The URL can be used to link to this page

Home My WebLink About217-143Kaitlyn 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: 4/20/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL GP ST 24-13RD2 (PTD 217-143) CIBP 3/29/2022 Please include current contact information if different from above. PTD:217-143 T36589 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.11 11:53:59 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 5/09/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL GP ST 24-13RD2 (PTD 217-143) Perf 4/17/2022 CBL 04/17/2022 Please include current contact information if different from above. PTD:217-143 T36577 T36578 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.10 09:46:19 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brad Gathman - (C) To:Regg, James B (OGC);DOA AOGCC Prudhoe Bay;Brooks, Phoebe L (OGC) Cc:Juanita Lovett;Donna Ambruz Subject:BOPE Test Report GP 24-13RD2 4-12-22 Date:Saturday, April 16, 2022 1:13:56 PM Attachments:BOPE Test Report GP 24-13RD2 4-12-22.xlsx EXTERNAL AOGCC Inspection Form Confirmation Email.msg EXTERNAL RE AOGCC Test Witness Notification Request BOPE SLB Coiled Tubing Unit 1 Granite Point Platform 24-13RD2.msg The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. *UDQLWH3W6WDWH5' 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:1 DATE: 4/12/22 Rig Rep.: Rig Phone: 907-659-2434 Operator: Op. Phone:907-777-8300 Rep.: E-Mail Well Name: PTD #22171430 Sundry #322-127 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:NA Valves:250/3500 MASP:2708 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig NA Lower Kelly 0NA PTD On Location P Hazard Sec.NA Ball Type 0NA Standing Order Posted NA Misc.NA Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75" top load P Trip Tank NA NA Annular Preventer 0 NA NA Pit Level Indicators NA NA #1 Rams 1 1.75 B/S P Flow Indicator NA NA #2 Rams 1 1.75 B/S P Meth Gas Detector NA NA #3 Rams 1 1.75 Slips P H2S Gas Detector NA NA #4 Rams 1 1.75 Pipes P MS Misc 0NA #5 Rams 0 NA NA #6 Rams 0 NA NA Quantity Test Result Choke Ln. Valves 1 2x2 FMC P Inside Reel valves 1P HCR Valves 0 NA NA Kill Line Valves 2 2x2 FMC P Check Valve 1 2" 1502 P ACCUMULATOR SYSTEM: BOP Misc 3 EQ PORTS P Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1550 P Quantity Test Result 200 psi Attained (sec)20 P No. Valves 5P Full Pressure Attained (sec)76 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 0NA Nitgn. Bottles # & psi (Avg.): NA NA CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:3.0 Hours Repair or replacement of equipment will be made within NA days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4/9/22 19:51 Waived By Test Start Date/Time:4/12/2022 11:30 (date) (time)Witness Test Finish Date/Time:4/12/2022 14:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Schlumberger A push/pull test was conducted on the slip rams. Granite Pt Platform Bryson Lowe Hilcorp Brad Gathman Granite Pt State 24-13RD2 Test Pressure (psi): brad.gathman@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0412_BOP_GranitePt_State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y Samantha Carlisle at 7:17 am, Mar 14, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH '65 6HQG 6&07 WR $2*&& IRU UHYLHZ EHIRUH SHUIRUDWLQJ 3URYLGH KUV QRWLFH IRU $2*&& ZLWQHVV RI SRVWSHUI 0,7,$ WR SVL %-0 &7 %23 WHVW WR SVL ; 6)' ; -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.03.22 13:16:50 -08'00' RBDMS SJC 033022 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗'WϮϰͲϭϯZϮ tĞůůEĂŵĞ͗'ZE/dWd^dϮϰͲϭϯZϮW/EƵŵďĞƌ͗ϱϬͲϳϯϯͲϮϬϬϴϬͲϬϮ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗/ŶũĞĐƚŽƌ>ĞŐ͗>ĞŐηϯ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗DĂƌĐŚϮϭ͕ϮϬϮϮZŝŐ͗^>ͬ>ͬdh ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ϰϬϯĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗:ƵĂŶŝƚĂ>ŽǀĞƚƚ;ϴϯϯϮͿWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϭϳͲϭϰϯ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗<ĂƚŚĞƌŝŶĞK͛ŽŶŶŽƌϵϬϳͲϳϳϳͲϴϯϳϲϮϭϰͲϲϴϰͲϳϰϬϬ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗:ĂŬĞ&ůŽƌĂϵϬϳͲϳϳϳͲϴϰϰϮϳϮϬͲϵϴϴͲϱϯϳϱ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ ϮϲϭϱƉƐŝΛϭϬϰϭϴ͛ds ^/,WƐƵƌǀĞǇϮͬϮϭ DĂǆŝŵƵŵǆƉĞĐƚĞĚ,W͗ ϯϲϴϭƉƐŝΛϵϳϯϮ͛ds DĂǆŝŵƵŵWŽƚĞŶƚŝĂů^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗ ϮϳϬϴƉƐŝ Ϭ͘ϭƉƐŝͬĨƚŐƌĂĚŝĞŶƚƉĞƌϮϬϮϱ͘ϮϴϬ;ďͿ;ϰͿ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ 'WϮϰͲϭϯZϮŝƐĂĐƵƌƌĞŶƚůǇĂǁĂƚĞƌŝŶũĞĐƚŽƌŝŶƚŚĞϳƐĂŶĚƐ͘/ƚǁĂƐĐŽŶǀĞƌƚĞĚƚŽĂŶŝŶũĞĐƚŽƌŝŶϮϬϭϵ͘dŚĞ ǁĞůůŝŶũĞĐƚĞĚĨůƵŝĚĨŽƌŵŽƐƚŽĨϮϬϮϬ͕ďƵƚŝŶũĞĐƚŝŽŶƌĂƚĞƐďĞĐĂŵĞƵŶƐƵƐƚĂŝŶĂďůĞ;ϰϬϬϬƉƐŝͿ͘dŚĞǁĞůůǁĂƐ ƐŚƵƚŝŶĂŶĚŚĂƐďĞĞŶƐŚƵƚŝŶƐŝŶĐĞKĐƚŽďĞƌϮϬϮϬ͘dŚĞŽďũĞĐƚŝǀĞŽĨƚŚŝƐƉƌŽŐƌĂŵŝƐƚŽĐŽŶǀĞƌƚƚŚŝƐǁĞůůďĂĐŬ ŝŶƚŽĂŐĂƐůŝĨƚĞĚƉƌŽĚƵĐĞƌďǇƉůƵŐŐŝŶŐŽĨĨƚŚĞϳƐĂŶĚƐ͕ƉůĂĐŝŶŐĂĐĞŵĞŶƚƉĂĐŬĞƌŝŶƚŚĞǁĞůůĂŶĚĂĚĚŝŶŐϲ ƉĞƌĨŽƌĂƚŝŽŶƐ͘ ƚŽƉďŽƚƚŽŵƐŝǌĞ/ďďůƐͬĨƚĨƚǀŽůƵŵĞ ϮͲϳͬϴΗƚďŐϬϭϬϯϵϱϮͲϳͬϴΗϮ͘ϰϰϭϬ͘ϬϬϲϭϬϯϵϱϲϮ͘ϯϳ ϮͲϯͬϴΗƚďŐϭϬϯϵϱϭϭϰϱϯϮͲϯͬϴΗϭ͘ϵϵϱϬ͘ϬϬϰϭϬϱϴϰ͘ϮϯϮ ϮͲϳͬϴΗƚďŐǆϳΗ ĐĂƐŝŶŐϬϭϬϯϵϱ ϮͲϳͬϴΗϲ͘ϱη ǆϳΗϮϲηϲ͘ϭϴϰϬ͘ϬϮϵϭϮϭϬϯϵϱϯϬϮ͘ϳϬϯϰ ϮͲϯͬϴΗƚďŐǆϳΗ ĐĂƐŝŶŐϭϬϯϵϱϭϬϰϰϵ ϮͲϯͬϴΗϰ͘ϳη ǆϳΗϮϲηϲ͘ϭϴϰϬ͘Ϭϯϭϲϳϱϰϭ͘ϳϭϬϭϴϳ ϮͲϯͬϴΗƚďŐǆϱΗ ĐĂƐŝŶŐϭϬϰϰϵϭϭϯϰϵ ϮͲϯͬϴΗϰ͘ϳη ǆϱΗϭϱηϰ͘ϰϬϴϬ͘ϬϭϯϯϵϲϵϬϬϭϮ͘Ϭϱϲϰ '>sη ϭϬ WƌŽĐĞĚƵƌĞ͗ ϭ͘Zh^>ƉƌĞƐƐƵƌĞƚĞƐƚůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϮϬϬϬƉƐŝŚŝŐŚ Ă͘^Ğƚ/WĂƚцϭϭϯϳϬ͛D ď͘WƌĞƐƐƵƌĞƚĞƐƚƚƵďŝŶŐƚŽϮϬϬϬƉƐŝ;ĞŶƐƵƌĞ'>sƐΘddWĂƌĞŚŽůĚŝŶŐͿ Đ͘WƵůůůŽǁĞƐƚ'>sΘŝŶƐƚĂůůĐŝƌĐƐƵďĂƚцϭϭϯϰϵ͛D Ϯ͘WƵŵƉ&/tŝŶƚŽŝŶŶĞƌĂŶŶƵůƵƐĂŶĚƚƵďŝŶŐ͕ƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽƉƌŽĚƵĐƚŝŽŶ͘ ϯ͘D/ZhĐŽŝůƚƵďŝŶŐ ϰ͘EhKWĂŶĚƚĞƐƚƚŽϮϱϬƉƐŝůŽǁͬϯϱϬϬƉƐŝŚŝŐŚ͘ Ă͘;EŽƚĞ͗EŽƚŝĨǇK'ϰϴŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚƚŽĂůůŽǁƚŚĞŵƚŽǁŝƚŶĞƐƐƚĞƐƚͿ͘ ϱ͘^ĞƚĐĞŵĞŶƚƌĞƚĂŝŶĞƌΛцϭϭϯϯϬ͛D ϲ͘Z/,͕ƐƚŝŶŐŝŶƚŽĐĞŵĞŶƚƌĞƚĂŝŶĞƌĞƐƚĂďůŝƐŚŝŶŐƌĞƚƵƌŶƐƵƉƚŚĞ/ĂŶĚƉƵŵƉƚŚĞĨŽůůŽǁŝŶŐ ƐĐŚĞĚƵůĞ;ƚĂƌŐĞƚdKŝŶƚŚĞ/ŝƐϵϴϬϬ͛DͿ͗ Ă͘ϭϬďďůƐƐƵƌĨĂĐƚĂŶƚǁĂƐŚ ď͘ϮďďůĨƌĞƐŚǁĂƚĞƌ;&tͿƐƉĂĐĞƌ tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗'WϮϰͲϭϯZϮ Đ͘ϮϲďďůƐĐůĂƐƐ'ĐĞŵĞŶƚ Ě͘Ϯďďů&tƐƉĂĐĞƌ Ğ͘dǀŽůƵŵĞŽĨĐĞŵĞŶƚĚŝƐƉůĂĐĞŵĞŶƚ ϳ͘tŝƚŚϭďďůŽĨĐĞŵĞŶƚƌĞŵĂŝŶŝŶŐŝŶƚŚĞĐŽŝů͕ƵŶƐƚŝŶŐĨƌŽŵƌĞƚĂŝŶĞƌĂŶĚůĂǇƚŚĞůĂƐƚϭďďůŽĨ ĐĞŵĞŶƚŽŶƚŚĞƌĞƚĂŝŶĞƌ͘EŽƚĞƉƌĞƐƐƵƌĞƐĂĨƚĞƌƵŶƐƚŝŶŐŝŶŐĨƌŽŵƌĞƚĂŝŶĞƌ͘ŽŶŽƚďůĞĞĚĂŶǇ ƉƌĞƐƐƵƌĞ͘ŶƐƵƌĞƌĞƚĂŝŶĞƌŝƐŚŽůĚŝŶŐƉƌĞƐƐƵƌĞ͕ĂŶĚƚŚĞŶĐŝƌĐͬƌĞǀĞƌĐĞĐŝƌĐĐĞŵĞŶƚ͘ ϴ͘ŝƌĐƵůĂƚĞƚďŐƚŽĚŝĞƐĞůĂŶĚWKK,ŵĂŝŶƚĂŝŶŝŶŐĨƵůůŚŽůĞ͘ ϵ͘ZDKdh ϭϬ͘Zh>ƉƌĞƐƐƵƌĞƚĞƐƚůƵďƌŝĐĂƚŽƌƚŽϮϱϬůŽǁͬϮϳϱϬƉƐŝŚŝŐŚ͘ Ă͘>ŽŐ^DdĨƌŽŵƉĂĐŬĞƌƚŽцϴϬϬϬ͛DƚŽŝĚĞŶƚŝĨǇdK͘ ď͘ĚĚƉĞƌĨŽƌĂƚŝŽŶƐƉĞƌƉƌŽĐĞĚƵƌĞ ϭϭ͘D/d/ƚŽϮϳϱϬƉƐŝ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘tĞůů^ĐŚĞŵĂƚŝĐƵƌƌĞŶƚ Ϯ͘tĞůů^ĐŚĞŵĂƚŝĐWƌŽƉŽƐĞĚ ϯ͘tĞůůŚĞĂĚ^ĐŚĞŵĂƚŝĐƵƌƌĞŶƚ ϰ͘ŽŝůdƵďŝŶŐKWƌĂǁŝŶŐ ϱ͘&ůƵŝĚ&ůŽǁŝĂŐƌĂŵƐ ϲ͘ZtK^ƵŶĚƌǇZĞǀŝƐŝŽŶŚĂŶŐĞ&Žƌŵ 6HQG 6&07 WR $2*&& IRU UHYLHZ EHIRUH SHUIRUDWLQJ EMP 3URYLGH KUV QRWLFH IRU $2*&& WR ZLWQHVV EMP D/d/ƚŽϮϳϱϬƉƐŝ hƉĚĂƚĞĚǇ͗:>>ϬϳͬϭϴͬϮϬϭϵ ^,Dd/ 'ƌĂŶŝƚĞWŽŝŶƚWůĂƚĨŽƌŵ tĞůů͗'ƌĂŶŝƚĞWƚ^ƚϮϰͲϭϯZϮ Wd͗ϮϭϳͲϭϰϯ W/͗ϱϬͲϳϯϯͲϮϬϬϴϬͲϬϮ Wd͗ ϭϮ͕ϴϵϯ͚ d͗ ϭϯ͕ϰϵϯ͛ Ϯϲ͟ ϳ͟ DĂǆ ,ŽůĞ ŶŐůĞ с ϭϬϬ͘ϯϮȗ Ăƚ ϭϯ͕ϰϵϯ͛D & 6DQG dKΛ ϭϭ͕Ϭϲϱ͛ ´ '9&ROODU ¶ &DVLQJ/HDN a¶ ϭϯͲϯͬϴ͟ ϵͲϱͬϴ͟ dKΛϳ͕ϵϳϬ͛ ^ƋƵĞĞǌĞWĞƌĨƐ ϭϬ͕ϱϬϬ͛ͲϭϬ͕ϱϬϰ͛ dK Λ ϴ͕ϵϯϬ͛ ϭϴ͟ ´7LHEDFN 6HDOV#¶ ϯϯ͟ ; 5.