.31 936.79 2,365,111.40 275,905.30 0.00 3,348.04 5/30/2014 1:49:50PM Page 5 COMPASS 5000.1 Build 70 u /� Halliburton H A LL I B RIDN Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 42-06Y Company: Hilcorp Energy Company TVD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Project: Kenai Gas Field MD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Site: KGF 41-7 Pad North Reference: True Well: Plan:KBU 42-06Y Survey Calculation Method: Minimum Curvature Wellbore: KBU 42-06Y Design: KBU 42-06Y wp1.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 9,354.00 10,136.93 0.00 16.25 9,438.50 9,354.00 3,214.31 936.79 2,365,111.40 275,905.30 0.00 3,348.04 Tyonek D5 10,189.93 0.00 16.25 9,491.50 9,407.00 3,214.31 936.79 2,365,111.40 275,905.30 0.00 3,348.04 Tyonek D6 10,200.00 0.00 16.25 9,501.57 9,417.07 3,214.31 936.79 2,365,111.40 275,905.30 0.00 3,348.04 10,300.00 0.00 16.25 9,601.57 9,517.07 3,214.31 936.79 2,365,111.40 275,905.30 0.00 3,348.04 10,400.00 0.00 16.25 9,701.57 9,617.07 3,214.31 936.79 2,365,111.40 275,905.30 0.00 3,348.04 10,427.76 0.00 16.25 9,729.33 9,644.83 3,214.31 936.79 2,365,111.40 275,905.30 0.00 3,348.04 5" / 10,448.43 • 0.00 16.25 9,750.00 . 9,665.50 3,214.31 936.79 2,365,111.40 I 275,905.30 1/ 0.00 3,348.04 Total Depth:10448.43'MD,9750'TVD Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (0) (0) (usft) (usft) (usft) (usft) (usft) KBU 42-06Y BHL 0.00 0.00 9,750.00 3,214.31 936.79 2,365,111.40 275,905.30 -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 130.00 130.00 16" 16 22 1,500.00 1,479.82 10 3/4" 10-3/4 13-1/2 6,118.00 5,681.66 75/8" 7-5/8 9-7/8 10,427.76 9,729.33 5" 5 6-3/4 5/30/2014 1:49:50PM Page 6 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:KBU 42-06Y Company: Hilcorp Energy Company TVD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Project: Kenai Gas Field MD Reference: KBU 42-06Y:Prelim @ 84.50usft(147) Site: KGF 41-7 Pad North Reference: True Well: Plan:KBU 42-06Y Survey Calculation Method: Minimum Curvature Wellbore: KBU 42-06Y Design: KBU 42-06Y wp1.0 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) NameLithology (°) (°) 3,816.63 3,589.50 Sterling 10,136.93 9,438.50 Tyonek D5 6,586.43 6,107.50 Lower Beluga 5,783.43 5,377.50 Middle Beluga 10,189.93 9,491.50 Tyonek D6 9,807.93 9,109.50 Tyonek D3 5,036.53 4,698.50 Upper Beluga 4,478.83 4,191.50 Sterling 5.2 7,773.33 7,186.50 Upper Tyonek 9,463.91 8,765.50 Tyonek D1 9,546.93 8,848.50 Tyonek D2 10,012.93 9,314.50 Tyonek D4 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +EI-W (usft) (usft) (usft) (usft) Comment 500.00 500.00 0.00 0.00 Start Dir 2°/100':500'MD,500'TVD 1,730.99 1,693.46 250.03 72.87 End Dir :1730.99'MD,1693.45'TVD 8,725.77 8,052.36 3,047.62 888.21 Start Dir 3°/100':8725.77'MD,8052.36'TVD 9,546.43 8,848.00 3,214.31 936.79 End Dir :9546.43'MD,8848'TVD 10,448.43 9,750.00 3,214.31 936.79 Total Depth:10448.43'MD,9750'TVD 5/30/2014 1.49:50PM Page 7 COMPASS 5000.1 Build 70 Z1 m D L N w CC rnn • C M O.1 J '' 4 L L m = a In Iln a n II1=1 N C O N O R C t. 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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: /c(e —( ' PTD: Development Service Exploratory —Stratigraphic Test _Non-Conventional 8L' (LZLL/0 I L 6-71,4:__ FIELD: 4-- POOL: �l 42 r C j t�ttg -=U C'c / 1 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 MC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Lo ,n also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 MC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 El El To N os 0 a) a N N 0 0 - O To c a 3 a.) .0 o L' coN: .0N. O N as O o O' c Cl) Z a) L 0 o W O a o_ D >, O (v o o °, E N O Z N O O ulN N - o 0 � a) o 12 a) -o oi : t 2 ao 0 c v •�: pp Ii W U c c O a) a >,, 52 - O N 0 '� v: 0 : o' -CI La 0 a) O c a) N o N .� )) 3' o a c LO ' > 0 3 w 3. N E `m N 'f3 • m -o v a> CO 0) >. a> < - : a) - C .0 •.O- - CO N 1]: a) N C , T U) } -O r- -o (I) ' O. 3' U) ... 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N 2 o_ 0. co,, cn, U W a E O N M V 10 c0 h CO 0) 0 N CO V )0 CO n CO 0) O N CO V LO CO h CO 0) N cn V r0 (o r` CO O) ,- ,- (V N N N N N N N N N (-0 CO COCO COCOCO CO CO CO I- _ O __-- _._. _(V _ __..._._. _I_. _ N O C G p C NCO _ CO \ m N V 0 O O CI ,- 0 N'71- O N i J N .- a) a) (9 O C) w o •E qc 0 •C) ' J -°o `°a- o 0 5. oIa a `a w a ( a `) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simpify 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. KBU 42-06Y Kenai Beluga Unit Kenai Borough, Alaska July 29, 2014 – August 17, 2014 Provided by: Approved by: Sarah Rittenhouse Compiled by: Ralph Winkelman Trey Thrailkill Distribution Date: October 3, 2014 KBU 42-06Y 2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................3 1.1 Equipment Summary ......................................................................................................................3 1.2 Crew................................................................................................................................................3 2 GENERAL WELL DETAILS...................................................................................................................4 2.1 Well Objectives...............................................................................................................................4 2.2 Hole Data........................................................................................................................................4 2.3 Daily Activity Summary...................................................................................................................5 3 GEOLOGICAL DATA.............................................................................................................................7 3.1 Lithostratigraphy .............................................................................................................................7 3.2 Lithology Details..............................................................................................................................8 3.3 Sampling Program........................................................................................................................15 4 DRILLING DATA..................................................................................................................................16 4.1 Surveys.........................................................................................................................................16 4.2 Bit Record.....................................................................................................................................21 4.3 Mud Record ..................................................................................................................................22 4.4 Drilling Progress Chart..................................................................................................................23 5 SHOW REPORTS ...............................................................................................................................24 6 DAILY REPORT...................................................................................................................................25 Enclosures 2” / 100’ Formation Log (MD/TVD) 5” / 100’ Formation Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) Final Data CD KBU 42-06Y 3 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Computers – Surface Logging (5) Rigwatch Server, Rigwatch Remote DML, LWD WITS, Rigwatch Remote 0 hours Ditch gas QGM gas trap; Flame ionization total gas & chromatography. Hook Load / Weight on bit WITS from Pason 0 hours Mud Flow In Derived from Strokes/Minute and Pump Output 0hours Mud Flow Out WITS from Pason 0hours Pit Volumes, Pit Gain/Loss WITS from Pason 0hours Pump Pressure WITS from Pason 0 hours Pump Stroke Counters (2) WITS from Pason 0 hours Rate of Penetration Calculated from Pason 0 hours RPM WITS from Pason 0 hours Torque WITS from Pason 0 hours WITS To/ From Pason Rigwatch Remote (HP Compaq) 0 hours 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML057 Logging Geologists Years1 Days2 Sample Catchers Years Days2 Technician Days2 Ralph Winkelman 23 21 Don Thibodeaux 30 10 Trey Thrailkill 2 24 Fred Spiers 2 10 Tollef Winslow 6 3 *1 Years experience as Mudlogger *2 Days at wellsite between rig up and rig down of logging unit. KBU 42-06Y 4 2 GENERAL WELL DETAILS 2.1 Well Objectives KBU 42-06Y is a 10,448’MD/ 9,750’TVD grassroots well that will target the Beluga/ Upper Tyonek development well off the 41-07 pad in the Kenai Gas Field. The base plan is an S shaped well bore with a shallow kick off and a 30 deg tangent before dropping back to vertical in the production zone. Operator: HILCORP ALASKA, LLC Well Name: KBU 42-06Y Field: Kenai Beluga Unit County: Kenai Borough State: Alaska Company Representatives: Mike Leslie, Doug Yessak, James Lott Location: Surface Coordinates 92' FNL, 1008' FEL, Sec 7, T4N, R11W, SM, AK Ground ( Pad ) Elevation 66.4’ Rotary Table Elevation 84.9’ Classification: Development - Gas API #: 50-133-20634-00-00 Permit #: 214-089 Rig Name/Type: Saxon 147/ Land/ Double Spud Date July 26, 2014 Total Depth Date: August 17, 2014 Total Depth 10895’ MD/ 10029.47’ TVD Primary Targets Tyonek D2, D3, D4, D5, D6 Primary Target Depths 9,929’, 10,148’, 10,415’, 10,507’, 10,647’ Total Depth Formation: Tyonek Completion Status: Run, Set and Cement 5” Liner to surface. LWD-MWD Services. Halliburton/ Sperry Drilling Services Directional Drilling Halliburton/ Sperry Drilling Services Wireline Logging Services No open hole logging Drilling Fluids Service M.I. Swaco 2.2 Hole Data Max Depth Shoe Depth Hole Section MD (ft) TVD (ft) TD Formation MW ppg Dev oinc Csg Dia MD (ft) TVD (ft) FIT ppg 13 ½” 1603’ 1577.4’ Sterling 9.0 20.68 10.75 1595’ 1569.9’ 12.0 9 7/8” 6493’ 5809.6’ Beluga 9.7 29.24 7 5/8 6481’ 5799.1’ 13.5 6 ¾” 10895 10084.43’ Tyonek 12.0 2.09 5” 10891’ 10025’ n/a KBU 42-06Y 5 2.3 Daily Activity Summary 7/29/2014: Canrig arrive on location and participate in field wide urinalysis. Begin rig up. Rig testing BOP with AOGCC rep witness test. 7/30/2014: Canrig finish rig up. Picked up BHA #2 and shallow tested it. RIH to 1508' and dilled cement/float equipment to 1603' with shoe at 1591' to 1594'. Drill 20' of rat hole and perform FIT; EMW of 12 ppg successful. Continue drilling from 1623'. 7/31/2014: Pumped sweep at 2500' and drilled to 2697'. Pulled out of hole to 1026' for wiper trip. P/U 50 single joints of drill pipe and TIH. Continue drilling ahead, sliding and rotating 8/1/2014: Pumped sweeps at 2949', 3175', 3450', 3690' and 3940'. Drilled to 4248' and pumped a high VIS sweep and POOH for short trip to shoe. Back reamed 3744-3733, 3427-3365, 3250-3185. Hole was tight at 3640-3572, 3486 and 3284. Performed rig service and RIH to 4200' and sweep with high VIS. Continue to drill ahead. 8/2/2014: Drilled to 5551', high gas of 1,096u. Pumped high vis sweep and began wiper trip. Hole was tight from 5235' to 2750', pumped out and back reamed through this section. POOH to casing shoe and performed rig service. 8/3/2014: Drilled to TD at 6493' and pumped high vis sweep. Circulated bottoms up and pumped final survey. Pulling out of hole for wiper trip. 8/4/2014: Back reamed to 2,750' and POOH on elevators to 715' 8/5/2014: Lay down BHA #2 and pick up #3 for clean out run to bottom. TIH to 1053' and cut 95' of drill line. RIH to 6240' and safely ream to 6493'. Pumped high vis sweep and circulated out. POOH on elevators to surface. 8/6/2014: Pick up casing and RIH, at shoe fill casing and circulate 1.5x hole volume. Run casing to 6492', tagged fill at 6473'. Lost returns at 5150' pumped at 5320 and could not establish return, 210 bbl total loss. Build LCM pill and prepare to pump pill. 8/7/2014: Treating loss circulation by building additional LCM pill. Watering back and reconditioning mud moved from storage to 9.1 ppg for upcoming cement job. 8/8/2014: Build LCM pill by transferring 12.1 from tank and condition to 9.1 ppg. Pumped 150 bbl of 100 ppb LCM followed by 70 bbls of 50 ppb and chased with 9.1 ppg mud when pill exited shoe. Regained circulation and built 25 bbl LCM pill @ 105 ppb. Slowly increased pump rate from 1.5 to 2 BPM. Circulate out LCM pill and cement. Pumped two 40 bbl seal spacers, 163 bbl of 10.5 ppg Lead followed by 29 bbl of 13.5 ppg Tail. While cementing, 111 bbl mud was lost to formation. 