%WR7XELQJ+HDG¶ĂƐŝŶŐĞƚĂŝů͗ ^/ td 'Z KEE / dKW dD͘ ϯϯ͟ ^ƚƌƵĐƚƵƌĂů ^ƵƌĨ ϮϮϵ͛ Ϯϲ͟ ŽŶĚƵĐƚŽƌ ^ƵƌĨ Ϯϵϰ͛ ϭϴ͟ ϳϬ͘ϱϵ sĞŶƚƵƌĂ ^ƵƌĨ ϱϵϮ͛ ϭϯͲϯͬϴ͟ ϲϭ͘Ϭ :Ͳϱϱ Ƶƚƚ͘>dΘ ϭϮ͘ϱϭϱ ^ƵƌĨ ϯ͕ϵϲϬ͛ ϵͲϱͬϴ͟ϰϬΘ ϰϯ͘ϱ EͲϴϬΘ^Ͳϵϱ Ƶƚƚ͘>dΘ ϴ͘ϳϱϱ ^ƵƌĨ ϴ͕ϭϯϬ͛;dKtͿ ϳ͟dŝĞďĂĐŬ Ϯϲ >ͲϴϬ tͬ ϲ͘ϭϴϰ͟ ^ƵƌĨ ϱ͕ϴϯϬ͛ ϳ͟ Ϯϲ >ͲϴϬ tͬ ϲ͘ϭϴϰ͟ ϱ͕ϴϮϭ͛ ϭϬ͕ϴϵϯ͛ ϱ͟ ϭϱ >ͲϴϬ d;< ĐŽŶǀĞƌƚŝďůĞͿ ϰ͘ϰϬϴ͟ ϭϬ͕ϰϰϵ͛ ϭϯ͕ϬϮϯ͛ dƵďŝŶŐĞƚĂŝů͗ ϮͲϳͬϴ͟ ϲ͘ϱ >ͲϴϬ ϴƌŶĚh Ϯ͘ϰϰϭ͟ ^ƵƌĨ ϭϬ͕ϯϵϱ͛ ϮͲϯͬϴ͟ ϰ͘ϳ >ͲϴϬ ϴƌŶĚh ϭ͘ϵϵϱ͟ ϭϬ͕ϯϵϱ͛ ϭϭ͕ϰϱϯ͛ WZ&KZd/KEd/> ŽŶĞ dŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ &d ^W& ĂƚĞ ^ƚĂƚƵƐ ŽŵŵĞŶƚ Ͳϳ ϭϭ͕ϱϱϬ͛ ϭϮ͕ϴϭϬ͛ ϭϬ͕ϰϭϴ͛ ϭϬ͕ϲϵϲ͛ ϭ͕ϮϲϬ͛ ϲ ϭϮͬϮϯͬϭϳ KƉĞŶ :t>Zzd/> EŽ ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ / K /ƚĞŵ ϱϬ͘ϭϬ͛ ϱϬ͘ϭϬ͛ dƵďŝŶŐ,ĂŶŐĞƌ ϭ ϯϳϯ͛ ϯϳϯ͛ Ϯ͘ϯϭϯ͟ ϰ͘ϵϭ͟ ^^^s,ĂůůŝďƵƌƚŽŶEdZ^s Ϯ Ϯ͕ϱϰϰ͛ Ϯ͕ϰϵϵ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϭW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϰ͕ϱϯϬ͛ ϰ͕ϯϴϲ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϮW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϲ͕ϬϱϬ͛ ϱ͕ϴϱϱ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϯW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϳ͕ϭϯϮ͛ ϲ͕ϵϭϱ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϰW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϳ͕ϵϬϬ͛ ϳ͕ϲϱϭ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϱW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϴ͕ϱϰϮ͛ ϴ͕ϭϴϬ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϲW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϵ͕ϬϵϬ͛ ϴ͕ϳϰϮ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϳW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϵ͕ϳϬϭ͛ ϵ͕Ϯϰϳ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϴW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϭϬ͕ϯϰϯ͛ ϵ͕ϳϱϮ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϵW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϯ ϭϬ͕ϯϵϰ͛ ϵ͕ϳϴϵ͛ ϭ͘ϵϴϯ͟ ϯ͘ϲϴϴ͟ ϮͲϳͬϴ͟ǆϮͲϯͬϴ͟ƌŽƐƐŽǀĞƌ ϰ ϭϭ͕ϯϰϵ͛ ϭϬ͕ϯϯϵ͛ ϭ͘ϵϵϱ͟ ϯ͘ϲϮϱ͟ '>DηϭϬ'>DyͲϭ,WDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϱ ϭϭ͕ϯϵϴ͛ ϭϬ͕ϯϱϵ͛ ϭ͘ϵϰϬ͟ ϰ͘ϭϮϱ͟ WĂĐŬĞƌͲDĂƉKŝůdŽŽůD&,,ǇĚƌĂƵůŝĐ^ĞƚZĞƚƌŝĞǀĂďůĞǁͬϯϬ<^ŚĞĂƌ ϲ ϭϭ͕ϰϰϲ͛ ϭϬ͕ϯϳϵ͛ ϭ͘ϴϳϱ͟ ϯ͘Ϭϲϯ͟ yEŝƉƉůĞ ϳ ϭϭ͕ϰϱϯ͛ ϭϬ͕ϯϴϭ͛ Ϯ͘ϯϬϬ͟ ϯ͘ϬϬ͟ t>' hƉĚĂƚĞĚǇ͗<'KϯͬϯͬϮϮ WZKWK^ 'ƌĂŶŝƚĞWŽŝŶƚWůĂƚĨŽƌŵ tĞůů͗'ƌĂŶŝƚĞWƚ^ƚϮϰͲϭϯZϮ Wd͗ϮϭϳͲϭϰϯ W/͗ϱϬͲϳϯϯͲϮϬϬϴϬͲϬϮ Wd͗ ϭϮ͕ϴϵϯ͚ d͗ ϭϯ͕ϰϵϯ͛ Ϯϲ͟ ϳ͟ DĂǆ,ŽůĞŶŐůĞс ϭϬϬ͘ϯϮȗ Ăƚϭϯ͕ϰϵϯ͛D & 6DQG dKΛϭϭ͕Ϭϲϱ͛ ´ '9&ROODU ¶ &DVLQJ/HDN a¶ ϭϯͲϯͬϴ͟ ϵͲϱͬϴ͟ dKΛϳ͕ϵϳϬ͛ ^ƋƵĞĞǌĞWĞƌĨƐ ϭϬ͕ϱϬϬ͛ͲϭϬ͕ϱϬϰ͛ dKΛϴ͕ϵϯϬ͛ ϭϴ͟ ´7LHEDFN 6HDOV#¶ ϯϯ͟ dKΛϵϴϬϬ͛ & 6DQG 5.%WR7XELQJ+HDG ¶ ; ĂƐŝŶŐĞƚĂŝů͗ ^/ td 'Z KEE / dKW dD͘ ϯϯ͟ ^ƚƌƵĐƚƵƌĂů ^ƵƌĨ ϮϮϵ͛ Ϯϲ͟ ŽŶĚƵĐƚŽƌ ^ƵƌĨ Ϯϵϰ͛ ϭϴ͟ ϳϬ͘ϱϵ sĞŶƚƵƌĂ ^ƵƌĨ ϱϵϮ͛ ϭϯͲϯͬϴ͟ ϲϭ͘Ϭ :Ͳϱϱ Ƶƚƚ͘>dΘ ϭϮ͘ϱϭϱ ^ƵƌĨ ϯ͕ϵϲϬ͛ ϵͲϱͬϴ͟ϰϬΘ ϰϯ͘ϱ EͲϴϬΘ^Ͳϵϱ Ƶƚƚ͘>dΘ ϴ͘ϳϱϱ ^ƵƌĨ ϴ͕ϭϯϬ͛;dKtͿ ϳ͟dŝĞďĂĐŬ Ϯϲ >ͲϴϬ tͬ ϲ͘ϭϴϰ͟ ^ƵƌĨ ϱ͕ϴϯϬ͛ ϳ͟ Ϯϲ >ͲϴϬ tͬ ϲ͘ϭϴϰ͟ ϱ͕ϴϮϭ͛ ϭϬ͕ϴϵϯ͛ ϱ͟ ϭϱ >ͲϴϬ d;< ĐŽŶǀĞƌƚŝďůĞͿ ϰ͘ϰϬϴ͟ ϭϬ͕ϰϰϵ͛ ϭϯ͕ϬϮϯ͛ dƵďŝŶŐĞƚĂŝů͗ ϮͲϳͬϴ͟ ϲ͘ϱ >ͲϴϬ ϴƌŶĚh Ϯ͘ϰϰϭ͟ ^ƵƌĨ ϭϬ͕ϯϵϱ͛ ϮͲϯͬϴ͟ ϰ͘ϳ >ͲϴϬ ϴƌŶĚh ϭ͘ϵϵϱ͟ ϭϬ͕ϯϵϱ͛ ϭϭ͕ϰϱϯ͛ WZ&KZd/KEd/> ŽŶĞ dŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ &d ^W& ĂƚĞ ^ƚĂƚƵƐ ŽŵŵĞŶƚ Ͳϲ цϭϬ͕ϯϭϰ͛ цϭϬ͕ϯϳϴ͛ цϵ͕ϳϯϮ͛ цϵ͕ϳϳϴ͛ ϯϭ͛ ϲ &ƵƚƵƌĞ WƌŽƉŽƐĞĚ Ͳϳ ϭϭ͕ϱϱϬ͛ ϭϮ͕ϴϭϬ͛ ϭϬ͕ϰϭϴ͛ ϭϬ͕ϲϵϲ͛ ϭ͕ϮϲϬ͛ ϲ ϭϮͬϮϯͬϭϳ ůŽƐĞĚ :t>Zzd/> EŽ ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ / K /ƚĞŵ ϱϬ͘ϭϬ͛ ϱϬ͘ϭϬ͛ dƵďŝŶŐ,ĂŶŐĞƌ ϭ ϯϳϯ͛ ϯϳϯ͛ Ϯ͘ϯϭϯ͟ ϰ͘ϵϭ͟ ^^^s,ĂůůŝďƵƌƚŽŶEdZ^s Ϯ Ϯ͕ϱϰϰ͛ Ϯ͕ϰϵϵ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϭW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϰ͕ϱϯϬ͛ ϰ͕ϯϴϲ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϮW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϲ͕ϬϱϬ͛ ϱ͕ϴϱϱ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϯW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϳ͕ϭϯϮ͛ ϲ͕ϵϭϱ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϰW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϳ͕ϵϬϬ͛ ϳ͕ϲϱϭ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϱW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϴ͕ϱϰϮ͛ ϴ͕ϭϴϬ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϲW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϵ͕ϬϵϬ͛ ϴ͕ϳϰϮ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϳW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϵ͕ϳϬϭ͛ ϵ͕Ϯϰϳ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϴW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϭϬ͕ϯϰϯ͛ ϵ͕ϳϱϮ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϳϱ͟ '>DηϵW^WKͲϭDDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϯ ϭϬ͕ϯϵϰ͛ ϵ͕ϳϴϵ͛ ϭ͘ϵϴϯ͟ ϯ͘ϲϴϴ͟ ϮͲϳͬϴ͟ǆϮͲϯͬϴ͟ƌŽƐƐŽǀĞƌ ϰ цϭϭ͕ϯϯϬ цϭϬ͕ϯϯϭ͛ Eͬ Ϯ͘ϯϮϱ͟ ϮͲϯͬϴ͟KŶĞdƌŝƉĂƐƚ/ƌŽŶĞŵĞŶƚZĞƚĂŝŶĞƌ ϱ ϭϭ͕ϯϰϵ͛ ϭϬ͕ϯϯϵ͛ ϭ͘ϵϵϱ͟ ϯ͘ϲϮϱ͟ '>DηϭϬ'>DyͲϭ,WDĂŶĚƌĞůƐ͕ʹ;ƵŵŵǇsĂůǀĞͿ ϲ цϭϭ͕ϯϳϬ цϭϬ͕ϯϰϴ͛ Eͬ Ϯ͘ϯϮϱ͟ ϮͲϯͬϴ͟/W ϳ ϭϭ͕ϯϵϴ͛ ϭϬ͕ϯϱϵ͛ ϭ͘ϵϰϬ͟ ϰ͘ϭϮϱ͟ WĂĐŬĞƌͲDĂƉKŝůdŽŽůD&,,ǇĚƌĂƵůŝĐ^ĞƚZĞƚƌŝĞǀĂďůĞǁͬϯϬ<^ŚĞĂƌ ϴ ϭϭ͕ϰϰϲ͛ ϭϬ͕ϯϳϵ͛ ϭ͘ϴϳϱ͟ ϯ͘Ϭϲϯ͟ yEŝƉƉůĞ ϵ ϭϭ͕ϰϱϯ͛ ϭϬ͕ϯϴϭ͛ Ϯ͘ϯϬϬ͟ ϯ͘ϬϬ͟ t>' *UDQLWH3RLQW *335'WLHEDFN sĂůǀĞ͕DĂƐƚĞƌ͕/tͲ&>͕ ϯϭͬϴϱD&͕,tK͕ƚƌŝŵ sĂůǀĞ͕^ǁĂď͕/tͲ&>^͕ ϯϭͬϴϱD&͕,tK͕ƚƌŝŵ sĂůǀĞ͕^^s͕tŝŶŐ͕t<DͲD͕ ϯϭͬϴϱD͕ǁͬϭϱΖ͛stŽƉĞƌ ,d͕ŽǁĞŶ͕ϯϭͬϴϱD&y ϯΖ͛ŽǁĞŶ sĂůǀĞ͕DĂƐƚĞƌ͕/tͲ&>^͕ ϯϭͬϴϱD&͕,tK͕ƚƌŝŵ ϭϴΖ͛ ϭϯϯͬϴΖ͛ ϵϱͬϴΖ͛ dƵďŝŶŐŚĂŶŐĞƌ͕dͲϭͲEͲ >͕ϭϭyϯЪhůŝĨƚĂŶĚ ƐƵƐƉ͕ǁͬϯdǇƉĞ,Ws ƉƌŽĨŝůĞ͕ϮͲЪ͛͛ĐŽŶƚ^^^s ƉŽƌƚƐ͕ĂůůŽǇŵĂƚĞƌŝĂů hŶŝŚĞĂĚ͕KdƚǇƉĞϮ͕ϭϯϱͬϴϱDW/ ŚƵďƚŽƉyϭϯϯͬϴdĐĂƐŝŶŐďŽƚƚŽŵ͕ ǁͬϮͲϮΖ͛>WKŽŶůŽǁĞƌƐĞĐƚŝŽŶ͕ϮͲ Ϯ ϭͬϭϲϱD^^KŽŶƵƉƉĞƌƐĞĐƚŝŽŶ͕/W ŝŶƚĞƌŶĂůůŽĐŬƉŝŶĂƐƐǇ ^ƚĂƌƚŝŶŐŚĞĂĚ͕Kd͕ ϮϭϭͬϰϮD,Ƶďǆ ϮϰЬϭD,ƵďǁͬϮͲ ϮΖ͛>WK͕ ƉƌĞƉƉĞĚĨͬϭϴΖ͛EŚĂŶŐĞƌ ŽŶĚƵĐƚŽƌŚŽƵƐŝŶŐ͕Kd͕ ϮϰЬϭD,Ƶďy ϮϰΖ͛ƵƚƚǁĞůĚ 'ƌĂŶŝƚĞWŽŝŶƚWůĂƚĨŽƌŵ 'WWϮϰͲϭϯZϮ ϭϴyϭϯϯͬϴyϵϱͬϴyϳyϮϳͬϴ hƉƉĞƌďŽǁůƐĞĐƚŝŽŶďĂĚ ƚƚĂĐŚĞŵĞŶƚƐƉŽŽů ͕͕ ϭϯϱͬϴϱDW/ŚƵďǆϭϭΖ͛ϱD &ƚŽƉ dƵďŝŶŐŚĞĂĚ͕ĂĐƚƵƐͲϮϵ>͕ ϭϭϱD&ƚŽƉĂŶĚďŽƚƚŽŵ͕ ƉƌĞƉƉĞĚĨͬϵΖ͛'ďŽƚƚŽŵ͕ǁͬ ϮͲϮϭͬϭϲϱD^^K ϭϱΖ͛ ϮϳΖ͛ ϳΖ͛ ϮϳͬϴΖ͛ &RLOHG7XELQJ%23 6:$%9$/9( 0$67(59$/9( +LOFRUS0RQRSRG5LJ)ORZ'LDJUDP)OXLGV3XPSHG )OXLGV5HWXUQHG9DOYH2SHQ 9DOYH&ORVHG*DWH 9DOYH %DOO9DOYH%XWWHUIO\9DOYH /R7RUT9DOYH$XWRPDWLF&KRNH 0DQXDO&KRNH3UHVVXUH*DXJH.QLIH9DOYHChoke LineP PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLDGAS BUSTER Panic LineC12 C13 C15 C14 C16 A B C4 C5 C6 C7 C2 C10 C9 C11 C8 C3 P C1 C +LOFRUS$ODVND//&+LOFRUS$ODVND//&Changes to Approved Rig Work Over Sundry Procedure6XEMHFW &KDQJHVWR$SSURYHG6XQGU\3URFHGXUHIRU:HOO*UDQLWH3W6W5'37'6XQGU\;;;;;;$Q\PRGLILFDWLRQVWRDQDSSURYHGVXQGU\ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ&KDQJHVWRDQDSSURYHGVXQGU\ZLOOEHFRPPXQLFDWHGWRWKH$2*&&E\WKHULJZRUNRYHU5:2³ILUVWFDOO´HQJLQHHU$2*&&ZULWWHQDSSURYDORIWKHFKDQJHLVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH6HF 3DJH 'DWH 3URFHGXUH&KDQJH 1HZ5HTXLUHG"<1+$.3UHSDUHG%\,QLWLDOV+$.$SSURYHG%\,QLWLDOV$2*&&:ULWWHQ$SSURYDO5HFHLYHG3HUVRQDQG'DWH$SSURYDO$VVHW7HDP2SHUDWLRQV0DQDJHU 'DWH3UHSDUHG)LUVW&DOO2SHUDWLRQV(QJLQHHU 'DWH 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:Katherine O"Connor Cc:Juanita Lovett Subject:RE: GP 24-13RD2 (PTD 217-143) - Sundry (322-127) Cement Packer Adperf Date:Friday, March 25, 2022 12:57:00 PM Attachments:GP 24-13RD2 UPDATED AOGCC Cement Packer Procedure 03.21.22.pdf GP 24-13rd2 Proposed Schematic 2022-03-07.pdf Katherine, You have approval to make your proposed changes to the cement circulating point. 