8/9/2014: Finish BOP testing and cement bond logging. Preparing to test casing to 3500 psi for 30 minutes. Kla Shield mud is being transferred back into the active system and treated for use on the next well interval. 8/10/2014: PJSM and M/U BHA and RIH. Shallow test BHA and continue RIH. Perform rig service. RIH till tagging cement @ 6389'. Drill out cement to 6493'. Slide from 6493' to 6513' and displace mud to 9.7ppg. FIT to 13.5ppg EMW, 1150 PSI chart recorded. Continue drilling from 6513' to 6671'. 8/11/2014: Continue drilling ahead to 7,450' pumping sweeps every 250'. KBU 42-06Y 6 8/12/2014: Conducted a wiper trip at 7722’ and then continued drilling and sliding. Pumped sweep at 7697’ 8/13/2014: Drilling ahead and sliding from 7891’ to 8493’. 8/14/2014: Drilled ahead from 8493’ continuing to slide occasionally. High cuttings gas and connection gases at 9032’, weighted up to 11 ppg. Continue to drill ahead while weighting up to 11.8, preparing for wiper trip. 8/15/2014: Circulated at 9522' while increasing mud to 11.8ppg and saw 2583 units of gas. CBU and begun POOH for scheduled wiper trip. POOH to 6483' and slipped/cut 73' of drill line. TIH to 9522' with no tight spots. Washed bottom from 9494' to 9522'. Saw 2233 units of wiper gas. Pumped high vis sweep and began drilling ahead. 8/16/2014: Drilled to 10,643' and POOH for a quick 5 stand wiper trip and singled in with 8 singles. Pumped a sweep on bottom and continued drilling. 8/17/2014: Drilled to TD at 10985' at 06:30. Pumped sweep and spotted LCM pill. Tripped out of hole to shoe and circulated bottoms up. 8/18/2014: CBU 290 gallons per minute with 2390 psi at casing shoe. Monitor well for swabbing and pumped dry job and dropped MUD DOG pipe wiper. Continue to TOOH and L/D drill pipe. TIH with remaining stands of pipe in derrick and monitored well, pumped a second dry job and continued pulling out of hole and laying down the remainder of the drill pipe. 8/19/2014: Cement, spacers and displacement fluid was 387 bbl. Lost 19 bbl to formation while cementing. 8/20/2014: Canrig Surface Logging released. KBU 42-06Y 7 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Prognosed and Observed tops provided by Hilcorp Geologist Jacob Dunston. PROGNOSED OBSERVED MD TVD SSTVD MD TVD SSTVD FORMATION (ft) (ft) (ft) (ft) (ft) (ft) Sterling 3,550 3,550 (3,464) 3,918 3,586 -3,501 Sterling 5.2 4,186 4,186 (4,100) 4,607 4,180 -4,095 Sterling Pool 6 4,400 4,400 (4,314) 4,909 4,440 -4,355 Upper Beluga 4,680 4,680 (4,594) 5,199 4,689 -4,604 Middle Beluga 5,290 5,290 (5,204) 5,279 5,276 -5,190 Lower Beluga 6,732 6,018 (5,933) 6,732 6,015 -5,930 Upper Tyonek 8,061 7,218 (7,133) 8,061 7,219 -7,134 D-1 Sand 9,648 8,773 (8,688) 9,648 8,785 -8,700 D-2 Sand 9,812 8,935 (8,850) 9,825 8,962 -8,877 D-3 Sand 10,046 9,165 (9,080) 10,023 9,159 -9,074 D-4 Sand 10,281 9,396 (9,311) 10,281 9,416 -9,331 D-5 Sand 10,339 9,453 (9,368) 10,344 9,480 -9,395 D-6 Sand 10,429 9,542 (9,457) 10,434 9,569 -9,484 KBU 42-06Y 8 3.2 Lithology Details Full service mudlogging began at 6493’ MD/ 5809.6’ TVD. All the sample lithology descriptions provided by Canrig began after intermediate casing point. The well includes Beluga and Tyonek formations whose lithology of largely volcanic ash-derived fluvial sediments includes: tuffaceous claystone, tuffaceous siltstone, sand/sandstone, volcanic ash, coal and various other minor to trace thinly bedded lithologies. The wellbore was drilled to 10895’ MD /10084.4’TVD. Tuffaceous Siltstone/ Unconsolidated Sand/ Tuffaceous Claystone (6520'-6600') = dark gray to medium bluish gray; soft to easily friable grading into firmly friable; very poor to moderate induration; pulverulent to malleable; texture varies from silty/clayey to gritty depending on amount of sand in sample; dull to earthy luster; greater amounts of grayish brown siltstone with dark, thickly bedded organic lithics seen in later samples; unconsolidated sand is primarily quartz grains ranging from lower coarse to lower medium in size; moderate to low sphericity; subangular; poorly sorted; unconsolidated; 80% or more quartz; moderate HCl reaction in samples containing mostly unconsolidated sand. Tuffaceous Claystone/ Siltstone/ Coal (6600'-6660') = dark gray to medium light gray; soft to friable; very poor to moderate induration; malleable to pulverulent; silty clayey texture; earthy luster; very cohesive; pasty to punky; siltstone becomes increasingly more carbonaceous until it becomes a low grade coal/highly carbonaceous material. Tuffaceous Claystone/ Siltstone/ Unconsolidated Sand (6660'-6760') = medium bluish gray to medium dark gray; soft to firmly friable; grades to unconsolidated in later samples; poor to moderate induration grades into non indurated; pulverulent to malleable; massive to wedgelike; silty clay texture in samples with low amount of unconsolidated sand; dull to earthy luster; displays cohesive qualities that grade into adhesive; pasty to mushy to gelatinous in later samples; some specimens display thin beds of dark carbonaceous material; unconsolidated sand is 80% quartz; upper fine to lower medium in grain size; low sphericity; subangular; poorly sorted; samples high in unconsolidated sand display a moderate reaction to HCl. Tuffaceous Claystone/ Siltstone/ Unconsolidated Sand (6760'-6840') = medium bluish gray to dark greenish gray; soft to firmly friable; moderate to very poor induration; pulverulent to crunchy; massive to wedgelike; silty clayey texture; earthy luster; displays both adhesive and cohesive quality; siltstone displays increasingly higher amounts of carbonaceous material starting with thinly bedded bands of dark black lithic and ending in a low grade coal or carbonaceous shale; moderate HCl reaction in samples with high levels of sand. Tuffaceous Siltstone/ Claystone/ Unconsolidated Sand (6840'-6920') = medium gray to medium light gray; soft to firmly friable; moderate to poorly indurated; pulverulent to dense and brittle; clayey silt texture in samples with low amounts of unconsolidated sand; dull to earthy luster; samples start off with thin, dark carbonaceous material interbedded and grades towards being more carbonaceous until low grade coal/carbonaceous shale appears at 6920'; no HCl reaction. Sand (6920' - 6980') = medium to medium light gray with a moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, black and trace dark greenish gray; very fine upper to coarse lower, dominantly fine upper to medium lower; angular to subangular; poor to fair sorting; unconsolidated; non calcareous; present in minor amounts as suspended grains in a dominantly claystone/ siltstone formation. Tuffaceous Claystone (6980' - 7040') = medium light to light gray with light brown and light brownish gray secondary hues; very soft and very sticky; shapeless, irregular with trace PDC bit action "scooped" appearance; silty to clayey texture; dull to earthy luster; very soluble and expansive; hydrophilic; poor cohesiveness; good adhesiveness; non calcareous; rare trace dark brown to black microthin carbonaceous laminations and inclusions. KBU 42-06Y 9 Tuffaceous Claystone/ Tuffaceous Siltstone (7040' - 7100') = medium light to light gray with very light brownish gray secondary hues; soft; sticky; mushy; irregular, shapeless cuttings; clayey to silty texture; dull to greasy luster; hydrophilic; very soluble and expansive; poor cohesiveness; very good adhesiveness; non calcareous; rare trace dark brown to black microthin carbonaceous laminations and inclusions. Tuffaceous Claystone (7100' - 7160') = medium light to light gray with light brown and light brownish gray secondary hues; very soft and very sticky; shapeless, irregular cuttings; silty to clayey texture; dull to earthy luster; very soluble and expansive; hydrophilic; poor cohesiveness; good adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace thin coal/ carbonaceous shale beds. Tuffaceous Claystone/ Tuffaceous Siltstone (7160' - 7230') = medium light to light gray with very light brownish gray secondary hues; soft; sticky; mushy; irregular, shapeless cuttings, trace PDC bit action; silty to clayey texture; dull to greasy luster; very soluble and expansive; poor cohesiveness; good adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. Tuffaceous Claystone/ Tuffaceous Siltstone (7230' - 7300') = medium light to light gray with light yellowish gray secondary hues; soft; sticky; mushy; irregular, shapeless cuttings; clayey to silty texture; dull to greasy luster; hydrophilic; very soluble and expansive; poor cohesiveness; very good adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace very thin coal/ carbonaceous shale beds. Tuffaceous Claystone (7300' - 7340') = medium light to light gray with light brown and light yellowish gray secondary hues; very soft and very sticky; shapeless, irregular cuttings; silty to clayey texture; dull to earthy luster; very soluble and expansive; hydrophilic; poor cohesiveness; good adhesiveness. Tuffaceous Claystone/ Siltstone/ Unconsolidated Sand (7340'-7440') = dark gray to medium dark gray; soft and easily friable to unconsolidated; very poor to non indurated; pulverulent to malleable; no cuttings habit; very clayey texture in samples with minor amounts of silt; dull to greasy luster; strongly adhesive and lacking cohesiveness grading towards more cohesive; mushy to gelatinous; siltstone appears and tends to grade towards increasingly carbonaceous until a low grade coal/ carbonaceous shale appears; slight HCl reactions in sample with more than trace amounts of unconsolidated sand. Tuffaceous Siltstone/ Claystone/ Unconsolidated Sand (7440'-7520') = medium dark gray to black; firmly friable to soft and unconsolidated; moderate to very poor induration; brittle to crunchy with some pulverulent sections; no discernible cuttings habit; texture is a very clayey silt depending on amount of clay sample; greasy to dull luster; siltstone starts off as dark brown with thinly bedded dark carbonaceous material and becomes increasingly more carbonaceous until it appears as a carbonaceous shale/ low grade coal; no hydrochloric reaction. Tuffaceous Claystone/ Siltstone/ Unconsolidated Sand (7520'-7600) = medium dark gray to dark gray with some medium bluish gray; poor to no induration with a few moderately well indurated pieces; pulverulent to malleable; no discernible cuttings habit; sample ranges texturally from very clayey to silty clayey and occasionally gritty clayey; dull to greasy luster; displays highly adhesive and low cohesive qualities and grades towards slightly more cohesive; slimy grades to punky; tuffaceous siltstone appears in increasingly higher quantity; moderate to dusky brown; firmly friable to soft; moderate to poor induration; crumbly to pulverulent with some brittle pieces; extensive micro inclusions of dark carbonaceous material throughout; no discernible HCl reactions. Coal/ Carbonaceous Shale/ Carbonaceous Material (7600'-7680') = black to brownish black with dark brown secondary hues; hard and brittle to crumbly; platy to flaky to blocky; planar fracture dominant with trace conchoidal and birdeye; vitreous to earthy luster; smooth to silty texture; subbituminous; poorly developed coal grades to carbonaceous shale/ siltstone; no to trace outgassing detected. KBU 42-06Y 10 Tuffaceous Claystone/ Tuffaceous Siltstone (7680' - 7720') = medium to medium light gray with medium dark gray and light brownish gray secondary hues; soft; very sticky; shapeless, globular cuttings silty to clayey texture; greasy to earthy luster; non calcareous; trace dark brown to black carbonaceous laminations. Tuffaceous Claystone/ Tuffaceous Siltstone (7720' - 7790') = medium to medium light gray with light yellowish gray secondary hues; soft; sticky; irregular to shapeless with trace PDC bit action shaped cuttings; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble and expansive; poor cohesiveness; good adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace very thin coal/ carbonaceous shale beds. Tuffaceous Claystone/ Siltstone/ Unconsolidated Sand/ Coal (7790'-7880') = medium light gray to medium dark gray; soft and unconsolidated to friable; non to poor induration; pulverulent to malleable; no discernible cuttings habit; very silty, clayey texture; dull to greasy luster; displays extremely adhesive properties which grade into more cohesiveness; slimy to pasty; siltstone is mostly unconsolidated; poor to moderate induration; pulverulent to crumbly; silty texture; dull to earthy luster; significant micro intrusions of dark carbonaceous material; no HCl reactions. Tuffaceous Claystone/ Siltstone/ Coal/ Unconsolidated Sand (7900'-7980') = dark grayish black to medium light gray; soft and unconsolidated to friable; malleable to pulverulent; no discernible cuttings habit; silty clay to clayey texture; dull to greasy luster; high cohesiveness grading to higher adhesiveness; tacky grading to slimy; siltstone is often unconsolidated to soft with some firmly friable; non to moderate induration; malleable to crumbly; wedgelike cuttings habit when discernible; silty clayey texture; dull to earthy; significant micro intrusions of carbonaceous material and coal; samples display hydrochloric reaction only when unconsolidated sand is present in levels greater than 10%. Tuffaceous Claystone/ Tuffaceous Siltstone (7980' - 8040') = medium light to light gray with very light gray and light brownish gray secondary hues; very soft to trace firm; irregular, amorphous shaped cuttings; silty to clayey texture; dull, earthy to greasy luster; hydrophilic; poor cohesiveness; fair to good adhesiveness; very soluble and expansive non calcareous; trace dark brown to black carbonaceous laminations and inclusions. Coal/ Carbonaceous Shale (8040'-8100') = black with brownish black secondary hues; very firm to hard and brittle; massive to flaky and platy; planar fracture dominant with trace conchoidal and birdeye; smooth to silty texture; earthy to vitreous luster; bituminous to subbituminous weak trace outgassing bubbles observed; coal commonly grades to a silty shale. Tuffaceous Claystone/ Tuffaceous Siltstone (8100' - 8160') = medium light to light gray with light yellowish gray secondary hues; soft; sticky; irregular to shapeless with trace PDC bit action shaped cuttings; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble and expansive; poor cohesiveness; good adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. Tuffaceous Sandstone/ Sand (8160'-8220') = very light gray to grayish white with abundant light gray, light yellowish gray and light brownish gray secondary hues; soft to fragile and pulverulent; crumbly to crunchy; massive, irregular shaped cuttings; non calcareous; individual grains dominantly clear to translucent quartz and volcanic glass, trace dark gray, black and pale rose; very fine upper to medium lower, dominantly fine; angular to subangular; fair to good sorting; loosely supported in ash matrix. Tuffaceous Claystone/ Tuffaceous Siltstone (8220' - 8280') = light to very light gray with light yellowish gray secondary hues; soft to moderately firm; irregular to PDC bit action shaped cuttings; silty to clayey to slightly gritty texture; dull to earthy luster; slight to moderately soluble and expansive; poor to fair cohesiveness; fair adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations. KBU 42-06Y 11 Coal/ Carbonaceous Shale (8280'-8340') = black with brownish black secondary hues very firm to hard and brittle; massive to flaky and platy; planar fracture dominant with trace conchoidal and birdeye; smooth to silty texture; earthy to vitreous luster; bituminous; vigorous and prolonged outgassing bubbles observed; coal commonly interbedded with silty carbonaceous shale; dark brown; soft to firm; silty texture; earthy luster. Tuffaceous Claystone/ Tuffaceous Siltstone (8340'-8410') = medium light gray to brownish gray with light brownish gray and light gray secondary hues; firm to fragile and pulverulent; irregular shaped with PDC bit action shaped common; silty to clayey texture; dull to earthy luster; slight to moderately soluble and expansive; fair cohesiveness; poor to fair adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. Sand (8410'-8450') = light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to medium upper, dominantly fine; angular to subangular; moderately well sorted; very loosely supported in ashy matrix. Tuffaceous Sandstone/ Unconsolidated Sand/ Tuffaceous Siltstone/ Coal (8450'- 8540') = medium dark gray to black with scattered light gray; lower medium to lower fine grain size; moderate sphericity; sub angular to sub rounded; moderately well sorted; unconsolidated to very poorly consolidated; very loosely supported ash matrix; 80% quartz grains with the rest being made up of volcanic glass and trace dark lithics; siltstone is dark brown; firmly friable; shows moderate induration; crumbly; gritty silty texture; dull luster; micro inclusions of coal and carbonaceous material; moderate outgassing on coal heavy samples; no hydrochloric reactions Tuffaceous Sandstone/ Unconsolidated Sand/ Coal/ Siltstone (8560' - 8620') = medium dark gray to black, with some medium light gray; lower fine to upper medium grain size; low to moderate sphericity; subangular to angular; moderately well sorted; very poorly consolidated to unconsolidated; very loose ashy matrix; 70% quartz grains, remainder comprised of volcanic glass and trace dark lithics; coal shows minor outgassing; trace to no hydrochloric reactions. Tuffaceous Siltstone/ Tuffaceous Sandstone/ Unconsolidated Sand/ Coal (8620' - 8680') = medium light gray to black soft and unconsolidated to friable; moderate to poor induration; crumbly to crunchy; no discernible cuttings habit; gritty silty texture; dull earthy luster; significant micro intrusions of dark carbonaceous material; little to no hydrochloric reaction. Sand/ Tuffaceous Sandstone (8680' - 8740') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace dark gray, black and light to medium green to greenish gray; very fine lower to trace medium upper, dominantly fine lower; angular to subangular; fair to good sorting; unconsolidated to very loosely supported in ashy matrix; very fragile, pulverulent; non calcareous. Tuffaceous Sandstone/ Sand (8740' - 8840') = very light gray to light yellowish gray with light gray, light brown to light brownish gray, greenish gray secondary hues; soft to fragile and pulverulent; crumbly to crunchy; massive, irregular shaped cuttings; non calcareous; individual grains dominantly clear to translucent quartz and volcanic glass, trace dark gray, black and pale rose; very fine lower to medium lower, dominantly fine; angular to subangular; fair to good sorting; loosely supported in ash matrix; light yellowish gray to light brownish gray siltstone grades between silty sandstone and sandy siltstone; soft to firm; non calcareous; trace thin coal/ carbonaceous shales throughout interval. Tuffaceous Siltstone/ Tuffaceous Claystone (8840'-8900') = medium light gray to light brownish gray with light olive gray secondary hues; irregular shaped with PDC bit action 'scooped' appearance common; firm to fragile and pulverulent; silty to clayey to slightly gritty texture; dull to earthy luster; poor adhesiveness; fair cohesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace thin coal/ carbonaceous shale beds throughout interval. KBU 42-06Y 12 Tuffaceous Siltstone/ Sandstone (8900' - 8960') = medium light to light brownish gray to light yellowish gray; irregular shaped cuttings; soft to slightly firm; silty to clayey to slightly gritty texture; dull to earthy luster; non calcareous; siltstone grades between silty sandstone and sandy siltstone; trace dark brown to black microthin carbonaceous laminations and inclusions; trace coal/ carbonaceous shale beds. Coal/ Carbonaceous Shale (8960'-9030') = black with brownish black secondary hues; very firm to hard and brittle; massive to flaky and platy; planar fracture dominant with trace conchoidal and birdeye; smooth to silty texture; earthy to vitreous luster; bituminous; vigorous and prolonged outgassing bubbles observed. Sand/ Sandstone/ Tuffaceous Sandstone (9030' - 9090') = medium light gray with a strong salt and pepper appearance; hard very fine upper to fine upper; well sorted; grain supported; non calcareous cement; individual grains dominantly clear to translucent quartz and volcanic glass trace dark liths; very fine upper to coarse lower, medium dominant; angular to subangular; poorly sorted; loosely supported in ash matrix. Tuffaceous Sandstone/ Sand (9090' - 9160') = very light gray to grayish white with abundant light gray, light yellowish gray and light brownish gray secondary hues; soft to fragile and pulverulent; crumbly to crunchy; massive, irregular shaped cuttings; non calcareous; individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark greenish gray, dark gray, black; very fine lower to fine upper; angular to subangular; moderately well sorted; very loosely supported in ashy matrix. Tuffaceous Siltstone/ Tuffaceous Sandstone/ Sand/ Coal (9160' - 9240') = medium dark grey to medium light gray with scattered black; easily friable to firmly friable; well to moderate induration; crumbly and crunchy to sometimes brittle sometimes platy cuttings habit; silty to clayey silty texture, sometimes gritty dull to earthy luster; some micro laminations of thin dark carbonaceous material; no hydrochloric reactions. Tuffaceous Sandstone/ Unconsolidated Sand/ Coal (9240' - 9320') = medium light gray to medium dark gray and scattered black; upper fine to lower coarse grained translucent to clear quartz grains; moderate to low sphericity; sub angular to subrounded; poor sorting, grades into more moderate sorting; very poorly consolidated and unconsolidated to moderate consolidation; very loose ash matrix; 70% quartz grains with the rest comprised of volcanic glass and trace dark lithics; moderate to minor outgassing seen in the coals; samples are non calcareous. Tuffaceous Siltstone/ Unconsolidated Sand/ Tuffaceous Sandstone/ Coal (9320' - 9400') = medium light gray to dark gray and scattered black; firmly friable to easily friable and soft; moderate to poor induration; dense to brittle, sometimes crumbly; mostly irregular cuttings habit with rare bladed and/or curved; clayey silty texture that sometimes gets gritty based on amount of sand present; dull to earthy luster; can be slightly cohesive due to clay; scattered dark carbonaceous micro laminations; no reaction to hydrochloric acid; significant outgassing in later samples due to coal. Tuffaceous Sandstone/ Tuffaceous Siltstone/ Unconsolidated Sand/ Coal (9400' - 9500') = light gray to medium light gray, some black and medium dark gray; lower fine to upper medium grain size; moderate to low sphericity; subrounded to subangular; poor sorting grading into more moderate sorting; friable to very poorly consolidated grading into more moderately well consolidated; matrix consists of a very loose ash; siltstone is seen with increasingly high amounts of dark carbonaceous micro laminations as the sample grades; culminates in a coal which displays very high outgassing; no hydrochloric reactions. Tuffaceous Siltstone (9500' - 9600') = light brownish gray with light gray and yellowish gray secondary hues; irregular shaped with PDC bit action common; firm; silty to clayey to slightly gritty; earthy to dull luster; light yellowish gray siltstone grades between sandy siltstone and silty sandstone; firm to fragile; non calcareous; trace waxy tuff; light yellowish gray to grayish white; fragile; waxy luster; smooth texture; note: poor