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: Katherine O'Connor <Katherine.Oconnor@hilcorp.com> Sent: Thursday, March 24, 2022 3:25 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: RE: GP 24-13RD2 (PTD 217-143) - Sundry (322-127) Cement Packer Adperf Hey Bryan Based on the deviation and preemptive slickline work I made a couple changes to the program for GPP24-13RD2. I moved the plug & retainer up to keep it above 60 degree deviation and will be punching with EL instead of pulling the DGLV with slickline. I made that change both to account for the deviation (hard to pull valve with that deviation in that small of tubing). Also the geologist increased the perforation footage. It is all in the same interval just wanted more footage. Updated program & schematic attached Thanks Katherine From: Juanita Lovett <jlovett@hilcorp.com> Sent: Tuesday, March 22, 2022 3:07 PM To: Katherine O'Connor <Katherine.Oconnor@hilcorp.com>; Vanessa Hughes <vhughes@hilcorp.com> Subject: GP 24-13RD2 - Sundry Approval Hi Katherine, For distribution when needed. \\hilcorp.com\share\Alaska\Fields\Granite Point\_Granite Point Platform\_1.0 Wells\GP-24- 13RD2\Regulatory\10-403\10-403 Granite Pt St 24-13RD2 PTD 217-143_Sundry_322- 127_Approved_032222.pdf Thanks, Juanita The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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. Well Work Prognosis Well: GP 24-13RD2 Well Name: GRANITE PT ST 24-13RD2 API Number: 50-733-20080-02 Current Status: Injector Leg: Leg #3 Estimated Start Date: March 21, 2022 Rig: SL/EL/CTU Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 217-143 First Call Engineer: Katherine O’Connor 907-777-8376 214-684-7400 Second Call Engineer: Jake Flora 907-777-8442 720-988-5375 Current Bottom Hole Pressure: 2615 psi @ 10418’ TVD SIBHP survey 2/21 Maximum Expected BHP: 3681 psi @ 9732’ TVD Maximum Potential Surface Pressure: 2708 psi 0.1 psi/ft gradient per 20AAC25.280(b)(4) Brief Well Summary GP 24-13RD2 is a currently a water injector in the C7 sands. It was converted to an injector in 2019. The well injected fluid for most of 2020, but injection rates became unsustainable (4000 psi). The well was shut in and has been shut in since October 2020. The objective of this program is to convert this well back into a gas lifted producer by plugging off the C7 sands, placing a cement packer in the well and adding C6 perforations. top bottom size ID bbls/ft ft volume 2-7/8" tbg 0 10395 2-7/8" 2.441 0.006 10395 62.37 2-3/8" tbg 10395 11453 2-3/8" 1.995 0.004 1058 4.232 2-7/8" tbg x 7" casing 0 10395 2-7/8" 6.5# x 7" 26# 6.184 0.02912 10395 302.7034 2-3/8" tbg x 7" casing 10395 10449 2-3/8" 4.7# x 7" 26# 6.184 0.03167 54 1.710187 2-3/8" tbg x 5" casing 10449 11100 2-3/8" 4.7# x 5" 15# 4.408 0.013396 651 8.721 TBG punch Procedure: 1. RU SL pressure test lubricator to 250psi low/2000 psi high a. Set CIBP at ±11370’ MD b. Pressure test tubing to 2000 psi (ensure GLVs & TTP are holding) c. Pull lowest GLV & install circ sub at ± 11349’ MD 2. RU EL pressure test lubricator to 250psi low/2000 psi high a. Set CIBP at ±11100’ MD b. Pressure test tubing to 1000 psi (ensure GLVs & TTP are holding) c. Punch tubing at 11050’ MD 3. Pump FIW into inner annulus and tubing, taking returns to production. 4. MIRU coil tubing 5. NU BOP and test to 250psi low/3500psi high. a. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 6. Set cement retainer @ ± 11000’ MD Well Work Prognosis Well: GP 24-13RD2 7. RIH, sting into cement retainer establishing returns up the IA and pump the following schedule (target TOC in the IA is 9800’ MD): a. 10 bbls surfactant wash b. 2 bbl fresh water (FW) spacer c. 28 bbls class G cement d. 2 bbl FW spacer e. CT volume of cement displacement 8. With 1 bbl of cement remaining in the coil, unsting from retainer and lay the last 1 bbl of cement on the retainer. Note pressures after unstinging from retainer. Do not bleed any pressure. Ensure retainer is holding pressure, and then circ/reverce circ cement. 9. Circulate tbg to diesel and POOH maintaining full hole. 10. RDMO CTU 11. RU EL pressure test lubricator to 250 low/2750 psi high. a. Log SCMT from packer to ±8000’ MD to identify TOC. b. Add perforations per procedure 12. MITIA to 2750 psi Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. Coil Tubing BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form Updated By: KGO 3/3/22 PROPOSED Granite Point Platform Well: Granite Pt St 24-13RD2 PTD: 217-143 API: 50-733-20080-02 1 PBTD: 12,893‘ TD: 13,493’ 2 26” RKB: MSL = 96’ 7” Max Hole Angle = 100.32˚ at 13,493’ MD C7 Sand C D E F TOC @ 11,065’ i 5” 5 6 7 DV Collar 2,198’ 7 8 9 10 11 12 13 Casing Leak ~1,550’ 13-3/8” 9-5/8” 1 2 TOC @ 7,970’ 14 Squeeze Perfs 10,500’-10,504’ 4 3 TOC @ 8,930’ Punch 11,050’ 18” 7” Tieback Seals @ 5,830’ 33” TOC @ 9800’ C6 Sand RKB to Tubing Head 50.35’ X Casing Detail: SIZE WT GRADE CONN ID TOP BTM. 33” Structural Surf 229’ 26” Conductor Surf 294’ 18” 70.59 B Ventura Surf 592’ 13-3/8” 61.0 J-55 Butt. LT&C 12.515 Surf 3,960’ 9-5/8” 40 & 43.5 N-80 & S-95 Butt. LT&C 8.755 Surf 8,130’ (TOW) 7” Tieback 26 L-80 DWC/C 6.184” Surf 5,830’ 7” 26 L-80 DWC/C 6.184” 5,821’ 10,893’ 5” 15 L-80 BTC (KC convertible) 4.408” 10,449’ 13,023’ Tubing Detail: 2-7/8” 6.5 L-80 8rnd EUE 2.441” Surf 10,395’ 2-3/8” 4.7 L-80 8rnd EUE 1.995” 10,395’ 11,453’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Date Status Comment C-6 ±10,294’ ±10,377’ ±9,732’ ±9,778’ 83’ 6 Future Proposed C-7 11,550’ 12,810’ 10,418’ 10,696’ 1,260’ 6 12/23/17 Closed JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 50.10’ 50.10’ Tubing Hanger 1 373’ 373’ 2.313” 4.91” SSSV Halliburton NE TRSV 2 2,544’ 2,499’ 2.441” 4.75” GLM #1 PSPO-1M Mandrels, – (Dummy Valve) 4,530’ 4,386’ 2.441” 4.75” GLM #2 PSPO-1M Mandrels, – (Dummy Valve) 6,050’ 5,855’ 2.441” 4.75” GLM #3 PSPO-1M Mandrels, – (Dummy Valve) 7,132’ 6,915’ 2.441” 4.75” GLM #4 PSPO-1M Mandrels, – (Dummy Valve) 7,900’ 7,651’ 2.441” 4.75” GLM #5 PSPO-1M Mandrels, – (Dummy Valve) 8,542’ 8,180’ 2.441” 4.75” GLM #6 PSPO-1M Mandrels, – (Dummy Valve) 9,090’ 8,742’ 2.441” 4.75” GLM #7 PSPO-1M Mandrels, – (Dummy Valve) 9,701’ 9,247’ 2.441” 4.75” GLM #8 PSPO-1M Mandrels, – (Dummy Valve) 10,343’ 9,752’ 2.441” 4.75” GLM #9 PSPO-1M Mandrels, – (Dummy Valve) 3 10,394’ 9,789’ 1.983” 3.688” 2-7/8” x 2-3/8” Crossover 4 ±11,000 ±10,169’ N/A 2.325” 2-3/8” One Trip Cast Iron Cement Retainer 5 11,349’ 10,339’ 1.995” 3.625” GLM #10 GLMAX-1HP Mandrels, – (Dummy Valve) 6 ±11,100 ±10,223’ N/A 2.325” 2-3/8” CIBP 7 11,398’ 10,359’ 1.940” 4.125” Packer - Map Oil Tool MFH Hydraulic Set Retrievable w/ 30K Shear 8 11,446’ 10,379’ 1.875” 3.063” X Nipple 9 11,453’ 10,381’ 2.300” 3.00” WLEG MEMORANDUM TO: Jim Regg P.I. Supervisor CJC� FROM: Lou Laubenstein Petroleum Inspector Well Name GRANITE PT ST 24-13RD2 Insp Num: mitLOL200508122919 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 11, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC 24-13 RD2 GRANITE PT ST 24-13RD2 Src: Inspector Reviewed By: P.1. Supry_-)73C— Comm API Well Number 50-733-20080-02-00 Inspector Name: Lou Laubenstein Permit Number: 217-143-0 Inspection Date: 5/4/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2TVI) 10359 Tubin 3340 3340 - 3340 3340 - PTD 21714 02 YPJ g �T a Test P ;Test psi 2590 to 60 2850 - 2843 - 2839 BBL Pumped: 3 BBL Returned: 1 3 OA 47 52 52 I 52 Interval I INITAL ilF -P --- Notes: Initial MIT IA on a well converted to injection. ✓ Monday, May 11, 2020 Page 1 of 1 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: Variance of 20 AAC 25.265 (o)(1) 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 13,493 feet N/A feet true vertical 10,712 feet N/A feet Effective Depth measured 12,893 feet 11,398 feet true vertical 10,708 feet 10,359 feet Perforation depth Measured depth 11,550 - 12,810 feet True Vertical depth 10,418 - 10,696 feet 2-7/8" 6.5 / L-80 10,395 (MD) 9,790 (TVD) Tubing (size, grade, measured and true vertical depth)2-3/8" 4.7 / L-80 11,453 (MD) 10,381 (TVD) Packers and SSSV (type, measured and true vertical depth)MFH Hyd Pkr 11,398 (MD) 10,359 (TVD) Halliburton NE TRSV 373 (MD) 393 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: WINJ WAG 0 Water-Bbl MD 229 294 592 13,023 TVD 229 Casing Pressure Tubing Pressure 0 Oil-Bbl measured true vertical Packer 7" 5" Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 330 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 217-143 50-733-20080-02-00 Plugs ADL0018761 N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 319-312 2,982 Size 133 Granite Pt St 24-13RD2 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 572 Authorized Signature with date: Authorized Name:Daniel E. Marlowe Operations Manager Joe Kaiser jkaiser@hilcorp.com 5. Permit to Drill Number: 0 Granite Point Field / Middle Kenai Oil PoolN/A measured 5,830 5,072 N/A Production Production Casing Structural Liner 2,574 Length 229 294 592 9-5/8" Conductor Conductor 5,410psi 1,540psi 33" 26" 18" 7" 5,830 10,893 Collapse 5,410psi Burst 7,240psi 3,842 3,090psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,290psi 7,240psi 294 591 Surface Intermediate 3,960 8,130 13-3/8" 3,960 8,130 7,872 5,750psi 3,090psi (907) 777-8393 5,643 10,108 10,730 7,250psi SPL UGGG Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Daniel Marlowe I am approving this document 2020.05.06 07:38:41 -08'00' Daniel Marlowe By Samantha Carlisle at 3:58 pm, May 06, 2020 DSR-5/6/2020 SFD 5/8/2020 Swing check gls 5/13/20 RBDMS HEW 5/7/2020 Updated By: JLL 07/18/2019 SCHEMATIC Granite Point Platform Well: Granite Pt St 24-13RD2 PTD: 217-143 API: 50-733-20080-02 1 PBTD: 12,893‘ TD: 13,493’ 2 26” 7” Max Hole Angle = 100.32ȗ at 13,493’ MD C7 Sand TOC @ 11,065’ 5” 5 6 7 DV Collar 2,198’ Casing Leak ~1,550’ 13-3/8” 9-5/8” 1 TOC @ 7,970’ Squeeze Perfs 10,500’-10,504’ 4 3 TOC @ 8,930’ 18” 7” Tieback Seals @ 5,830’ 33” X RKB to Tubing Head 50.35’Casing Detail: SIZE WT GRADE CONN ID TOP BTM. 33” Structural Surf 229’ 26” Conductor Surf 294’ 18” 70.59 B Ventura Surf 592’ 13-3/8” 61.0 J-55 Butt. LT&C 12.515 Surf 3,960’ 9-5/8”40 & 43.5 N-80 & S-95 Butt. LT&C 8.755 Surf 8,130’ (TOW) 7” Tieback 26 L-80 DWC/C 6.184” Surf 5,830’ 7” 26 L-80 DWC/C 6.184” 5,821’ 10,893’ 5” 15 L-80 BTC (KC convertible)4.408” 10,449’ 13,023’ Tubing Detail: 2-7/8” 6.5 L-80 8rnd EUE 2.441” Surf 10,395’ 2-3/8” 4.7 L-80 8rnd EUE 1.995” 10,395’ 11,453’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date Status Comment C-7 11,550’ 12,810’ 10,418’ 10,696’ 1,260’ 6 12/23/17 Open JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 50.10’ 50.10’ Tubing Hanger 1 373’ 373’ 2.313” 4.91” SSSV Halliburton NE TRSV 2 2,544’ 2,499’ 2.441” 4.75” GLM #1 PSPO-1M Mandrels, – (Dummy Valve) 4,530’ 4,386’ 2.441” 4.75” GLM #2 PSPO-1M Mandrels, – (Dummy Valve) 6,050’ 5,855’ 2.441” 4.75” GLM #3 PSPO-1M Mandrels, – (Dummy Valve) 7,132’ 6,915’ 2.441” 4.75” GLM #4 PSPO-1M Mandrels, – (Dummy Valve) 7,900’ 7,651’ 2.441” 4.75” GLM #5 PSPO-1M Mandrels, – (Dummy Valve) 8,542’ 8,180’ 2.441” 4.75” GLM #6 PSPO-1M Mandrels, – (Dummy Valve) 9,090’ 8,742’ 2.441” 4.75” GLM #7 PSPO-1M Mandrels, – (Dummy Valve) 9,701’ 9,247’ 2.441” 4.75” GLM #8 PSPO-1M Mandrels, – (Dummy Valve) 10,343’ 9,752’ 2.441” 4.75” GLM #9 PSPO-1M Mandrels, – (Dummy Valve) 3 10,394’ 9,789’ 1.983” 3.688” 2-7/8” x 2-3/8” Crossover 4 11,349’ 10,339’ 1.995” 3.625” GLM #10 GLMAX-1HP Mandrels, – (Dummy Valve) 5 11,398’ 10,359’ 1.940” 4.125” Packer - Map Oil Tool MFH Hydraulic Set Retrievable w/ 30K Shear 6 11,446’ 10,379’ 1.875” 3.063” X Nipple 7 11,453’ 10,381’ 2.300” 3.00” WLEG Rig Start Date End Date Slickline 5/4/20 5/4/20 5/4/2020 AOGCC Inspector, Lou Laubenstein, on site to witness check valve performance test. Start pressure 3,352psig. SD injection pump and block-in piping. Bleed pressure from upstream side of check valve to 0 psig. A drip was observed. Down stream pressure 3,348 psig. After 4 mins, downstream pressure 2,982 psig. No volume was observed. AOGCC Inspector concluded a passing test. Received AOGCC verbal from Guy Schwartz to resume injection. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 24-13RD2 50-733-20080-02-00 217-143 Swing check valve test.... gls Well GP24-13RD2 Check Valve Performance Test Date: 5/4/2020 Well: GP 24-13RD2 PTD: 217-143 Sundry: 319-312 Operations: Jimmy Madrid, Steve Phipps, Mike Heath, Chris Hamel AOGCC Witnessed by: Lou Laubenstein Time Pump Pressure Tubing Press.Inj. Rate Check Valve Back Flow Comments 14:18 3353 3345 295 B/D Pretest 14:19 3352 3348 296 B/D Shut Down / Block In Pump 14:20 3168 0 Drip Block upstream of Check Valve / Open Bleed line upstream of Check Valve. (Leave open for duration of Test) 14:21 3083 0 None Observe open line for leak 14:22 3021 0 None Observe open line for leak 14:23 2982 0 None Production / Inspector concluded a passing test a (QhL Pt Z4--13 Regg, James B (CED) Pm Z(7/4-3r— From: (7/43C From: Sandra Reynolds <sreynolds@hilcorp.com> Sent: Monday, July 22, 2019 1:06 PM To: Regg, James B (CED); DOA AOGCC Prudhoe Bay; Wallace, Chris D (CED) Cc: Brooks, Phoebe L (CED); Dan Marlowe; Holly Tipton Subject: MITIA for 24-13RD2 Granite Point Platform Attachments: GPP 24-13 MIT 7-21-19.xlsx; 100# ID # 870115022-01-003 perma-cal.pdf; 1000# ID# 1011TTM11Y23.pdf; 3000# ID #564059 20180306 Crystal Cal 2019.doc Mr. Regg, Please find the attached MIT test form that was performed yesterday, 7/21/19 for Granite Point Platform 24-13RD2 well. Also, attached are the gauges calibration records used for the testing. Please let me know if you need any other information or data. Thank you. Kind Regards, San,dt 9?ery ddo, P-ead (9pewtox Hilcorp Alaska LLC Granite Point Platform (907)776-6650 I � YEARS From: Regg, James B (CED) [mailto:jim.regg@alaska.gov] Sent: Saturday, July 20, 2019 5:27 PM To: Sandra Reynolds <sreynolds@hilcorp.com> Subject: Re: [EXTERNAL] AOGCC Inspection Form Confirmation Email Spartan's postponed test has complicated our Inspectors' schedules. Still waiting to see if an Inspector will come available for their BOPE test and your MIT. If you have not heard from an Inspector by tomorrow AOGCC witness is waived. Sent via the Samsun, Galaxy SR Active, an AT&T >G Evolution capable smartphone -------- Original message -------- From: Sandra Reynolds <srevnolds a?hilcoW.com> Date: 7/20/19 12:49 PM (GMT -09:00) To: "Begg, James B (CED)" <jim.reff >�:ialaska. ov> Subject: FW: [EXTERNAL] AOGCC Inspection Form Confirmation Email Hello Mr. Regg, I am just following up on our 22-13 MIT witness request. I realize there is witness for Spartan 151 Rig BOP test also, so we are available to do this at any time that is convenient for your folks to make this a combined trip. Thank you Kind Regards, sandy ReytwMj, eead Oen Hilcorp Alaska LLC Granite Point Platform (907)776-6650 veYEARSRSr.