sample quality from safe carb mud additive contamination (10% - 30%). KBU 42-06Y 13 Tuffaceous Sandstone/ Unconsolidated Sand/ Coal/ Tuffaceous Siltstone (9600' - 9700') = medium light gray to medium dark gray; lower medium to upper medium grade toward upper fine; moderate to high sphericity; subangular to subrounded; moderate to well sorted; moderately consolidated grading towards more unconsolidated; moderately tight ashy matrix grading towards a much looser matrix; 70% quartz grained with the remainder composed of volcanic glass, and trace dark lithics; scattered trace amounts of light yellowish gray tuff; siltstone appears as dark brown and with extensive micro laminations of dark carbonaceous material; non calcareous. Tuffaceous Sandstone/ Unconsolidated Sand/ Tuff/ Siltstone (9700' - 9800') = medium light gray to medium dark gray, scattered very light gray; upper fine to lower medium grain size; moderate to low sphericity; subrounded to subangular; moderate to poor sorting; moderately well consolidated grades into poor and unconsolidated; tight ashy matrix grades into a looser ashy matrix; 70% quartz grained, the remainder consists of volcanic glass and trace dark lithics; yellowish gray to white tuff becomes increasingly abundant; non calcareous. Tuffaceous Sandstone/ Unconsolidated Sand/ Tuff/ Siltstone (9800' - 9860') = medium dark gray to medium light gray scattered very light gray; upper fine to lower medium grain size; moderate to low sphericity; subrounded to subangular; moderate to poor sorting; moderately well consolidated grades into poor and unconsolidated; tight ashy matrix grades into a looser ashy matrix; 70% quartz grained, the remainder consists of volcanic glass and trace dark lithics; coal displays moderate to significant outgassing; non calcareous. Tuffaceous Siltstone/ Tuffaceous Sandstone/ Unconsolidated Sand (9870' - 9940') = medium dark gray to medium gray with scattered brownish black; soft and easily friable grades to more firmly friable; moderate induration; crunchy grading into crumbly; silty texture grades to clayey silty to gritty silty; dull to earthy luster; irregular cuttings habit with evidence of PDC bit action; thin micro laminations of dark carbonaceous material abundant in early samples; no hydrochloric reaction. Tuffaceous Siltstone/ Tuffaceous Sandstone/ Unconsolidated Sand (9940' - 10040') = medium gray to medium dark gray with scattered olive gray; soft to easily friable with traces of firmly friable; moderately well indurated with scattered poor to very poor induration; crumbly grading towards crunchy; irregular cuttings habit with evidence of PDC bit action; very silty texture grades towards a more adhesively clayey texture; dull to earthy luster; samples display slightly adhesive clay properties near the end of this interval; micro laminations of a dark carbonaceous material is seen in increasingly greater quantities; very slight hydrochloric reaction seen in several samples. Coal (10040'-10080') = black with brownish black secondary hues; hard; brittle at times; platy to flaky, occasionally splintery; planar fracture dominant with trace conchoidal and birdeye fracture; smooth to silty texture; earthy to vitreous luster; bituminous to sub lignitic; abundant outgassing bubbles observed. Tuffaceous Sandstone/ Sandstone/ Sand/ Conglomeratic Sand (10080' - 10160') = grayish white with light gray, very light greenish gray and light yellowish gray secondary hues; very soft and fragile; crumbly to crunchy; pulverulent; massive, irregular shaped cuttings; individual sand grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, black, green to greenish gray; very fine lower to pebble (4mm), dominantly medium; angular to subangular; poorly sorted; very loosely supported in ashy matrix; non calcareous. Tuffaceous Sandstone/ Sand (10160’ – 10240’) = very light gray to grayish white with abundant light gray, light yellowish gray and light brownish gray secondary hues; soft to fragile and pulverulent; crumbly to crunchy; massive, irregular shaped cuttings; non calcareous; individual sand grains multicolored with clear to translucent quartz and volcanic glass dominant; very fine upper to pebble and pebble fragments (3-5mm), dominantly medium lower to coarse lower; angular to subangular; poorly sorted; loosely supported in ash matrix; trace to common white ashy tuff; fragile to pulverulent; common glass shards visible. KBU 42-06Y 14 Tuffaceous Siltstone (10240'-10300') = light brownish gray with light gray and light olive gray secondary hues; irregular shaped with PDC bit action common; massive; firm to crumbly and pulverulent; silty to clayey to slightly gritty; earthy to dull luster; light yellowish gray siltstone grades between sandy siltstone and silty sandstone; firm to fragile; well sorted; grain supported; non calcareous; present as thin beds in dominant tuffaceous sandstone formation. Tuffaceous Sandstone (10300' - 10380') = very light gray to grayish white with abundant light gray, light yellowish gray and light brownish gray secondary hues; soft to fragile and pulverulent; crumbly to crunchy; massive, irregular shaped cuttings; non calcareous; individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark greenish gray, dark gray, black; very fine upper to very coarse upper, dominantly medium lower to coarse lower; angular to subangular; poorly sorted; very loosely supported in ashy matrix. Tuffaceous Siltstone (10380' - 10440') = light brownish gray with light gray and yellowish gray secondary hues; irregular shaped with PDC bit action common; firm; silty to clayey to slightly gritty texture; dull to earthy luster; fair to good cohesiveness; poor adhesiveness; non calcareous; very light yellowish brown and light brownish gray siltstone grades between sandy siltstone and silty sandstone; fragile; well sorted; grain supported; non calcareous. Tuffaceous Sandstone/ Sand (10440’ – 10520’) = very light gray to grayish white with abundant light gray, light yellowish gray and light brownish gray secondary hues; soft to fragile and pulverulent; crumbly to crunchy; massive, irregular shaped cuttings; non calcareous; individual sand grains multicolored with clear to translucent quartz and volcanic glass dominant; very fine upper to pebble and pebble fragments, dominantly medium; angular to subangular; poorly sorted; very loosely supported by ashy matrix; trace thin coal beds. Tuffaceous Siltstone (10520' - 10580') = light brownish gray with light gray and light olive gray secondary hues; irregular shaped with PDC bit action common; silty to clayey to slightly gritty texture; dull to earthy luster; fair to good cohesiveness; poor adhesiveness; firm to crumbly and pulverulent; light yellowish gray to very light brownish gray siltstone grades between silty sandstone and sandy siltstone; soft; non calcareous. Tuffaceous Siltstone/ Tuffaceous Sandstone/ Sand/ Conglomerate/ Tuff (10580'-10680') = olive and medium dark gray to light gray, scattered medium light gray; soft and easily friable to firmly friable; moderate to poor induration; crunchy to crumbly; irregular cuttings habit and PDC bit action common; gritty silty grades into a more clayey silty texture; dull to earthy luster; poor cohesiveness and moderate adhesiveness; small amounts of dark carbonaceous laminations; varying amounts of very coarse quartz conglomerate present; no hydrochloric reactions. Tuffaceous Sandstone/ Tuffaceous Siltstone (10680' - 10800') = olive gray to medium light gray, scattered very light gray; lower fine to upper medium grain size; moderate to low sphericity; sub angular to sub rounded; moderately well sorted; poorly consolidated to unconsolidated; very loose ashy matrix with scattered pieces of relatively tight ashy matrix; 80% quartz grained with the remainder made up of volcanic glass and trace dark lithics; mild HCl reaction in early samples; siltstone is a moderate brown; friable to firmly friable; moderate to poorly indurated; crumbly to sometimes slightly crunchy; platy cuttings habit; dull to earthy luster; starts off as a clayey, gritty, silky texture and grades towards a more smooth silty texture; moderate adhesive qualities disappear in later samples; carbonaceous micro laminations increasing in abundance until terminate in coal. Tuffaceous Siltstone/ Tuffaceous Sandstone/ Unconsolidated Sand (10800' - 10895') = olive gray to medium dark gray; soft and easily friable to firmly friable; moderately well to poor induration; crumbly to sometimes crunchy; platy to irregular cuttings habit; clayey silty to gritty silty texture; dull to earthy luster; slightly cohesive qualities; shows moderate micro laminations of dark carbonaceous material; no hydrochloric reactions; sandstone is a light white gray with an extremely loose ashy matrix; poorly consolidated to unconsolidated. KBU 42-06Y 15 3.3 Sampling Program The sampling program specified by the Geologist called for the collection of three sets of Washed and Dried Reference Samples beginning at 6493’ MD. The resulting set, interval, and distribution are shown below. Sets Type and Purpose Interval Frequency Distribution A Washed and Dried 6493’ –10895’ 20’ Landon Ellison Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 B Washed and Dried 6493’ –10895’ 20’ Landon Ellison Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 C Washed and Dried 6493’ –10895’ 20’ Landon Ellison Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 KBU 42-06Y 16 4 DRILLING DATA 4.1 Surveys Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 18.50 0.00 0.00 18.50 0.00 0.00 0.00 0.00 264.25 0.66 121.31 264.24 -0.73 1.21 -0.36 0.27 325.99 0.33 140.44 325.99 -1.06 1.62 -0.55 0.59 387.47 0.50 179.28 387.47 -1.46 1.74 -0.91 0.51 448.65 0.66 78.08 448.64 -1.65 2.09 -0.99 1.47 510.73 0.96 39.45 510.72 -1.18 2.77 -0.35 0.97 571.71 1.64 32.34 571.68 -0.05 3.56 0.96 1.15 633.40 3.49 23.96 633.31 2.41 4.79 3.67 3.06 695.86 4.83 22.60 695.60 6.58 6.58 8.18 2.15 758.67 6.06 19.08 758.13 12.16 8.68 14.12 2.03 820.07 7.43 17.22 819.10 19.02 10.91 21.33 2.25 881.76 8.46 13.52 880.19 27.24 13.15 29.85 1.86 946.23 9.81 13.63 943.84 37.19 15.56 40.07 2.10 1005.75 11.05 15.38 1002.38 47.61 18.26 50.84 2.14 1069.06 11.63 14.63 1064.45 59.64 21.48 63.28 0.94 1130.91 12.28 16.32 1124.96 71.98 24.91 76.09 1.20 1193.73 13.13 17.08 1186.24 85.21 28.88 89.90 1.37 1255.57 13.73 15.77 1246.39 98.99 32.94 104.26 1.09 1317.14 14.88 16.57 1306.05 113.60 37.18 119.48 1.88 1380.40 16.77 15.63 1366.91 130.17 41.95 136.72 3.02 1443.09 17.71 14.50 1426.79 148.11 46.78 155.29 1.60 1505.09 19.57 14.53 1485.53 167.29 51.74 175.10 2.99 1565.39 20.55 15.41 1542.17 187.27 57.09 195.77 1.71 1601.10 20.68 16.67 1575.60 199.35 60.56 208.34 1.29 1663.12 21.94 17.64 1633.38 220.89 67.22 230.88 2.12 1725.41 22.47 15.75 1691.05 243.43 73.97 254.42 1.42 1787.76 23.83 15.73 1748.37 267.03 80.62 278.93 2.19 1849.25 25.18 17.32 1804.32 291.48 87.89 304.43 2.44 1911.55 27.10 17.70 1860.25 317.65 96.15 331.88 3.09 1972.68 28.76 18.22 1914.25 344.89 104.98 360.50 2.74 2035.67 30.19 17.61 1969.09 374.38 114.51 391.48 2.32 2095.91 30.14 17.89 2021.17 403.21 123.74 421.75 0.25 2159.30 31.02 17.36 2075.74 433.95 133.50 453.99 1.45 2221.68 30.75 17.48 2129.28 464.50 143.09 486.01 0.45 KBU 42-06Y 17 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 2283.50 30.33 16.94 2182.52 494.51 152.38 517.42 0.81 2345.31 30.58 16.75 2235.80 524.50 161.46 548.75 0.44 2407.20 30.99 16.09 2288.97 554.88 170.41 580.43 0.86 2469.28 30.63 16.46 2342.29 585.41 179.33 612.22 0.66 2532.12 31.30 15.78 2396.17 616.46 188.30 644.56 1.21 2593.49 31.43 16.01 2448.57 647.19 197.05 676.50 0.29 2655.72 30.98 15.85 2501.80 678.19 205.90 708.74 0.75 2717.60 30.40 15.98 2555.01 708.56 214.56 740.32 0.95 2779.25 31.31 16.48 2607.94 738.92 223.39 771.93 1.54 2841.05 31.66 16.67 2660.64 769.85 232.60 804.21 0.60 2903.97 31.13 17.08 2714.35 801.22 242.11 836.99 0.91 2966.21 30.55 16.55 2767.79 831.76 251.35 868.89 1.03 3028.27 30.65 16.28 2821.20 862.07 260.27 900.48 0.27 3090.20 31.89 