� From: AOGCC Inspections [mailto:noreply@jotform.com] Sent: Friday, July 19, 2019 7:43 AM To: Sandra Reynolds <sreynoldsCa7hilcorp.com> Subject: [EXTERNAL] AOGCC Inspection Form Confirmation Email This email confirms your request for an inspection with the following information: Type of Test Requested: MIT Requested Time for Inspection: 07-21-2019 12:00 PM Location: Granite Point Platform Name: Sandra Reynolds E-mail: srevnolds!@hilcorp.com Phone Number: (907) 776-6650 Company: Hilcorp Alaska, LLC Other Information: MIT test on 24-13RD2 injection well - (Note:Date chosen for possible coincide travel with Spartan Rig BOP testing ) Thank you. If you are not contacted within 12 hours, please notify Jim Regg at 907-793-1236. Thank you! Alaska Oil and Gas Conservation Commission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: dT.regg0alasCTgov: AOGCC. Inspectorstialaska. Coy. phoebe.brocksratataska.go OPERATOR: Hiywrp Alaska. LLC FIELD I UNIT / PAD: Granite Point Field/ Granite Point Unit /Granite Point Platform DATE: 07/21/19 OPERATOR REP: B. Reynolds AOGCC REP: Witness waived per Jim Regg Chlis.wallace0alaskam 'W�lj 7�Zoljtti Well 24.13RD2 INTERVAL Codes Pressures. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 4=Four Year Cycle F=Fast PTD 217-143 " Typa IN N Tubing 463 464 464 465 465 465 Type Test P Packer TVD 10359 BBL Pump 3.3 IA 64 2745 2738 2733- 2729 2725' Interval 0 Test psi 2590 BBL Return 3.3 - OA 46 52 52 52 52 52 Result P Notes: Conven to lnjetlo,"Pre-Injeclion MITIA Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min, PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures. Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. PTD Typa Inj Tubing Typa Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTOType Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Indal 15 Min. 30 Min. 45 Min. 60 Min, PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures'. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type IN Tubing Type Test Packer TVD BBL Pump IA In Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result No.s: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTO Type Inj Tubing Type Test Pecker TVD BBL Pump IA Interval Test psi BBL Return I OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=poon,le ie. 1=lnOW Test P=Pus G=Gad 0= 01M1er )describe In Nonni 4=Four Year Cycle F=Fast S=Slurry V= Requite br Varier I - loconds. I = Indention Wastewater G=Cee, tdewdbe m rates) N = Net Inleain, Form 10-426 (R9VISe4 01/2017) GPP 24-13 MIT 7-21-19 Gauge type: S/N Number: ID Number: Calibrated by: Perma-Cal 870115022-01-003 8 TEST PRESSURE 0 25 50 75 100 y%atoria Asi zi,w Pressure range: 0-100 psi L� Date: 7/18/19 INDICATION 24.99 49.97 74.98 99.98 1000440 This certificate expires in 90 Days on 10/18/19. For recertification, contact Gina Bogart 776-6825; Cathy Marshall 283-1384 Of Victoria Askin 283-1308 M Silil,mp AltAit, LLC Pit tforni Anna iii; Calibration Rep.,ml tai 3 Pa i -� asaR3s;ea1� s�r�pt��anro !F q ic`il ,Tn..b•i:;t:�I §'2i` I s � i �.'':_.______.. 'u",aaii'r�s�i ` ..I. i� ._., .. 'Ooj) 1 X ca9f#arration X A€9 Parts CaHbraarte¢€ y: mMirc,VC')tl (;: X RepeatabiRty —Data matasiTaags oatcx 9/23/19 0031rO4 a'3uatpAut ��'eaai ratpaaY� CI,500 PSI 50,C) 1:)ai 1500 1133 " :i P 1 000 f : 1()00 r'_il l iol X ca9f#arration X A€9 Parts CaHbraarte¢€ y: mMirc,VC')tl (;: X RepeatabiRty —Data matasiTaags oatcx 9/23/19 Nsired Output icctuai_Oputpoit 50,C) 1:)ai 1500 1133 " :i P 1 000 f : 1()00 r'_il l X ca9f#arration X A€9 Parts CaHbraarte¢€ y: mMirc,VC')tl (;: X RepeatabiRty —Data matasiTaags oatcx 9/23/19 Uffilcorl) Alaska, TALC: HILCORP CALIBRATION CERTIFICATE Pressure Standards Referenced to NIST annually. Gauge type: ID Number: Calibrated by: Crystal 564059 TEST PRESSURE Pressure range: 0-3000 psi / Date: 3/19/19 INDICATION 0 0 750 750.00 1500 1500.03 2250 2250.00 3000 3000.02 VCCtor, l ASlZLV Test equipment S/N: This certificate expires in one year on 3-19-2020. 23577 For recertification, contact Gina Bogart 776-6825; Cathy Marshall 283-1384 or Victoria Askin 283-1308. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 0`4 �� k,p e � V C LJ JUL 2 2 ?R19 1. Operations Abandon L Plug Perforations L Fracture Stimulate L Pull Tubing L 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. Convert to Infector ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Exploratory ❑ Stratigraphic ❑ Service ❑ 217-143 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20080-02-00 7. Property Designation (Lease Number): 8. Well Name and Number. ADL0018761 Granite Pt St 24-13RD2 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Granite Point Field / Middle Kenai Oil Pool 11. Present Well Condition Summary: Total Depth measured 13,493 feet Plugs measured N/A feet true vertical 10,712 feet Junk measured NIA feet Effective Depth measured 12,893 feet Packer measured 11,398 feet true vertical 10,708 feet true vertical 10,359 feet Casing Length Size MD TVD Burst Collapse Structural 229' 33" 229' 229' Conductor 294' 26" 294' 294' Conductor 592' 18" 592' 591' Surface 3,960' 13-3/8" 3,960' 3,842' 3,090 psi 1,540 psi Intermediate 8,130' 9-5/8" 8,130' 7,872' 5,750 psi 3,090 psi Production 5,830' 7" 5,830' 5,643' 7,240 psi 5,410 psi Production 5,072' 7" 10,893' 10,108' 7,240 psi 5,410 psi Liner 2,574' 5" 13,023' 10,730' 8,290 psi 7,250 psi Perforation depth Measured depth 11,550 - 12,810 feet True Vertical depth 10,418 - 10,696 feet Tubing (size, grade, measured and true vertical depth) 2-7/8" & 2-3/8" 6.5 / L-80 & 4.7 / L-80 11,453 (MD) 10,381 (TVD) Map Oil Tool 11,398 (MD) 373 (MD) Packers and SSSV (type, measured and true vertical depth) MFH Hyd Set Retry 10,359 (TVD) Halliburton NE TRSV 373 (TVD) 12. Stimulation or cement squeeze summary: 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 1 0 7 4 Subsequent to operation: 0 0 1 0 433 203 14. Attachments (required Per 20 AAc 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑ Development ❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. We11 Status after work: Oil ❑ Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 319-289 Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmadoweCahilcom.com a Ct Authorized Signature: (T1.-. Date: 2� Z Contact Phone: (907) 283-1329 �U4 nu.,x., RBDMS -W-01 JUL 2 3 2019 ,f 'uor 7 nginai My K iiilcoro Alaska, LLC RK13 to Tubing Head 50.35' PBTD: 12,893' TD: 13,493' Max Hole Angle = 100.32' at 13,493' MD SCHEMATIC Casine Detail: Granite Point Platform Well: Granite Pt St 24-13RD2 Last Completed: Future PTD: 217-143 API: 50-733-20080-02 JEWELRY DETAIL No VVT GRADE CONN ID TOP BTM. 50.10' 50.10' Structural Tubing Hanger Surf 229' r 2.313" 4.91" Conductor Surf 294' 2.441" 70.59 B Ventura 4,386' Surf 592' GLM #2 PSPO-1M Mandrels, —(Dummy Valve) 61.0 J-55 5,855' Butt. LT&C 12.515 Surf 3,960' 9-5/8- 43.5 N-80 & S-95 Butt. LT&C 8.755 Surf 8,130' (TOW) 7" Tieback 26 L-80 GLM #5 PSP0-1M Mandrels,—(Dummy Valve) DWC/C 6.184" Surf 5,830' 7" 26 L-80 9,090' DWC/C 6.184" 5,821' 10,893' 5" 35 L-80 2.441" BTC (KCe) convertible) 408" 10,449' 13,023' 9,752' 2.441" 4.75" Tubing Detail: 3 10,394' 9,789' 2-7/8" 6.5 L-80 4 8rnd EUE 2.441" Surf 10,395' 2-3/8" 4.7 L-80 10,359' 8rnd EUE 1.995" 10,395' 11,453' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item Open 50.10' 50.10' Tubing Hanger 1 373' 373' 2.313" 4.91" SSSV Halliburton NE TRSV 2,544' 2,499' 2.441" 4.75" GUM #1 PSP0-1M Mandrels, — (Dummy Valve) 4,530' 4,386' 2.441" 4.75" GLM #2 PSPO-1M Mandrels, —(Dummy Valve) 6,050' 5,855' 2.441" 4.75" GUM #3 PSP0-1M Mandrels, — (Dummy Valve) 7,132' 6,915' 2.441" 4.75" GUM #4 PSPO-IM Mandrels,—(Dummy Valve) 2 7,900' 7,651' 2.441" 4.75" GLM #5 PSP0-1M Mandrels,—(Dummy Valve) 8,542' 8,180' 2.441" 4.75" GUM #6 PSPO-IM Mandrels, — (Dummy Valve) 9,090' 8,742' 2.441" 4.75" GUM #7 PSP0-1M Mandrels, — (Dummy Valve) 9,701' 9,247' 2.441" 4.75" GUM #8 PSP0-1M Mandrels, — (Dummy Valve) 10,343' 9,752' 2.441" 4.75" GLM#9 PSP0-1M Mandrels,—(Dummy Valve) 3 10,394' 9,789' 1.983" 3.688" 2-7/8" x 2-3/8" Crossover 4 11,349' 10,339' 1.995" 3.625" GUM #10 GLMAX-1HP Mandrels,—(Dummy Valve) 5 11,398' 10,359' 1.940" 4.125" Packer- Map Oil Tool MFH Hydraulic Set Retrievable w/30K Shear 6 11,446' 10,379' 1.875" 3.063" X Nipple 7 11,453' 1 10,381' 2.300" 3.00" 1 WLEG PERFORATION DETAIL Top Btm op Zone (MD) (MD) Top Btm (TVD) (TVD) FT SPF Date Status Comment C-7 11,550' 12,810' 1 10,418' 10,696' 1,260' 6 12/23/17 Open Updated By: AL 07/18/2019 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permi[ Number Start Dale End Dale Granite Pt St 24-13RD2 Slickline 50-733-20080-02-00 217-143 7/1/19 7/3/19 Daily Operations: 7/1/2019 - Monday ARRIVE G.P. PLATFORM MEET W/ JIM TGSM JSA PERMIT, SPOT UNIT RIG UP SUCKLINE. P/T LUB. & WLV'S TO 250PSI LOW 2,500PSI HIGH C/O 0 -RING TEST AGAIN - GOOD TEST. RIH W/ 1.75" DD BAILER TO 11,870'KB TAG POOH - REMOVE SPANGS PROGRAM GAUGES. RIH W/TRI-GAUGES @ 120FPM TO 11,550'KB BOTTOM STOP SEE STOP SHEET. OOH W/ GAUGES DOWNLOAD DATA & SEND TO JERRY BUTLER - DISCOVER BENT SHAFT ON UNIT RUBBING ON WIRE STAND BY FOR PRODUCTION TO LAY DOWN LUB CUT- FIX. RIH W/ 2" GS W/ 2-3/8" AD -2 STOP TO 11,370'WLM W/ TOOL SET POOH;OOH CLOSE SWAB BLEED LUB. SECURE AREA FOR NIGHT. 7/2/2019 -Tuesday MORNING MEETING JSA PERMIT. P/U LUB. STAB ON RISER. RIH W/ 2-3/8" OK -1 KOT W/ 1.25" JDS TO 11,336'WLM 11,370'KB LOCATE BUT WOULD NOT LATCH. POOH -TRIGGER PIN SHEARED REDRESS. RIH W/ SAME TO SAME LOCATE - LATCH W/ TOOL POOH W/ ORFICE. RIH W/ 2-7/8" DANIELS KOT W/ 1.25" JDS TO 10,330'WLM 10,364'KB LOCATE -LATCH W/ TOOL. POOH W/ VALVE. RIH W/ SAME TO 9,786'WLM 9,820'KB LOCATE -COULD NOT LATCH POOH TO 9,076'WLM 10,010'KB. LOCATE -LATCH W/ TOOL POOH W/ VALVE. RIH W/ SAME TO 8,528'WLM 8,562'KB LOCATE -LATCH W/ TOOL CAME FREE - SLING SHOT UP HOLE. POOH @ 7,610' HUNG UP -WIRE BROKE. APPEAR TO HAVE ALL WIRE BACK CALL TOWN & SUP. LAY DOWN LUB CUT WIRE BUILD TOOLSTRING. RIH W/ 2.25" LIB TO 10,341'WLM 10,375'KB TAG - HIT ONE TIME POOH STAND BY FOR CHOPPER. OOH W/ IMPRESSION OF WIRE. RIH W/ 2" SPLIT SKIRT JDC TO 10,344WLM 10,378'KB LATCH TOOLSTRING POOH HUNG UP @ 10,039' WLM MULTIPLE JAR LICKS TO 1600# CAME FREE POOH W/ TOOLSTRING NO WIRE. RIH W/ 2.25 WIRE GRAB TO 10,363'KB SIT DOWN POOH W/ 5' OF WIRE. RIH W/ 2-7/8" DANIELS KOT W/ 1-1/4" JDC TO 9,820'KB W/T CAN NOT LOCATE OR SIT DOWN PULL UP TO 7916'KB LOCATE, SIT DOWN, W/T POOH W/ VALVE. RIH W/ SAME TO 7150'KB LOCATE, SIT DOWN, W/T POOH W/ VALVE. RIH W/ 2-7/8" DANIELS KOT W/ I- 1/4" JDC TO 6,066'KB LOCATE, SIT DOWN POOH W/ VALVE. RIH W/ SAME TO 4,545'KB LOCATE, SIT DOWN, W/T POOH W/ VALVE. RIH W/ SAME TO 2,555'KB LOCATE, SIT DOWN, W/T POOH W/ VALVE. RIH W/ 2-7/8" OK -1 W/ 1-1/4" JDC TO 9,720'KB LOCATE, SIT DOWN, W/T POOH W/ VALVE. RIH W/ 2-7/8" DANIELS W/ JK R.T. W/ DUMMY VALVE TO 2,555'KB W/T POOH VALVE SET. RIH W/ SAME TO 4,545'KB W/TOOL POOH VALVE SET 07/03/19 - Wednesday POOH DUMMY VALVE SET. RIH W/ SAME TO 6066'KB W/ TOOL. POOH DUMMY VALVE SET. STOP THE JOB FOR CRANE OP TO SLEEP. RIH W/ SAME TO 7150'KB W/ TOOL. POOH DUMMY VALVE SET. RIH W/ SAME TO 7916 -KB W/ TOOL. POOH DUMMY VALVE SET. RIH W/ SAME TO 8562'KB W/ TOOL. POOH DUMMY VALVE SET. RIH W/ SAME TO 9110'KB W/ TOOL. POOH DUMMY VALVE SET. RIH W/ SAME TO 9720'KB W/ TOOL. POOH DUMMY VALVE SET. RIH W/ SAME TO 10,364'KB W/ TOOL. POOH DUMMY VALVE SET. RIH W/ 2 3/8" OK -1 KOT W/ JK -RUNNING TOOL W/ DUMMY VALVE TO 11,370'KB W/ TOOL. POOH HUNG UP @ 10,770', 2 JAR LICKS CAME FREE POOH - LOOKS LIKE TRIGGER CAUGHT DAMAGING BODY OF ROT JUST UNDER TRIGGER. CAME OUT W/ DUMMY VALVE. RIH W/ 1.85 WIRE GRAB TO 11404 -KB W/T POOH - NO WIRE. RIH W/ 2 3/8 DANIELS W1 JK R.T. W/ DUMMY TO 800'. POOH CHECK R.T. ON DANIELS. RIH W/ SAME TO 11394'KB W/T SHEAR OFF, TRIGGER KEEPS LOCATING, SPANG THROUGH, HANG UP AT 11232'KB SPANG THROUGH POOH - VALVE SET. RIH W/ 2 3/8 GS TO 11407'KB W/T POOH W/ AD -2 STOP. RIG DOWN STAND BY FOR CHOPPER. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stan W. Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 24-13RD2 Permit to Drill Number: 217-143 Sundry Number: 319-312 Dear Mr. Golis: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .00gcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this day of July, 2019. R13DMSL4/JUL 0 2 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 "tGEIVED JUN 2 7 2013 A Jr, _i% 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Variance of ❑✓ 20 AAC 26.265 (o)(2) 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Stratigraphic ❑ Service y�. [� 217-143 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 C drum ,,;�, 50-733-20080-02-00 7. If perforating:�- - 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑✓ Granite Pt St 24-13RD2 9. Property Designation (Lease Number): 10. Field/Pool($): ADL0018761 I Granite Point Field / Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,493 10,712 12,893 10,708 2,082 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural 229' 33" 229' 229' Conductor 294' 26" 294' 294' Conductor 592' 18" 592' 591' Surface 3,960' 13-3/8" 3,960' 3,842' 3,090 psi 1,540 psi Intermediate 8,130' 9-5/8" 8,130' 7,872' 5,750 psi 3,090 psi Production 5,830' 7" 5,830' 5,643' 7,240 psi 5,410 psi Production 5,072' 7" 10,893' 10,108' 1 7,240 psi 5,410 psi Liner 2,574' 5" 13,023' 10,730' 1 8,290 psi 7,250 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11,550 - 12,810 10,418 - 10,696 2-7/8" & 2-3/8" 6.5 / L-80 & 4.7 / L-80 11,453 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Map Oil Tool MFH Hydraulic Set Retry / Halliburton NE TRSV 11,398 (MD) 10,359 (TVD) & 373 (MD) 373 (TVD) 12. Attachments: Proposal Summary Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Slratigraphic ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/11/2019 OIL ❑ WINJ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowt: hilcor .Com T Contact Phone: (907) 283-1329 m�//7-/ � M•% J ✓n -n Authorized Signature:!'<Z/� � ate: � Z% / COMMI§SIO14 USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: _ 3� 2 Plug Integrityy�❑BOP Test ❑ Mechanical IntegrityEl Test ❑ Location Clearance L Other: Aloe -rpt �.+C-. SVS- n tlfe..xitG z.ro,$. 2/oS (U) ( t) 2s� b t r� e-v Ze4- Post Initial Injection MIT Req' Yes No ❑ Spacing Exception Required?4YesNo V� Subsequent Form Required: la-Kr`i RBDMS JU4 0 1019 APPROVED BY / /�{T Approved by: COMMISSIONER THE COMMISSION Date: ` (� (f O Form 10-403 Revised 4/2017 91-6 wilm I for 12 months from the nein-roil Attachments in Duplicate 4 z-7,1 F "o� e 2-711 R Hllm p Alk., LLC Well Work Prognosis Well Name: Granite Pt St #24-13RD2 (GP 24-13rd2) API Number: 50-733-20080-02 Current Status: Producer Leg: Leg #3 Estimated Start Date: July 11th, 2019 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 217-143 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Joe Kaiser 1 (907) 777-8393 (0) (907) 952-8897 (M) Current Bottom Hole Pressure: 3,100 psi @ 10,178' TVD Maximum Expected BHP: 3,100 psi @ 10,178' TVD Maximum Potential Surface Pressure: 2,082 psi 0.305 lbs/ft (5.86 ppg) based on offset producers 0.305 lbs/ft (5.86 ppg) based on offset producers Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary GP 24-13rd2 is a very low rate C-7 producer completed with Gas Lift. The current completion is a 2017 side track from the GP 24-13rd a shut-in injector. This well is approved for injection in accordance with Area Injection Order 11 and sundry 319-289. Last Casing Test: 12/27/2017 tested packer at 11,398' MD / 10,359' TVD to 2,100 psi on chart for 30 minutes G L7 'rte! Waiver Request: 1_6� k jJ Hilcorp is requesting a variance of 20 AAC 25.265 (o) f2�to eliminate the installation of a�tltomated surface safet valve due to this wells injection being incapablle' of sustained back flow./ iet During waterflood pumping operations, GP24-13rd2 will have a full fluid column of water equivalent to 4,510 psi. The current bottom hole shut-in pressure is —3,100 psi. This is a pressure differential deficit of 1,410 psi, I the well will be on a vacuum until liquid level stabilizes. On 6/14/2019 echometer data verified liquid I GP 24-13RD2 has a tubing pressure of 383 psig and fluid level of 2,573'. This shows a 731 psig deficiency. Hilcorp Alaska, LLC will install a check valve adjacent to the well tree to prevent any backflow to surface as good engineering practice and common practice for water injection wells throughout the Cook Inlet. Attachments: 1. Well Schematic Current 2. Wellhead Schematic 3. GP 24-13rd2 Flow Diagram �i��. ,.44-e-- ;7 -Ls Cbz K liilrnm Alaska. LLC RKB to Tubing Head 50.35' PBTD: 12,893' TD: 13,493' Max Hole Angle =100.32' at 13,493' MD SCHEMATIC Casing Detail: Granite Point Platform Well: Granite Pt St 24-13RD2 Last Completed: 12/28/17 PTD: 217-143 API: 50-733-20080-02 SIZE WT GRADE CONN ID TOP BTM. 33" 50.10' Structural Tubing Hanger Surf 229' 26" 2.313" 4.91" Conductor Surf 294' 18" 70.59 B Ventura 4,530' Surf 592' 13-3/8" 61.0 J-55 Butt. LT&C 12.515 Surf 3,960' 9-5/8" 40g, N-80 & 5-95 Butt. LT&C 8.755 Surf 8,130' (TOW) 7" Tieback 26 L-80 DWC/C 6.184" Surf 5,830' 7" 26 L-80 DWC/C 6.184" 5,821' 10,893' 5" 15 L-80 BTC (KC convertible) 4.408" 10,449' 13,023' 9,247' 2.441" 4.75" Tubing Detail: 10,343' 9,752' 2-7/8"6.5 4.75" L-80 3 8rnd EUE 2.441" Surf 10,395' 2-7/8" x 2-3/8" Crossover 4.7 L-80 10,339' 8rnd EUE 1.995" 1 10,395' 11,453' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 6 12/23/17 Open 50.10' 50.10' Tubing Hanger 1 373' 373' 2.313" 4.91" SSSV Halliburton NE TRSV 2,544' 2,499' 2.441" 4.75" GLM #1 PSPO-1M Mandrels, R-1 Valves w/ BK -2 latches 4,530' 4,386' 2.441" 4.75" GLM #2 PSPO-1M Mandrels, R-1 Valves w/ BK -2 latches 6,050' 5,855' 2.441" 4.75" GLM #3 PSPO-1M Mandrels, R-1 Valves W/ BK -2 latches 7,132' 6,915' 2.441" 4.75" GLM #4 PSPO-1M Mandrels, R-1 Valves w/ BK -2 latches 2 7,900' 7,651' 2.441" 4.75" GLM #5 PSPO-IM Mandrels, R-1 Valves w/ BK -2 latches 8,542' 8,180' 2.441" 4.75" GLM #6 PSPO-1M Mandrels, R-1 Valves w/ BK -2 latches 9,090' 8,742' 2.441" 4.75" GLM #7 PSPO-1M Mandrels, R-1 Valves w/ BK -2 latches 9,701' 9,247' 2.441" 4.75" GLM #8 PSPO-1M Mandrels, R-1 Valves w/ BK -2 latches 10,343' 9,752' 2.441" 4.75" GLM#9 PSPO-1M Mandrels, R-1 Valves w/ BK -2 latches 3 10,394' 9,789' 1.983" 3.688" 2-7/8" x 2-3/8" Crossover 4 11,349' 10,339' 1.995" 3.625" GLM #10 GLMAX-1HP Mandrels, R001 orifice w/ T-1 latches 5 11,398' 10,359' 1.940" 4.125" Packer- Map Oil Tool MFH Hydraulic Set Retrievable w/ 30K Shear 6 11,446' 10,379' 1.875" 3.063" X Nipple 7 11,453' 10,381' 2.300" 3.00" WLEG PERFORATION DETAIL ,one Top Btm (MD) (MD) Top Btm FT (TVD) (TVD) SPF Date Status Comment C-7 11,550' 12,810' 10,418' 10,696' 1,260' 6 12/23/17 Open Updated By: GD: 01/16/18 Granite Point GPP 24-13RD2 tie -back 06/05/2019 Granite Paint Platform Tubing hanger, TC M-EN- GPP 2413RD2 CCL 11 X 3 % EOE lift and 18X133/8X95/8 X7 X2718 cusp. w/3 Type H BW profile, 2-%"nor4 SCM ports, alloy material BHTA Bowen, 31/8 SM FE X 3" Bowen Valve, Swab, CAW -FLS, 31/8 5M FE, HWO, EE trim Valve, 55 V, Win, WW -M, 31/8 SM, w/ 15"VW eper 0 Valve, Master, CI W -FLS, 31/85M FE, HW0, EE trim Valve Martep CIWiL, 31/85M FE, HWO, EE trim Tubing head, Cactus -C391, 115M FE Np and Wttdn, prepped f/ 9" BG bottom, w/ 2-21/16 5M SSO TnacMment spool, DCB, 13 5/8 5M API bub x 11" 5M FE top 27" Onihe 2' OCT n 1 13 5/8 SM API 6"'LN >ri Nace, bowl se[tllT bad hub top X 133/8 BTC casing bottom, w/165 LPO on lower wcdo 2-2 1/165inern on upper secGan, IP internal lockpn asst' Starti, head, OCT, 211/4 2M Hub x 24MSM Hub w/2-2" LP), prepped f/ 18' EN hanger Conductor housing, OCT, 24%1M Hub 24"ButtweM UFFilcorp Alaska Calculation Record Schwartz, Guy L (CED) From: Joe Kaiser <jkaiser@hilcorp.com> Sent: Thursday, June 27, 2019 11:35 AM To: Schwartz, Guy