15.45 2874.14 892.99 269.06 932.63 2.13 3152.09 32.52 14.67 2926.50 924.84 277.63 965.61 1.22 3214.25 32.11 14.94 2979.03 956.97 286.12 998.82 0.70 3276.49 31.88 16.62 3031.82 988.86 294.53 1031.79 0.46 3338.84 31.43 14.81 3084.89 1020.51 302.85 1064.50 0.74 3400.50 31.03 14.53 3137.62 1051.43 310.94 1096.45 0.69 3462.59 30.54 14.53 3190.96 1082.20 318.92 1128.21 0.80 3524.62 30.02 14.64 3244.53 1112.46 326.79 1159.47 0.84 3586.72 29.65 15.04 3298.39 1142.33 334.70 1190.35 0.67 3648.72 30.05 15.42 3352.17 1172.11 342.81 1221.20 0.72 3710.23 30.00 15.39 3405.42 1201.78 350.99 1251.98 0.08 3772.41 29.73 15.69 3459.34 1231.61 359.28 1282.94 0.50 3834.53 29.50 15.51 3513.35 1261.18 367.54 1313.63 0.40 3896.80 29.99 17.37 3567.42 1290.80 376.28 1344.52 1.68 3959.07 30.18 18.08 3621.30 1320.53 385.79 1375.73 0.64 4020.67 30.90 16.66 3674.35 1350.41 395.13 1407.02 1.66 4082.55 31.36 16.23 3727.32 1381.09 404.18 1439.01 0.82 4144.55 31.07 16.70 3780.35 1411.90 413.29 1471.14 0.61 4205.65 30.70 16.59 3832.80 1441.95 422.27 1502.51 0.62 4268.63 30.33 15.93 3887.04 1472.65 431.23 1534.49 0.79 4330.79 30.03 15.87 3940.77 1502.71 439.79 1565.74 0.49 4392.80 29.72 15.83 3994.54 1532.42 448.22 1596.62 0.51 4454.98 29.51 16.22 4048.60 1561.96 456.71 1627.35 0.46 4516.84 30.50 16.45 4102.17 1591.65 465.41 1568.29 1.61 KBU 42-06Y 18 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 4578.69 30.84 16.67 4155.36 1621.89 474.40 1689.84 0.57 4641.29 30.56 16.74 4209.19 1652.50 483.59 1721.80 0.45 4703.17 30.39 16.96 4262.52 1682.54 492.69 1753.19 0.33 4765.40 30.07 16.94 4316.28 1712.51 501.83 1784.52 0.52 4827.59 29.89 16.90 4370.15 1742.24 510.87 1815.59 0.29 4889.67 30.72 17.82 4423.75 1772.14 520.22 1846.91 1.52 4951.40 31.62 17.65 4476.57 1802.57 529.95 1878.86 1.47 5013.68 31.24 17.83 4529.71 1833.51 539.84 1911.33 0.63 5075.64 31.19 17.73 4582.70 1864.08 549.65 1943.43 0.12 5137.44 30.81 17.52 4635.67 1894.42 559.29 1975.25 0.64 5199.44 30.46 17.46 4689.01 1924.55 568.78 2006.84 0.56 5261.65 30.29 18.37 4742.69 1954.48 578.46 2038.29 0.80 5324.09 30.03 18.09 4796.68 1984.28 588.27 2069.64 0.48 5385.28 29.60 17.69 4849.77 2013.23 597.62 2100.05 0.77 5447.51 30.06 18.01 4903.75 2042.69 607.11 2131.00 0.79 5508.25 30.62 18.18 4956.17 2071.86 616.64 2161.67 0.93 5571.88 30.30 18.07 5011.02 2102.51 626.67 2193.91 0.51 5633.76 30.15 17.96 5064.49 2132.14 636.31 2225.05 0.26 5696.13 29.93 18.33 5118.48 2161.81 646.04 2256.26 0.46 5756.90 29.73 18.19 5171.20 2190.52 655.51 2286.48 0.35 5819.82 29.57 18.49 5225.88 2220.06 665.30 2317.59 0.36 5881.51 29.71 18.51 5279.50 2248.99 674.98 2348.08 0.24 5943.76 30.51 16.19 5333.34 2278.80 684.28 2379.30 2.28 6006.44 30.55 15.45 5387.34 2309.43 692.96 2411.14 0.60 6068.36 30.18 15.45 5440.76 2339.61 701.30 2442.43 0.58 6129.47 29.96 15.13 5493.65 2369.14 709.37 2473.05 0.45 6191.67 29.97 15.14 5547.53 2399.13 717.49 2504.11 0.01 6254.15 29.83 15.48 5601.70 2429.17 725.71 2535.25 0.35 6315.93 29.73 15.30 5655.32 2458.76 733.85 2565.93 0.23 6377.79 29.46 16.06 5709.11 2488.17 742.11 2596.47 0.74 6449.72 29.24 15.73 5771.80 2522.08 751.77 2631.73 0.38 6506.58 29.97 17.31 5821.24 2549.01 759.75 2659.82 1.88 6568.79 31.01 17.30 5874.84 2579.15 769.14 2691.38 1.68 6630.74 31.29 17.36 5927.86 2609.74 778.69 2723.42 0.44 6693.02 31.12 16.89 5981.13 2640.57 788.19 2755.69 0.47 6755.20 30.66 16.07 6034.49 2671.18 797.25 2787.61 1.01 6816.23 30.91 15.84 6086.92 2701.21 805.83 2818.84 0.45 6877.10 31.00 15.72 6139.13 2731.34 814.35 2850.15 0.18 6939.49 31.30 15.69 6192.52 2762.41 823.08 2882.41 0.48 KBU 42-06Y 19 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 7003.09 31.23 15.61 6246.89 2794.19 831.99 2915.42 0.12 7064.88 30.70 16.04 6299.87 2824.78 840.65 2947.21 0.93 7127.13 30.42 16.03 6353.47 2855.19 849.39 2978.85 0.46 7189.02 30.00 15.73 6406.96 2885.15 857.91 3009.99 0.72 7251.14 27.43 14.89 6461.44 2913.93 865.80 3039.83 4.18 7313.26 26.16 13.70 6516.88 2941.06 872.72 3067.81 2.23 7374.77 24.51 14.68 6572.48 2966.58 879.17 3094.11 2.77 7437.42 23.09 16.13 6629.80 2990.95 885.87 3119.38 2.45 7498.68 22.87 15.58 6686.20 3013.95 892.40 3143.29 0.50 7561.10 22.07 15.33 6743.88 3036.94 898.76 3167.14 1.29 7621.41 21.12 15.00 6799.96 3058.37 904.57 3189.33 1.58 7684.81 19.72 14.73 6859.37 3079.75 910.24 3211.45 2.21 7747.13 19.13 15.26 6918.14 3099.77 915.61 3232.17 1.00 7809.13 16.73 18.48 6977.13 3118.03 921.11 3251.24 4.18 7871.57 16.62 18.27 7036.95 3135.03 926.76 3269.14 0.20 7929.20 16.24 17.43 7092.22 3150.55 931.75 3285.44 0.77 7994.75 15.87 16.86 7155.22 3167.87 937.10 3303.57 0.62 8056.79 15.50 17.49 7214.95 3183.89 942.05 3320.34 0.64 8119.54 14.99 18.06 7275.49 3199.61 947.09 3336.84 0.85 8181.83 15.02 17.92 7335.65 3214.95 952.07 3352.96 0.08 8244.00 14.78 17.67 7395.73 3230.18 956.95 3368.95 0.40 8305.33 14.50 17.54 7455.07 3244.95 961.64 3384.44 0.47 8368.78 14.38 17.30 7516.52 3260.05 966.38 3400.26 0.21 8429.68 12.50 16.86 7575.75 3273.57 970.54 3414.41 3.09 8491.48 11.71 16.28 7636.17 3286.00 974.24 3427.38 1.28 8553.38 9.16 17.44 7697.04 3296.73 977.48 3438.59 4.14 8613.15 7.14 19.39 7756.20 3304.77 980.14 3447.05 3.42 8678.61 7.20 19.35 7821.15 3312.48 982.84 3455.21 0.09 8740.58 6.87 18.16 7882.66 3319.66 985.29 3462.79 0.58 8802.57 6.85 15.63 7944.20 3326.75 987.44 3470.20 0.49 8864.97 6.56 15.37 8006.18 3333.77 989.39 3477.48 0.47 8925.67 6.53 14.86 8066.48 3340.45 991.19 3484.40 0.11 8988.04 6.21 12.77 8128.46 3347.17 992.84 3491.31 0.64 9050.13 6.06 12.47 8190.20 3353.64 994.29 3497.93 0.24 9112.03 5.92 12.41 8251.76 3359.95 995.69 3504.37 0.24 9174.80 5.58 11.51 8314.22 3366.09 996.99 3510.64 0.56 9237.17 5.72 10.71 8376.28 3372.12 998.17 3516.75 0.26 9299.39 5.69 9.96 8438.20 3378.20 999.28 3522.90 0.13 9361.25 5.39 7.89 8499.77 3384.09 1000.21 3528.81 0.58 KBU 42-06Y 20 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 9423.50 5.39 7.81 8561.74 3389.89 1001.01 3534.59 0.02 9483.77 5.15 6.76 8621.76 3395.38 1001.71 3540.06 0.43 9545.33 5.30 7.76 8683.06 3400.95 1002.42 3545.60 0.28 9609.37 5.50 7.06 8746.82 3406.93 1003.20 3551.56 0.33 9670.53 5.23 6.05 8807.71 3412.61 1003.85 3557.19 0.46 9732.97 5.16 5.67 8869.89 3418.24 1004.43 3562.75 0.13 9795.66 4.90 4.67 8932.34 3423.71 1004.93 3568.14 0.44 9857.00 4.89 5.27 8993.46 3428.93 1005.38 3573.27 0.08 9919.09 4.68 4.98 9055.33 3434.08 1005.84 3578.35 0.34 9980.94 4.41 5.52 9116.98 3438.97 1006.29 3583.16 0.43 10042.29 4.26 5.94 9178.16 3443.58 1006.75 3587.72 0.26 10104.37 3.84 6.12 9240.08 3447.94 1007.21 3592.03 0.68 10166.92 3.61 4.14 9302.50 3451.99 1007.58 3596.01 0.43 10229.19 3.40 2.98 9364.66 3455.79 1007.82 3599.72 0.35 10291.04 3.58 4.44 9426.39 3459.55 1008.06 3603.40 0.32 10353.12 3.67 3.80 9488.35 3463.46 1008.34 3607.23 0.16 10415.40 3.41 3.20 9550.51 3467.31 1008.58 3610.98 0.42 10476.96 3.58 3.44 9611.95 3471.06 1008.80 3614.64 0.28 10539.73 3.54 1.64 9674.60 3474.95 1008.97 3618.43 0.19 10601.39 3.06 1.38 9736.16 3478.50 1009.06 3621.85 0.78 10663.46 2.94 1.44 9798.14 3481.74 1009.14 3624.99 0.20 10725.82 2.66 359.38 9860.43 3484.78 1009.17 3627.91 0.48 10787.68 2.41 359.68 9922.23 3487.51 1009.15 3630.53 0.39 10856.69 2.09 358.65 9991.19 3490.22 1009.11 3633.11 0.47 10895.00* 2.09 358.65 10029.47 3491.62 1009.08 3634.44 0.00 *Projected KB U 4 2 - 0 6 Y 21 4. 2 B i t R e c o r d BI T N O . SI Z E TY P E S/ N JE T S / TF A IN OU T FT HR S AV E RO P Ft / H R CONDITION 2 9 7 / 8 ” H D B S , M M 6 5 1 2 4 0 6 8 5 7 6 x 1 3 1 6 0 3 6 4 9 3 4 8 9 0 2 7 . 7 5 1 7 6 . 2 1 - 2 - C T - G - X - I - N O - T D RR 2 9 7 / 8 ” H D B S , M M 6 5 1 2 4 0 6 8 5 7 6 x 1 3 6 4 9 3 6 4 9 3 0 0 0 C L E A N O U T R U N 3 6 ¾ ” H D B S , E M 6 5 D 1 2 4 0 1 2 2 5 6 X 1 0 6 4 9 3 1 0 8 9 5 44 0 2 8 6 . 6 7 5 0 . 8 1 - 1 - E R - S - X - I - N O - T D KB U 4 2 - 0 6 Y 22 4. 3 M u d R e c o r d Co n t r a c t o r : M . I . S w a c o S P U D M U D 1 6 0 3 ’ – 1 6 2 3 ’ , K L A S H I E L D 1 6 2 3 ’ – 1 0 8 9 5 ’ Da t e De p t h (M D / T V D ) MW (p p g ) VI S (s / q t ) PV YP Ge l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) MB T pH Cl (ml/l) Ca (ml/l) 7/ 2 9 / 2 0 1 4 1 6 0 3 / 1 5 7 7 9 5 5 1 8 1 4 3 / 5 / 8 9 1 / - 3 / 9 7 1 1 5 8 . 4 3 0 0 1 2 0 7/ 3 0 / 2 0 1 4 1 7 0 4 / 1 6 8 7 9 6 3 1 4 3 3 7 / 1 5 / 1 7 5 . 8 1 / 1 4 T R / 9 6 . 1 6 9 . 9 4 3 0 0 0 1 2 0 7/ 3 1 / 2 0 1 4 3 5 0 3 / 3 2 4 2 9 . 2 7 0 1 5 2 2 7 / 1 2 / 1 8 5 . 2 1 / 1 6 T R / 9 4 . 3 5 6 9 . 5 5 0 0 0 0 2 4 0 8/ 1 / 2 0 1 4 4 6 8 0 / 4 2 4 9 9 . 4 7 0 1 7 2 8 7 / 1 4 / 2 0 5 . 4 1 / 1 8 T R / 9 2 . 2 5 6 9 . 8 4 7 0 0 0 4 8 0 8/ 2 / 2 0 1 4 4 9 4 5 / 4 5 3 3 9 . 5 6 1 1 8 2 8 7 / 1 5 / 2 1 5 . 6 1 / 1 7 T R / 9 3 . 3 8 9 . 9 4 9 0 0 0 1 6 0 8/ 3 / 2 0 1 4 6 4 9 3 / 5 8 0 9 9 . 7 6 7 1 9 3 0 6 / 1 4 / 1 9 5 1 / 1 8 T R / 9 2 . 2 5 1 0 . 5 9 . 6 4 8 5 0 0 2 4 0 8/ 4 / 2 0 1 4 6 4 9 3 / 5 8 0 9 9 . 7 7 1 2 4 2 5 6 / 1 3 / 2 0 4 . 7 1 / 1 9 1 / 9 0 T R 1 0 9 . 6 5 1 0 0 0 2 4 0 8/ 5 / 2 0 1 4 6 4 9 3 / 5 8 0 9 9 . 7 6 9 2 3 2 5 6 / 1 3 / 2 0 4 . 9 1 / 1 9 1 / 9 0 T R 1 1 9 . 5 4 9 5 0 0 2 4 0 8/ 6 / 2 0 1 4 6 4 9 3 / 5 8 0 9 9 . 7 7 4 2 2 2 8 6 / 1 3 / 2 1 5 1 / 1 9 1 / 9 0 T R 1 1 9 . 5 4 9 5 0 0 2 4 0 8/ 7 / 2 0 1 4 6 4 9 3 / 5 8 0 9 9 . 3 6 6 2 0 2 8 6 / 1 0 / 1 6 6 . 2 1 / - 6 T R / 9 4 . 1 6 9 . 0 3 7 0 0 0 1 2 0 8/ 8 / 2 0 1 4 6 4 9 3 / 5 8 0 9 9 . 0 5 0 8 1 2 3 / 6 / 9 9 . 4 1 / - 4 T R / 9 6 . 2 5 4 8 . 8 2 9 0 0 0 1 2 0 8/ 9 / 2 0 1 4 6 4 9 3 / 5 8 0 9 9 . 0 5 0 8 1 2 3 / 6 / 9 9 . 4 1 / - 4 T R / 9 6 . 2 5 4 8 . 8 2 9 0 0 0 1 2 0 8/ 1 0 / 2 0 1 4 6 6 4 0 / 5 9 3 8 9 . 7 5 9 1 8 1 9 5 / 7 / 1 0 5 . 4 1 / 1 6 T R / 9 4 . 1 5 . 5 9 . 2 5 0 0 0 0 1 6 0 8/ 1 1 / 2 0 1 4 7 3 5 8 / 6 5 5 7 9 . 9 6 9 2 0 2 1 4 / 9 / 1 4 4 . 6 1 / 1 6 2 / 9 2 . 1 5 . 5 1 0 . 1 5 5 0 0 0 1 4 0 8/ 1 2 / 2 0 1 4 7 8 6 1 / 7 0 2 6 1 0 . 1 7 2 2 5 2 2 4 / 1 0 / 1 3 4 . 4 1 / 1 1 0 2 / 8 8 0 . 1 5 1 0 . 1 5 3 0 0 0 1 0 0 8/ 1 3 / 2 0 1 4 8 5 0 6 / 7 6 5 0 1 0 . 3 5 8 2 2 2 3 4 / 9 / 1 2 4 . 3 1 / 1 1 0 . 5 2 / 8 8 0 . 1 5 9 . 8 5 3 0 0 0 1 0 0 8/ 1 4 / 2 0 1 4 9 0 5 0 / 8 6 6 0 1 1 . 8 6 2 3 1 3 3 6 / 1 0 / 1 3 4 . 4 1 / 1 1 7 2 / 8 2 0 . 1 5 9 . 8 4 7 0 0 0 1 2 0 8/ 1 5 / 2 0 1 4 9 7 8 1 / 8 9 1 9 1 2 . 0 6 1 2 8 3 0 6 / 9 / 1 4 4 . 4 1 / 1 1 8 2 / 8 1 . 1 5 9 . 8 5 0 0 0 0 1 2 0 8/ 1 6 / 2 0 1 4 1 0 6 3 8 / 9 7 7 3 1 2 . 0 5 6 2 6 2 3 6 / 9 / 1 1 4 . 9 1 / 1 1 8 1 / 8 1 . 1 5 . 5 9 . 4 5 0 0 0 0 1 2 0 8/ 1 7 / 2 0 1 4 1 0 8 9 5 / 1 0 0 2 9 1 2 . 1 5 9 2 7 2 7 5 / 1 0 / 1 3 3 . 8 1 / 1 1 8 2 / 8 0 0 . 1 5 . 5 9 . 6 5 2 0 0 0 1 2 0 8/ 1 8 / 2 0 1 4 1 0 8 9 5 / 1 0 0 3 0 1 2 . 1 6 2 2 7 2 7 5 / 1 0 / 1 3 4 1 / 1 1 8 2 / 8 0 0 . 1 5 . 5 9 . 6 5 2 0 0 0 1 2 0 8/ 1 9 / 2 0 1 4 1 0 8 9 5 / 1 0 0 3 0 1 2 5 6 2 4 2 1 4 / 9 / 1 2 4 . 2 1 / 1 1 8 2 / 8 0 0 . 1 5 . 5 9 . 6 5 2 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 PV = 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 G e l s = G e l S t r e n g t h F L = W a t e r o r F i l t r a t e Lo s s F C = F i l t e r C a k e O / W = O i l t o W a t e r r a t i o S o l s = S o l i d s S d = S a n d c o n t e n t M B T = M e t h y l e n e B l u e A l k , P m = A l k a l i n i t y , M u d pH = A c i d i t y C l = C h l o r i d e s C a = H a r d n e s s C a l c i u m n r = N o t R e c o r d e d KB U 4 2 - 0 6 Y 23 4. 4 D r i l l i n g P r o g r e s s C h a r t DA Y S V E R S U S D E P T H 15 0 0 20 0 0 25 0 0 30 0 0 35 0 0 40 0 0 45 0 0 50 0 0 55 0 0 60 0 0 65 0 0 70 0 0 75 0 0 80 0 0 85 0 0 90 0 0 95 0 0 10 0 0 0 10 5 0 0 11 0 0 0 7 /29/1 4 7/3 0 /14 7 /31 /1 4 8/1/14 8 /2 /14 8 /3/1 4 8/4/14 8 /5 /1 4 8 /6/14 8/7 /14 8 /8/1 4 8 /9/14 8/1 0 /14 8 /11 /1 4 8/12/14 8 /1 3 /14 8 /14 /1 4 8/15/14 8 /1 6 /1 4 8 /17/1 4 8/1 8 /14 8 /1 9 /1 4 8 /20/1 4 8 D E P T H (F T ) 9 7 / 8 " H o l e 6 3/4" Hole K B U 4 2 - 0 6 Y KBU 42-06Y 24 5 SHOW REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number Field: Date: Rig: Time: County: Depth Start End State:20 6525'MD 6550'MD Country:20 5837'TVD 5859'TVD Averages Before During After Maximum ROP (fph)76 ft/hr 102 ft/hr 83 ft/hr 125 ft/hr WOB 5 klbs 5 klbs 6 klbs 6 klbs RPM 34 rpm 48 rpm 64 rpm 67 rpm PP 1796 psi 2078 psi 2115 psi 2131 psi Mud Weight 10.1 lbs/gal 10.1 lbs/gal 10.1 lbs/gal 10.1 lbs/gal Chloride 54,000 54,000 54,000 54,000 Total Gas 28 167 66 267 C1 (ppm)6,866 34,522 11,843 53,471 C2 (ppm)- - - - C3 (ppm)- - - - C4 (ppm)- - - - C5 (ppm)- - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut UNCONSOLIDATED SAND IS PRIMARILY QUARTZ GRAINS RANGING FROM LOWER COARSE TO LOWER MEDIUM IN SIZE; MODERATE TO LOW SPHERICITY; SUBANGULAR; POORLY SORTED; UNCONSOLIDATED; 80% OR MORE QUARTZ; MODERATE HCL REACTION IN SAMPLES CONTAINING MOSTLY UNCONSOLIDATED SAND. 50-133-20634-00-00KBU 42-06Y Keanai Gas Field Saxon 147 8/10/2014 9:20 PM Cut Free Oil in Mud Keanai Peninsula Borough Alaska United States of America Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis Trey Thrailkill Gas ShowOil Show Rating 1 10 100 1000 10000 1234 pp m Pixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report #2 Operator: Well:API Number Field: Date: Rig: Time: County: Depth Start End State:20 8140'MD 8172'MD Country:20 7295'TVD 7326'TVD Averages Before During After Maximum ROP (fph)147 ft/hr 134 ft/hr 136 ft/hr 266 ft/hr WOB 9 klbs 8 klbs 8 klbs 10 klbs RPM 94 rpm 99 rpm 96 rpm 115 rpm PP 3071 psi 3056 psi 3078 psi 3117 psi Mud Weight 10.3 lbs/gal 10.3 lbs/gal 10.3 lbs/gal 10.3 lbs/gal Chloride 53,000 53,000 53,000 53,000 Total Gas 163 175 204 253 C1 (ppm)33,386 34,474 39,970 48,189 C2 (ppm)- - - - C3 (ppm)- - - - C4 (ppm)- - - - C5 (ppm)- - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut TUFFACEOUS SANDSTONE/SAND, INDIVIDUAL GRAINS DOMINANTLY CLEAR TO TRANSLUCENT QUARTZ AND VOLCANIC GLASS, TRACE DARK GRAY, BLACK AND PALE ROSE;VERY FINE UPPER TO MEDIUM LOWER, DOMINANTLY FINE; ANGULAR TO SUBANGULAR; FAIR TO GOOD SORTING; LOOSELY SUPPORTED IN ASH MATRIX. Hilcorp Alaska, LLC 50-133-20634-00-00KBU 42-06Y Keanai Gas Field Saxon 147 8/13/2014 12:23 PM Cut Free Oil in Mud Keanai Peninsula Borough Alaska United States of America Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis Trey Thrailkill Gas ShowOil Show Rating 1 10 100 1000 10000 1234 pp m Pixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report #3 Operator: Well:API Number Field: Date: Rig: Time: County: Depth Start End State:20 9356'MD 9377'MD Country:20 8494'TVD 8515'TVD Averages Before During After Maximum ROP (fph)113 ft/hr 119 ft/hr 83 ft/hr 160 ft/hr WOB 6 klbs 6 klbs 6 klbs 6 klbs RPM 67 rpm 66 rpm 66 rpm 70 rpm PP 3353 psi 3399 psi 3386 psi 3431 psi Mud Weight 11.8 lbs/gal 11.8 lbs/gal 11.8 lbs/gal 11.8 lbs/gal Chloride 47,000 47,000 47,000 47,000 Total Gas 359 575 280 935 C1 (ppm)71,085 113,981 55,607 185,461 C2 (ppm)496 786 381 1,275 C3 (ppm)28 42 20 67 C4 (ppm)5 7 3 11 C5 (ppm)- - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut TUFFACEOUS SANDSTONE, LIGHT GRAY TO MEDIUM LIGHT GRAY, SOME BLACK AND MEDIUM DARK GRAY; LOWER FINE TO UPPER MEDIUM GRAIN SIZE; MODERATE TO LOW SPHERICITY; SUBROUNDED TO SUBANGULAR; POOR SORTING GRADING INTO MORE MODERATE SORTING; FRIABLE TO VERY POORLY CONSOLIDATED GRADING INTO MORE MODERATELY WELL CONSOLIDATED; MATRIX CONSISTS OF A VERY LOOSE ASH. Hilcorp Alaska, LLC 50-133-20634-00-00KBU 42-06Y Keanai Gas Field Saxon 147 8/14/2014 9:47 PM Cut Free Oil in Mud Keanai Peninsula Borough Alaska United States of America Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis Trey Thrailkill Gas ShowOil Show Rating 1 10 100 1000 10000 1234 pp m Pixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report #4 Operator: Well:API Number Field: Date: Rig: Time: County: Depth Start End State:20 10083'MD 10102'MD Country:20 9219'TVD 9238'TVD Averages Before During After Maximum ROP (fph)75 ft/hr 71 ft/hr 78 ft/hr 137 ft/hr WOB 9 klbs 7 klbs 8 klbs 11 klbs RPM 73 rpm 73 rpm 73 rpm 74 rpm PP 3208 psi 3106 psi 3149 psi 3179 psi Mud Weight 12.0 lbs/gal 12.0 lbs/gal 12.0 lbs/gal 12.0 lbs/gal Chloride 50,000 50,000 50,000 50,000 Total Gas 121 439 270 635 C1 (ppm)23,380 83,559 51,580 118,934 C2 (ppm)150 629 381 918 C3 (ppm)8 40 22 57 C4 (ppm)- 6 4 12 C5 (ppm)- - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut TUFFACEOUS SANDSTONE, SANDSTONE, SAND, CONGLOMERATIC SAND, GRAYISH WHITE WITH LIGHT GRAY,VERY LIGHT GREENISH GRAY AND LIGHT YELLOWISH GRAY SECONDARY HUES; VERY SOFT AND FRAGILE; CRUMBLY TO CRUCHY; PULVERULENT; MASSIVE, IREGULAR SHAPED CUTTINGS; INDIVIDUAL SAND GRAINS DOMINANTLY CLEAR TO TRANSLUCENT QUARTZ AND VOLCANIC GLASS, MEDIUM TO DARK GRAY, BLACK, GREEN TO GREENISH GRAY; VERY FINE LOWER TO PEBBLE (4mm), DOMINANTLY MEDIUM; ANGULAR TO SUB ANGULAR; POORLY SORTED;VERY LOOSELY SUPPORTED IN ASHY MATRIX; NON CALCAREOUS. Hilcorp Alaska, LLC 50-133-20634-00-00KBU 42-06Y Keanai Gas Field Saxon 147 8/16/2014 7:46 AM Cut Free Oil in Mud Keanai Peninsula Borough Alaska United States of America Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis Trey Thrailkill Gas ShowOil Show Rating 1 10 100 1000 10000 1234 pp m Pixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report #5 Operator: Well:API Number Field: Date: Rig: Time: County: Depth Start End State:20 10142'MD 10162'MD Country:20 9278'TVD 9298'TVD Averages Before During After Maximum ROP (fph)70 ft/hr 57 ft/hr 78 ft/hr 121 ft/hr WOB 9 klbs 10 klbs 10 klbs 11 klbs RPM 73 rpm 74 rpm 74 rpm 74 rpm PP 3139 psi 3249 psi 3262 psi 3309 psi Mud Weight 12.0 lbs/gal 12.0 lbs/gal 12.0 lbs/gal 12.0 lbs/gal Chloride 50,000 50,000 50,000 50,000 Total Gas 181 177 266 237 C1 (ppm)35,295 34,186 52,333 45,527 C2 (ppm)248 220 366 312 C3 (ppm)18 16 23 21 C4 (ppm)- - - - C5 (ppm)- - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis Trey Thrailkill Gas ShowOil Show Rating Cut Free Oil in Mud Keanai Peninsula Borough Alaska United States of America Stain Hilcorp Alaska, LLC 50-133-20634-00-00KBU 42-06Y Keanai Gas Field Saxon 147 8/16/2014 8:43 AM Fluorescence TUFFACEOUS SANDSTONE, SANDSTONE, SAND, CONGLOMERATIC SAND GRAYISH WHITE WITH LIGHT GRAY,VERY LIGHT GREENISH GRAY AND LIGHT YELLOWISH GRAY SECONDARY HUES; VERY SOFT AND FRAGILE; CRUMBLY TO CRUCHY; PULVERULENT; MASSIVE, IRREGULAR SHAPED CUTTINGS; INDIVIDUAL SAND GRAINS DOMINANTLY CLEAR TO TRANSLUCENT QUARTZ AND VOLCANIC GLASS,MEDIUM TO DARK GRAY, BLACK, GREEN TO GREENISH GRAY; VERY FINE LOWER TO PEBBLE (4mm), DOMINANTLY MEDIUM; ANGULAR TO SUB ANGULAR; POORLY SORTED;VERY LOOSELY SUPPORTED IN ASHY MATRIX; NON CALCAREOUS. Cut Fluorescence Residual Cut 1 10 100 1000 10000 1234 pp m Pixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report #6 Operator: Well:API Number Field: Date: Rig: Time: County: Depth Start End State:20 10192'MD 10202'MD Country:20 9328'TVD 9338'TVD Averages Before During After Maximum ROP (fph)82 ft/hr 23 ft/hr 68 ft/hr 47 ft/hr WOB 10 klbs 12 klbs 9 klbs 13 klbs RPM 73 rpm 73 rpm 74 rpm 74 rpm PP 3265 psi 3223 psi 3233 psi 3290 psi Mud Weight 12.0 lbs/gal 12.0 lbs/gal 12.0 lbs/gal 12.0 lbs/gal Chloride 50,000 50,000 50,000 50,000 Total Gas 217 37 105 46 C1 (ppm)42,818 7,120 20,755 8,687 C2 (ppm)318 54 162 77 C3 (ppm)17 1 10 4 C4 (ppm)- - - - C5 (ppm)- - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis Trey Thrailkill Gas ShowOil Show Rating Cut Free Oil in Mud Keanai Peninsula Borough Alaska United States of America Stain Hilcorp Alaska, LLC 50-133-20634-00-00KBU 42-06Y Keanai Gas Field Saxon 147 8/16/2014 9:44 AM Fluorescence TUFFACEOUS SANDSTONE, SAND,VERY LIGHT GRAY TO GRAYISH WHITE WITH ABUNDANT LIGHT GRAY, LIGHT YELLOWISH GRAY AND LIGHT BROWNISH GRAY SECONDARY HUES; SOFT TO FRAGILE AND PULVERULENT; CRUMBLY TO CRUNCHY; MASSIVE, IRREGULAR SHAPED CUTTINGS; NON CALCAREOUS; INDIVIDUAL SAND GRAINS MULTICOLORED WITH CLEAR TO TRANSLUCENT QUARTZ AND VOLCANIC GLASS DOMINANT; VERY FINE UPPER TO PEBBLE AND PEBBLE FRAGMENTS (3-5mm), DOMINANTLY MEDIUM LOWER TO COARSE LOWER; ANGULAR TO SUBANGULAR; POORLY SORTED;LOOSELY SUPPORTED IN ASH MATRIX; TRACE TO COMMON WHITE ASHY TUFF; FRAGILE TO PULVERULENT; COMMON GLASS SHARDS VISIBLE. Cut Fluorescence Residual Cut 1 10 100 1000 10000 1234 pp m Pixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report #7 Operator: Well:API Number Field: Date: Rig: Time: County: Depth Start End State:20 10308'MD 10337'MD Country:20 9443'TVD 9472'TVD Averages Before During After Maximum ROP (fph)73 ft/hr 32 ft/hr 68 ft/hr 65 ft/hr WOB 10 klbs 12 klbs 9 klbs 14 klbs RPM 74 rpm 75 rpm 74 rpm 120 rpm PP 3294 psi 3250 psi 3330 psi 3367 psi Mud Weight 12.0 lbs/gal 12.0 lbs/gal 12.0 lbs/gal 12.0 lbs/gal Chloride 50,000 50,000 50,000 50,000 Total Gas 98 32 81 59 C1 (ppm)20,746 6,416 15,557 11,391 C2 (ppm)133 20 114 74 C3 (ppm)9 0 4 1 C4 (ppm)- - 1 - C5 (ppm)- - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis Trey Thrailkill Gas ShowOil Show Rating Cut Free Oil in Mud Keanai Peninsula Borough Alaska United States of America Stain Hilcorp Alaska, LLC 50-133-20634-00-00KBU 42-06Y Keanai Gas Field Saxon 147 8/16/2014 12:33 PM Fluorescence TUFFACEOUS SANDSTONE, VERY LIGHT GRAY TO GRAYISH WHITE WITH ABUNDANT LIGHT GRAY, LIGHT YELLOWISH GRAY AND LIGHT BROWNISH GRAY SECONDARY HUES; SOFT TO FRAGILE AND PULVERULENT; CRUMBLY TO CRUNCHY; MASSIVE, IRREGULAR SHAPED CUTTINGS; NON CALCAREOUS; INDIVIDUAL GRAINS DOMINANTLY CLEAR TO TRANSLUCENT QUARTZ AND VOLCANIC GLASS, MEDIUM TO DARK GREENISH GRAY, DARK GRAY, BLACK; VERY FINE UPPER TO VERY COARSE UPPER, DOMINANTLY MEDIUM LOWER TO COARSE LOWER; ANGULAR TO SUBANGULAR; POORLY SORTED; VERY LOOSELY SUPPORTED IN ASHY MATRIX. Cut Fluorescence Residual Cut 1 10 100 1000 10000 1234 pp m Pixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 KBU 42-06Y 25 6 DAILY REPORT Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR James Loft, Shane Barber DATE Aug 19, 2014 DEPTH 10895' PRESENT OPERATION Running Casing TIME 2400 YESTERDAY 10895' 24 HOUR FOOTAGE 0' CASING INFORMATION 7.625" @ 6481' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 12 VIS 56 PV 24 YP 21 FL 4.2 Gels 4/9/12 CL- 52000 FC 1/1 SOL 18 SD 0.1 OIL 2/80 MBT 5.5 pH 9.6 Ca+ 120 Alk 1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 2080 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Cement, spacers and displacement fluid was 387 bbl. Lost 19 bbl to formation while cementing. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2148.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR James Loft, Shane Barber DATE Aug 18, 2014 DEPTH 10895' PRESENT OPERATION Tripping out of hole TIME 2400 YESTERDAY 10895' 24 HOUR FOOTAGE 0' CASING INFORMATION 7.625" @ 6481' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" HDBS EM65D 12401225 6x10 6493' 10895 4402 TD 1-1-ER-S-X-I-NO-TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 12.1 VIS 62 PV 27 YP 27 FL 4 Gels 5/10/13 CL- 52000 FC 1/1 SOL 18 SD 0.1 OIL 2/80 MBT 5.5 pH 9.6 Ca+ 120 Alk 1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY CBU 290 gallons per minute with 2390 psi at casing shoe. Monitor well for swabbing and pumped dry job and dropped MUD DOG pipe wiper. Continue to TOOH and L?D drill pipe. TIH with remaining stands of pipe in derrick and monitored well, pumped a second dry job and continued pulling out of hole and laying down the remainder of the drill pipe. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR James Loft, Shane Barber DATE Aug 17, 2014 DEPTH 10895' PRESENT OPERATION Pulling out of hole TIME 2400 YESTERDAY 10683' 24 HOUR FOOTAGE 212' CASING INFORMATION 7.625"@ 6481' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10856.69 2.09 358.65 9991.19 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 9.75" HDBS EM65D 12401225 6x10 6493' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 63.4 @ 10773 3.6 @ 10695 42.9 40.68 FT/HR SURFACE TORQUE 11992 @ 10863 10774 @ 10718 11495.6 11781.34 AMPS WEIGHT ON BIT 12 @ 10753 4 @ 10832 8.2 9.92 KLBS ROTARY RPM 142 @ 10822 61 @ 10741 68.6 63.31 RPM PUMP PRESSURE 3343 @ 10783 3038 @ 10683 3243.1 3283.02 PSI DRILLING MUD REPORT DEPTH 10895/10030 MW 12.1 VIS 59 PV 27 YP 27 FL 3.8 Gels 5/10/13 CL- 52000 FC 1/1 SOL 18 SD 0.1 OIL 2/80 MBT 5.5 pH 9.6 Ca+ 120 Alk 1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 571 @ 10773 26 @ 10744 126.4 TRIP GAS CUTTING GAS 0 @ 10895 0 @ 10895 0.0 WIPER GAS 1696 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 111851 @ 10686 1934 @ 10697 24089.5 CONNECTION GAS HIGH ETHANE (C-2) 880 @ 10686 17 @ 10697 184.2 AVG PROPANE (C-3) 108 @ 10690 0 @ 10894 13.7 CURRENT BUTANE (C-4) 14 @ 10773 0 @ 10811 0.7 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 10895 0 @ 10895 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drilled to TD at 10985' at 06:30. Pumped sweep and spotted LCM pill. Tripped out of hole to shoe and circulated bottoms up. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR James Loft, Shane Barber DATE Aug 16, 2014 DEPTH 10683' PRESENT OPERATION Drilling ahead TIME 2400 YESTERDAY 9800' 24 HOUR FOOTAGE 883' CASING INFORMATION 7.625" @ 6481' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10663.46 2.94 1.44 9798.14 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" HDBS EM65D 12401225 6x10 6493' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 205.9 @ 10480 1.6 @ 10391 65.0 32.55 FT/HR SURFACE TORQUE 12250 @ 10524 9776 @ 9807 11020.1 11176.21 AMPS WEIGHT ON BIT 13 @ 10321 3 @ 10454 8.5 5.76 KLBS ROTARY RPM 120 @ 9826 71 @ 10558 73.4 72.77 RPM PUMP PRESSURE 3386 @ 10502 2882 @ 10081 3214.8 3038.95 PSI DRILLING MUD REPORT DEPTH 101638/9773 MW 12 VIS 56 PV 26 YP 23 FL 4.9 Gels 6/9/11 CL- 50000 FC 1/1 SOL 18 SD 0.1 OIL 1/81 MBT 5.5 pH 9.4 Ca+ 120 Alk 1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 809 @ 10371 20 @ 10317 137.5 TRIP GAS CUTTING GAS 0 @ 10683 0 @ 10683 0.0 WIPER GAS 265 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 158687 @ 10371 3955 @ 9946 26365.3 CONNECTION GAS HIGH ETHANE (C-2) 1380 @ 10372 3 @ 10324 201.5 AVG PROPANE (C-3) 67 @ 10029 0 @ 10386 9.6 CURRENT BUTANE (C-4) 18 @ 10369 0 @ 10386 0.5 CURRENT BACKGROUND/AVG 54 PENTANE (C-5) 0 @ 10683 0 @ 10683 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drilled to 10,643' and POOH for a quick 5 stand wiper trip and singled in with 8 singles. Pumped a sweep on bottom and continued drilling. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR James Loft, Shane Barber DATE Aug 15, 2014 DEPTH 9800' PRESENT OPERATION Drilling ahead TIME 2400 YESTERDAY 9504' 24 HOUR FOOTAGE 296' CASING INFORMATION 7.625" @ 6481' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9795.66 4.9 4.67 8932.34 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" HDBS EM65D 12401225 6x10 6493' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 154.6 @ 9700 2.8 @ 9585 60.9 130.74 FT/HR SURFACE TORQUE 10856 @ 9715 2573 @ 9656 9795.4 10099.05 AMPS WEIGHT ON BIT 16 @ 9658 4 @ 9517 9.0 7.77 KLBS ROTARY RPM 119 @ 9641 9 @ 9656 72.5 73.14 RPM PUMP PRESSURE 3547 @ 9521 2889 @ 9656 3213.3 3214.87 PSI DRILLING MUD REPORT DEPTH 9781/8819 MW 12 VIS 61 PV 28 YP 30 FL 4.4 Gels 6/9/14 CL- 50000 FC 1/1 SOL 18 SD 0.1 OIL 2/81 MBT 5 pH 9.8 Ca+ 120 Alk 0.7 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 597 @ 9639 17 @ 9610 138.1 TRIP GAS CUTTING GAS 0 @ 9800 0 @ 9800 0.0 WIPER GAS 2233 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 118066 @ 9506 3436 @ 9610 26513.1 CONNECTION GAS HIGH ETHANE (C-2) 796 @ 9639 2 @ 9609 175.5 AVG PROPANE (C-3) 28 @ 9708 0 @ 9523 8.1 CURRENT BUTANE (C-4) 0 @ 9800 0 @ 9800 0.0 CURRENT BACKGROUND/AVG 90 PENTANE (C-5) 0 @ 9800 0 @ 9800 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Tuffaceous sandstone, unconsolidated sand, Tuff DAILY ACTIVITY SUMMARY Circulated at 9522' while increasing mud to 11.8ppg and saw 2583 units of gas. CBU and begun POOH for scheduled wiper trip. POOH to 6483' and slipped/cut 73' of drill line. TIH to 9522' with no tight spots. Washed bottom from 9494' to 9522'. Saw 2233 units of wiper gas. Pumped high vis sweep and began drilling ahead. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR James Loft, Shane Barber DATE Aug 14, 2014 DEPTH 9504' PRESENT OPERATION Drilling Ahead TIME 2400 YESTERDAY 8493' 24 HOUR FOOTAGE 1011' CASING INFORMATION 7.625" @6841' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9483.77 5.15 6.76 8621.76 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" HDBS EM65D 12401225 6x10 6493' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 563.1 @ 8751 1.4 @ 8671 97.4 88.00 FT/HR SURFACE TORQUE 10644 @ 9153 727 @ 8566 6774.3 9082.66 AMPS WEIGHT ON BIT 33 @ 8759 0 @ 8575 6.2 4.17 KLBS ROTARY RPM 90 @ 8517 1 @ 8757 61.8 62.95 RPM PUMP PRESSURE 3601 @ 9475 2367 @ 8752 3029.8 3414.31 PSI DRILLING MUD REPORT DEPTH 9050/8860 MW 11.8 VIS 62 PV 31 YP 33 FL 4.4 Gels 6/10/13 CL- 47000 FC 1/1 SOL 17 SD 0.1 OIL 2/82 MBT 5 pH 9.8 Ca+ 120 Alk 0.9 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 2464 @ 9088 19 @ 8666 368.2 TRIP GAS CUTTING GAS 0 @ 9504 0 @ 9504 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 474462 @ 9088 1509 @ 8553 68171.6 CONNECTION GAS HIGH 2583 ETHANE (C-2) 4210 @ 9026 39 @ 8956 391.9 AVG 1734.33 PROPANE (C-3) 472 @ 9035 1 @ 8956 28.9 CURRENT BUTANE (C-4) 196 @ 9035 0 @ 9502 8.6 CURRENT BACKGROUND/AVG 40 PENTANE (C-5) 46 @ 9017 0 @ 9119 1.2 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drilled ahead from 8493' continuing to slide occasionally. High cuttings gas and connection gases at 9032', weighted up to 11 ppg. Continue drilling ahead while weighting up to 11.8, preparing to do a wiper trip. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR James Loft, Shane Barber DATE Aug 13, 2014 DEPTH 8493' PRESENT OPERATION Drilling ahead TIME 2400 YESTERDAY 7891' 24 HOUR FOOTAGE 602' CASING INFORMATION 7.625" @6841' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" HDBS EM65D 12401225 6x10 6493' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 402.0 @ 8177 0.3 @ 8074 88.4 25.18 FT/HR SURFACE TORQUE 17125 @ 8368 607 @ 7956 11864.8 2347.08 AMPS WEIGHT ON BIT 39 @ 8019 0 @ 8383 5.9 5.18 KLBS ROTARY RPM 116 @ 8030 1 @ 7956 79.1 50.91 RPM PUMP PRESSURE 3134 @ 8174 2552 @ 8020 2915.8 2659.9 PSI DRILLING MUD REPORT DEPTH 8506/7650 MW 10.3 VIS 58 PV 22 YP 23 FL 4.3 Gels 4/9/12 CL- 53000 FC 1/1 SOL 10.5 SD 0.1 OIL 2/88 MBT 5 pH 9.8 Ca+ 100 Alk 1.3 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 663 @ 8300 12 @ 7902 188.6 TRIP GAS CUTTING GAS 0 @ 8493 0 @ 8493 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 130805 @ 8300 2093 @ 7902 36666.6 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 8493 0 @ 8493 0.0 AVG PROPANE (C-3) 0 @ 8493 0 @ 8493 0.0 CURRENT BUTANE (C-4) 0 @ 8493 0 @ 8493 0.0 CURRENT BACKGROUND/AVG 50 PENTANE (C-5) 0 @ 8493 0 @ 8493 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Sand, tuffaceous sandstone, coal DAILY ACTIVITY SUMMARY Drilling ahead and sliding from 7891' to 8493'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR James Loft, Shane Barber DATE Aug 12, 2014 DEPTH 7891' PRESENT OPERATION Drilling ahead TIME 2400 YESTERDAY 7450' 24 HOUR FOOTAGE 441' CASING INFORMATION 7.625"@ 6481' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7809.13' 16.73 18.48 6977.13 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" HDBS EM65D 12401225 6x10 6493' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 171.9 @ 7668 1.1 @ 7506 70.4 19.7 FT/HR SURFACE TORQUE 16454 @ 7608 1741 @ 7773 10285.5 4291.02 AMPS WEIGHT ON BIT 22 @ 7883 0 @ 7863 4.0 5.66 KLBS ROTARY RPM 144 @ 7874 1 @ 7735 69.1 53.6 RPM PUMP PRESSURE 3187 @ 7729 1947 @ 7738 2825.1 2643.6 PSI DRILLING MUD REPORT DEPTH 7861/7026 MW 10.1 VIS 72 PV 25 YP 22 FL 4.4 Gels 4/10/13 CL- 53000 FC 1/1 SOL 10 SD 0.1 OIL 2/88 MBT 5 pH 10.1 Ca+ 100 Alk 1.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 683 @ 7669 18 @ 7817 173.1 TRIP GAS CUTTING GAS 0 @ 7891 0 @ 7891 0.0 WIPER GAS 61 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 124239 @ 7669 2800 @ 7627 30840.8 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 7891 0 @ 7891 0.0 AVG PROPANE (C-3) 0 @ 7891 0 @ 7891 0.0 CURRENT BUTANE (C-4) 0 @ 7891 0 @ 7891 0.0 CURRENT BACKGROUND/AVG 30 PENTANE (C-5) 0 @ 7891 0 @ 7891 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Tuffaceous claystone and siltstone. DAILY ACTIVITY SUMMARY Conducted a wiper trip at 7722' and then continued drilling and sliding. Pumped sweep at 7697' CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR James Loft, Doug Yessak DATE Aug 11, 2014 DEPTH 7450' PRESENT OPERATION Drilling ahead TIME 2400 YESTERDAY 6671' 24 HOUR FOOTAGE 779' CASING INFORMATION 7.625" @ 6481' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7437.42 23.09 16.13 6629.8 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" HDBS EM65D 12401225 6x10 6493' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 296.9 @ 7365 0.9 @ 6854 73.1 131.50458 FT/HR SURFACE TORQUE 16873 @ 7143 1673 @ 7352 10501.3 12113.63965 AMPS WEIGHT ON BIT 21 @ 6682 0 @ 7389 4.1 3.89000 KLBS ROTARY RPM 126 @ 7191 9 @ 7352 71.9 65.58000 RPM PUMP PRESSURE 2939 @ 7363 1692 @ 6681 2521.9 2795.52002 PSI DRILLING MUD REPORT DEPTH 6734/6021 MW 9.9 VIS 69 PV 20 YP 21 FL 4.6 Gels 4/9/14 CL- 55000 FC 1/1 SOL 6 SD 0.1 OIL 2/92 MBT 5.5 pH 10.1 Ca+ 140 Alk 1.7 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 553 @ 7426 7 @ 7045 119.1 TRIP GAS n/a CUTTING GAS 0 @ 7450 0 @ 7450 0.0 WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) 94186 @ 7426 1419 @ 7045 22900.9 CONNECTION GAS HIGH n/a ETHANE (C-2) 0 @ 7450 0 @ 7450 0.0 AVG n/a PROPANE (C-3) 0 @ 7450 0 @ 7450 0.0 CURRENT n/a BUTANE (C-4) 0 @ 7450 0 @ 7450 0.0 CURRENT BACKGROUND/AVG 140 PENTANE (C-5) 0 @ 7450 0 @ 7450 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Tuffaceous claystone, unconsolidated sand, tuffaceous siltstone grading into shale/low grade coal. DAILY ACTIVITY SUMMARY Continue drilling ahead to 7,450' pumping sweeps every 250'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR James Loft, Doug Yessak DATE Aug 10, 2014 DEPTH 6671' PRESENT OPERATION Drilling ahead TIME 2400 YESTERDAY 6493' 24 HOUR FOOTAGE 178' CASING INFORMATION 7.625" @ 6481' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6630.58' 31.29 17.36 5927.86' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" HDBS EM65D 12401225 6x10 6493' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 392.9 @ 6495 17.3 @ 6498 87.4 86.93938 FT/HR SURFACE TORQUE 11232 @ 6607 8122 @ 6519 8381.5 10522.45020 AMPS WEIGHT ON BIT 86 @ 6545 0 @ 6669 6.2 0.00000 KLBS ROTARY RPM 105 @ 6617 25 @ 6514 51.9 68.31000 RPM PUMP PRESSURE 2307 @ 6493 1335 @ 6495 2051.9 2082.66992 PSI DRILLING MUD REPORT DEPTH 6640/5938 MW 9.7 VIS 59 PV 18 YP 19 FL 5.4 Gels 5/7/10 CL- 50000 FC 1/1 SOL 6 SD 0.1 OIL trc/94 MBT 5.5 pH 9.2 Ca+ 160 Alk 0.4 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 266 @ 6545 0 @ 6505.00000 78.1 TRIP GAS N/A CUTTING GAS 0 @ 6671 0 @ 6671.00000 0.0 WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 53470 @ 6545 120 @ 6505 15538.7 CONNECTION GAS HIGH N/A ETHANE (C-2) 0 @ 6671 0 @ 6671 0.0 AVG N/A PROPANE (C-3) 0 @ 6671 0 @ 6671 0.0 CURRENT N/A BUTANE (C-4) 0 @ 6671 0 @ 6671 0.0 CURRENT BACKGROUND/AVG 40 PENTANE (C-5) 0 @ 6671 0 @ 6671 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Tuffaceous siltstone, tuffaceous claystone, unconsolidated sand DAILY ACTIVITY SUMMARY PJSM and M/U BHA and RIH. Shallow test BHA and continue RIH. Perform rig service while RIH til tagging cement @ 6389'. Drill out cement to 6493'. Slide from 6493' to 6513' and displace mud to 9.7ppg. FIT to 13.5ppg EMW, 1150 PSI chart recorded. Continue drilling from 6513' to 6671'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR James Loft, Doug Yessak DATE Aug 09, 2014 DEPTH 6493' PRESENT OPERATION Test BOPE TIME 16:18:56 YESTERDAY 6493' 24 HOUR FOOTAGE 0' CASING INFORMATION 10.75"@1595' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9 VIS 50 PV 8 YP 12 FL 9.4 Gels 3/6/9 CL- 29000 FC 1/- SOL 4 SD 0.25 OIL trc/96 MBT 4 pH 8.8 Ca+ 120 Alk 0.5 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finish BOP testing and cement bond logging. Preparing to test casing to 3500 psi for 30 minutes. Kla Shield mud is being transferred back into the active system and treated for use on the next well interval. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3030.00` REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR James Loft, Doug Yessak DATE Aug 08, 2014 DEPTH 6493' PRESENT OPERATION Cement intermediate TIME 2400 YESTERDAY 6493' 24 HOUR FOOTAGE 0' CASING INFORMATION 10.75"@1565' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" HDBS MM65PDC 12406875 1063' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 6493/5810 MW 9 VIS 50 PV 8 YP 12 FL 9.4 Gels 3/6/9 CL- 29000 FC 1/- SOL 4 SD 0.25 OIL trc/96 MBT 4 pH 8.8 Ca+ 120 Alk 0.5 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Build LCM pill by transferring 12.1 from attigan tank and condition to 9.1 ppg. Pumped 150 bbl of 100 ppb LCM followed by 70 bbls of 50 ppb and chased with 9.1 ppg mud when pill exited shoe. Regained circulation and built 25 bbl LCM pill @ 105 ppb. Slowly increased pump rate from 1.5 to 2 BPM. Circulate out LCM pill and cement. Pumped two 40 bbl seal spacers, 163 bbl of 10.5 ppg Lead followed by 29 bbl of 13.5 ppg Tail. While cementing, 111 bbl mud was lost to formation. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3030.00 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR James Loft, Doug Yessak DATE Aug 07, 2014 DEPTH 6493' PRESENT OPERATION Treat lost circulation TIME 2400 YESTERDAY 6493' 24 HOUR FOOTAGE 0' CASING INFORMATION 10.75" @ 1565' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" HDBS MM65 PDC 12406875 6 x 13 1063' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 6493/5810 MW 9.3 VIS 120 PV 20 YP 28 FL 6.2 Gels 6/10/16 CL- 37000 FC 1/- SOL 6 SD 0.1 OIL trc/94 MBT 6 pH 9 Ca+ 120 Alk 0.7 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Treating loss circulation by building additional LCM pill. Watering back and reconditioning mud moved from storage to 9.1 ppg for upcoming cement job. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2148.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR Mike Leslie, Doug Yessak DATE Aug 06, 2014 DEPTH 6493' PRESENT OPERATION Casing TIME 2400 YESTERDAY 6493' 24 HOUR FOOTAGE 0' CASING INFORMATION 10.75" @ 1565' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" HDBS MM65 PDC 12406875 6 x 13 1063' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Pick up casing and RIH, at shoe fill casing and circulate 1.5x hole volume. Run casing to 6492', tagged fill at 6473'. Lost returns at 5150' pumped at 5320 and could not establish return, 210 bbl total loss. Build LCM pill and prepare to pump pill. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2148.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR Mike Leslie, Doug Yessak DATE Aug 05, 2014 DEPTH 6493' PRESENT OPERATION Testing BOP rams TIME 2400 YESTERDAY 6493' 24 HOUR FOOTAGE 0' CASING INFORMATION 10.75" @1565' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" HDBS MM65 PDC 12406857 6 x 13' 1603' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 6493/5809 MW 9.7 VIS 69 PV 23 YP 25 FL 4.9 Gels 6/13/20 CL- 49500 FC 1/1 SOL 9 SD trc OIL 1/90 MBT 11 pH 9.5 Ca+ 240 Alk 0.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 369 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Lay down BHA #2 and pick up #3 for clean out run to bottom. TIH to 1053' and cut 95' of drill line. RIH to 6240' and safely ream to 6493'. Pumped high vis sweep and circulated out. POOH on elevators to survace. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2148.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR Mike Leslie, Doug Yessak DATE Aug 04, 2014 DEPTH 6493' PRESENT OPERATION POOH TIME 2400 YESTERDAY 6493' 24 HOUR FOOTAGE 0' CASING INFORMATION 10.75" @ 1565' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" HDBS MM65 PDC 12406857 6 x 13 1603' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 6943/5809 MW 9.7 VIS 71 PV 24 YP 25 FL 9.2 Gels 6/13/20 CL- 51000 FC 1/1 SOL 9 SD trc OIL 1/90 MBT 10 pH 9.6 Ca+ 240 Alk 0.9 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Back reamed to 2,750' and POOH on elevators to 715' CANRIG PERSONNEL ON BOARD 2 DAILY COST $2148.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR Mike Leslie, Doug Yessak DATE Aug 03, 2014 DEPTH 6493.000' PRESENT OPERATION Pulling out of hole TIME 2400 YESTERDAY 5551' 24 HOUR FOOTAGE 942' CASING INFORMATION 10.75" @ 1565' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6449.72' 29.24 15.73 5771.8 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" HDBS MM65 PDC 12406857 6 x 13 1603' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 597.1 @ 5742 1.1 @ 5952 160.0 138.98202 FT/HR SURFACE TORQUE 12504 @ 5896 1473 @ 5906 9310.7 10178.32000 AMPS WEIGHT ON BIT 15 @ 6335 3 @ 5873 10.0 11.40000 KLBS ROTARY RPM 94 @ 6364 5 @ 5906 54.5 58.32000 RPM PUMP PRESSURE 2479 @ 6369 1503 @ 5866 2232.2 2307.19000 PSI DRILLING MUD REPORT DEPTH 6493/5809 MW 9.7 VIS 67 PV 19 YP 30 FL 5 Gels 6/14/19 CL- 48500 FC 1/1 SOL 8 SD 0.25 OIL trc/92 MBT 10.5 pH 9.6 Ca+ 240 Alk 1.1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 610 @ 5551 6 @ 5555 152.3 TRIP GAS CUTTING GAS 0 @ 6493 0 @ 6493 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 126055 @ 5551 1275 @ 5555 30784.1 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 6493 0 @ 6493 0.0 AVG PROPANE (C-3) 0 @ 6493 0 @ 6493 0.0 CURRENT BUTANE (C-4) 0 @ 6493 0 @ 6493 0.0 CURRENT BACKGROUND/AVG 10 PENTANE (C-5) 0 @ 6493 0 @ 6493 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drilled to TD at 6493' and pumped high vis sweep. Circulated bottoms up and pumped final survey. Pulling out of hole for wiper trip. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2148.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR Mike Leslie, Doug Yessak DATE Aug 02, 2014 DEPTH 5551' PRESENT OPERATION Running in hole TIME 2400 YESTERDAY 4616' 24 HOUR FOOTAGE 935' CASING INFORMATION 10.75" @ 1565' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5508' 30.62 18.18 4956' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" HDBS MM65 PDC 12406857 6 x 13 1603' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1026.6 @ 4687 1.2 @ 5489 192.0 154.46367 FT/HR SURFACE TORQUE 15041 @ 4903 1493 @ 5437 8236.7 8779.64000 AMPS WEIGHT ON BIT 18 @ 4903 1 @ 4687 8.3 7.47000 KLBS ROTARY RPM 162 @ 5453 1 @ 5437 54.2 55.31000 RPM PUMP PRESSURE 2143 @ 5467 1550 @ 4682 1942.6 2005.92000 PSI DRILLING MUD REPORT DEPTH MW 9.5 VIS 61 PV 18 YP 28 FL 5.6 Gels 7/15/21 CL- 49000 FC 1/1 SOL 7 SD 0.3 OIL trc/93 MBT 8 pH 9.9 Ca+ 160 Alk 1.3 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1097 @ 5532 13 @ 4890 200.5 TRIP GAS CUTTING GAS 0 @ 5551 0 @ 5551 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 220258 @ 5532 2551 @ 4890 39704.1 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 5551 0 @ 5551 0.0 AVG PROPANE (C-3) 0 @ 5551 0 @ 5551 0.0 CURRENT BUTANE (C-4) 0 @ 5551 0 @ 5551 0.0 CURRENT BACKGROUND/AVG 1 PENTANE (C-5) 0 @ 5551 0 @ 5551 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drilled to 5551', high gas of 1,096u. Pumped high vis sweep and began wiper trip. Hole was tight from 5235' to 2750', pumped out and back reamed through this section. POOH to casing shoe and performed rig service. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2148.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR Mike Leslie, Doug Yessak DATE Aug 01, 2014 DEPTH 4616' PRESENT OPERATION Drilling ahead TIME 23:44:30 YESTERDAY 3449' 24 HOUR FOOTAGE 1167' CASING INFORMATION 10.75" @ 1565' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4578.89' 30.84 16.67 4155.36' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" HDBS MM65 PDC 12406857 6 x 13 1603' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1192.2 @ 3654 1.7 @ 4485 269.4 193.6 FT/HR SURFACE TORQUE 13525 @ 4542 296 @ 4020 6962.8 7641.2 AMPS WEIGHT ON BIT 53 @ 4249 0 @ 3845 6.8 6.6 KLBS ROTARY RPM 75 @ 4222 0 @ 4020 53.0 50.4 RPM PUMP PRESSURE 1830 @ 4377 1275 @ 4022 1590.7 1744.8 PSI DRILLING MUD REPORT DEPTH 4680/4249 MW 9.4 VIS 70 PV 17 YP 28 FL 5.4 Gels 7/14/20 CL- 47000 FC 1/1 SOL 8 SD 025 OIL trc/92 MBT 6 pH 9.8 Ca+ 480 Alk 1.28 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 296 @ 4538 2 @ 3691 115.9 TRIP GAS CUTTING GAS 0 @ 4616 0 @ 4616 0.0 WIPER GAS 125 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 59295 @ 3983 637 @ 3691 21782.8 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 4616 0 @ 4616 0.0 AVG PROPANE (C-3) 0 @ 4616 0 @ 4616 0.0 CURRENT BUTANE (C-4) 0 @ 4616 0 @ 4616 0.0 CURRENT BACKGROUND/AVG 120 PENTANE (C-5) 0 @ 4616 0 @ 4616 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Pumped sweeps at 2949', 3175', 3450', 3690' and 3940'. Drilled to 4248' and pumped a high VIS sweep and POOH for short trip to shoe. Back reemed 3744-3733, 3427-3365, 3250-3185. Hole was tight at 3640-3572, 3486 and 3284. Performed rig service and RIH to 4200' and sweep with high VIS. Continue to drill ahead. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2148.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR Mike Leslie, Doug Yessak DATE Jul 31, 2014 DEPTH 3449' PRESENT OPERATION Drilling ahead TIME 23:42:33 YESTERDAY 1696' 24 HOUR FOOTAGE 1753' CASING INFORMATION 10.75" @ 1595' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3400' 31 14.5 3137 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" HDBS MM65 PDC 12406857 6 x 13 1603' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1757.3 @ 2091 1.8 @ 2752 250.8 237.24062 FT/HR SURFACE TORQUE 12420 @ 3101 1491 @ 2525 4770.3 6392.00977 AMPS WEIGHT ON BIT 46 @ 3442 0 @ 2013 4.4 3.20000 KLBS ROTARY RPM 77 @ 2642 3 @ 2525 48.4 70.40000 RPM PUMP PRESSURE 1632 @ 3444 940 @ 1705 1239.0 1482.97998 PSI DRILLING MUD REPORT DEPTH 3503/3242 MW 9.2 VIS 70 PV 15 YP 22 FL 5.2 Gels 7/12/18 CL- 50000 FC 1/1 SOL 6 SD 0.35 OIL trc/94 MBT 6 pH 9.5 Ca+ 240 Alk 0.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 63 @ 2116' 0 @ 2371.00000 28.7 TRIP GAS CUTTING GAS 0 @ 3449' 0 @ 3449.00000 0.0 WIPER GAS 9 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 12888 @ 2116 53 @ 2371 5637.9 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 3449 0 @ 3449 0.0 AVG PROPANE (C-3) 0 @ 3449 0 @ 3449 0.0 CURRENT 48 BUTANE (C-4) 0 @ 3449 0 @ 3449 0.0 CURRENT BACKGROUND/AVG 25 PENTANE (C-5) 0 @ 3449 0 @ 3449 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Sand DAILY ACTIVITY SUMMARY Pumped sweep at 2500' and drilled to 2697'. Pulled out of hole to 1026' for wiper trip. P/U 50 single joints of drill pipe and TIH. Continue drilling ahead, sliding and rotating CANRIG PERSONNEL ON BOARD 2 DAILY COST $2148.50 REPORT BY Trey Thrailkill Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 42-06Y REPORT FOR Mike Leslie, Doug Yessak DATE Jul 30, 2014 DEPTH 1696' PRESENT OPERATION Drilling formation TIME 23:53:13 YESTERDAY 1605' 24 HOUR FOOTAGE 91' CASING INFORMATION 10.75" @ 1595' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1663.12 21.94 17.64 1633.38 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" HDBS MM65 PDC 12406857 6 x 13 1603' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 343.6 @ 1648 18.9 @ 1643 208.0 185.43668 FT/HR SURFACE TORQUE 5444 @ 1658 3818 @ 1617 3114.7 4176.45020 AMPS WEIGHT ON BIT 39 @ 1643 1 @ 1680 4.1 1.88000 KLBS ROTARY RPM 53 @ 1684 30 @ 1623 30.7 49.69000 RPM PUMP PRESSURE 1152 @ 1613 970 @ 1624 1045.5 1012.22998 PSI DRILLING MUD REPORT DEPTH 1704/1687 MW 9 VIS 63 PV 14 YP 33 FL 5.8 Gels 7/15/17 CL- 43000 FC 1/1 SOL 4 SD 0.1 OIL trc/96 MBT 6 pH 9.9 Ca+ 120 Alk 1.2 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 37 @ 1667 0 @ 1628 16.3 TRIP GAS CUTTING GAS 0 @ 1696 0 @ 1696 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 6619 @ 1668 2854 @ 1690 1585.5 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 1696 0 @ 1696 0.0 AVG PROPANE (C-3) 0 @ 1696 0 @ 1696 0.0 CURRENT 5 BUTANE (C-4) 0 @ 1696 0 @ 1696 0.0 CURRENT BACKGROUND/AVG 15 PENTANE (C-5) 0 @ 1696 0 @ 1696 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Picked up BHA #2 and shallow tested it. RIH to 1508' and dilled cement/float equipment to 1603' with shoe att 1591' to 1594'. Drill 20' of rat hole and perform FIT; EMW of 12 ppg successful. Continue drilling from 1623'. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2150 REPORT BY Trey Thrailkill