L (CED) Subject: GP 24-13 RD2: Check Valve Info Guy: We send of the sundry for the SSV waiver on GP 24-13rd2. Per your request yesterday, here is a brief summary of the types of check valves. The different types of check valves are depicted. Each type is used based on the service. We typically use swing check valves in most process applications because they have unrestricted flow, allow for tight sealing, allow pigs to travel through, and require less maintenance. WE do use wafer style or lift style check valve when space is constrained. These typically require more maintenance with more restrictive flow. We use swing check valves on all flowlines to prevent comingling and gas lift lines to wells. While they are not a pressure retaining device, they do prevent backflow and have minimal leakage. I like them because they have minimal parts wear due to full flow in them and are easily accessible for inspection and maintenance. It is very common practice throughout Cook Inlet to have injection wells with only check valves. Especially when pressure depleted reservoirs are utilized. Additionally, we also have high pressure alarms and shutdowns for the injection pump and surface pressure monitoring for this particular well. Any abnormal conditions and the well will be shut in immediately. If you have any further questions regarding check valves or this particular application on GP 24-13rd2, please contact me. I am happy to provide my experience and knowledge of valves and valve selection. Lift Check valves - higher pressure drop is expected. - equipped with small return spring to facilitate valve closure on reverse flow - two type of seat. hard seat for for high differential pressure sealing and resilient seat for low differential pressure sealing - shortest travel length. Fastest response. - excellent performance for low and/or pulsating flows - not good for fluid with particles - Body install horizontal with disc / piston vertically - Small check valve range from 1/2" to 2" lift piston type check valve - Prefer operate in full open position -10., LOW Swing Check Valve - Tight sealing / shut-off - Low pressure drop - Susceptible to water hammer - Not good for low flow and/or pulsating flow - Vertical (upward flow) & horizontal installation - Easiest check valve to maintain - Prefer operate in full open position FLCH Lift Check Valve Swing Check Valve Dual Plate Check valve The characteristic of dual plate check valve is pretty same as swing check valve. - low pressure drop - Not good for low flow and/or pulsating flow - Vertical (upward flow) & horizontal installation ,COW FLOW - Faster opening and closure compare to swing check valve - Susceptible to water hammer (lesser than Swing check valve) - Prefer operate in full open position scr eM MrwM CLMD �unuur nrq "CTM 1J Dual Plate Check Valve Tilting Disc Check Valves - Fast opening and closing without damage to disc and seat - Stable at low and pulsating flows - Moderate pressure drop. Lower than lifting check valve but higher than swing check valve - Vertical (upward) & horizontal installation - Moderate tight sealing - Prefer operate in full open position FLOW Tilting Disc Check Valve Joe Kaiser I Operations Engineer I Hilcorp Alaska, LLC O: (907) 777-8393 1 C: (907) 952-8897 1 ikaiser@bilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 FI OW The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication maybe legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. 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 STATE ALASKA GOVERNOR MIKE. DUNLEAVY Stan Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Granit Point Field, Middle Kenai Oil Pool, Granit Pt. St 24-13RD2 Permit to Drill Number: 217-143 Sundry Number: 319-289 Dear Mr. Golis: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /�� °�`" essiJ a L. C ielowski. Commissioner DATED this 11 day of June, 2019. RSDMSd�"JUN 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS o e`WL�11 V l;Lj JUN 10 2019 AOGCC / T 9 ZU AAI, ZD./OV ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ 1. Type of Request: Abandon ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Suspend ❑ Perforate ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Convert to Injector Q Plug for Redrill 4. Current Well Class: 5. Permit to Drill Number: 2. Operator Name: Exploratory ❑ Development Q • 217-143 ' Hilcorp Alaska, LLC ❑ 6. API Number: 3. Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic ❑ Service 50-733-20080-02-00 Anchorage, AK 99503 l Name and Number: 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? ;WA:::�ti-We'� Will planned perforations require a spacing exception? Yes ❑ N❑Q anPt St 24-13RD2 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): Granite Point Field / Middle Kenai Oil Pool . ADL0018761 . PRESENT WELL CONDITION SUMMARY 11 Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 13,493 - 10,712 12,893 10,708 2,082 psi N/A NIA Size MD ND Burst Collapse Casing Length Structural 229' 33" 229' 229 Conductor 294' 26" 294 294 Conductor 592' 18" 592' 591' 3,842 3,090 psi 1,540 psi Surface 3,960' 13-3/8" 3,960' 7,872' 5,750 psi 3,090 psi Intermediate 8,130' 9-5/8" 8,130' 57643' 7,240 psi 5,410 psi Production 5,830' ?° 5,830 10,893' 10,108' 7,240 psi 5,410 psi Production 5,072' ?" 13,023' 8,290 Psi 7,250 psi 10,730' Liner 2,574' 5" Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11,550 - 12,810 10,418 - 10,696 2-7/8" & 2-3/8" 6.5 / L-80 & 4.7 / L-80 11,453 Packers and SSSV MD (tt) and ND (ft): Packers and SSSV Type: Oil Tool MFH Hydraulic Set Ret" / Halliburton NE TRSV It1398 (MD) 10,359 (TVD) & 373 (MD) 373,(TVD) Map 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: ❑� ' Program F-1Ex BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service P Detailed Operations 15. Well Status after proposed work: 14. Estimated Date for 6/24/2019 OIL ❑ WINJ Q WDSPL El Suspended ❑ Commencing Operations: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Date: 16. Verbal Approval: ❑ Op Shutdown ❑ Abandoned ❑ Commission Representative: GINJ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Dan Marlowe Authorized Name: Stan W. Golis Contact Email: drllaflOWe � hIICOr .COm Authorized Title: Operations Manager Contact Phone: (907) 283-1329 `� Date: 1 b ICN Authorized Signature: COMMISSION USE ONLY Sundry Number: Conditions of approval: Notify Commission so that a representative may witness `/'A1 L ✓I Plug Integrity BOP Test ❑ Mechanical Integrity Test / Location Clearance ❑ ✓❑ �{/ Other: iF� V � I`�`J¢t�S r ��L.-e�-rJ' i kt t.� SF" C e� r y�� ZC A4e— ZS. / Cb> Post Initial Injection MIT Req'd? Yes ❑ No ❑ut_ r� M$4/JUN 18 2019 Yes No Subsequent Form Required: l- LIU^ I f181] Spacing Exception Required? ❑ APPROVED BY Date: COMMISSIONER THE COMMISSION Approved by: u orrn an Ztl Form 10 3 Revised 4/eon Approved applicatio i ffr(j T*kthe date of approval. Attach Duplicate /q 6--3. 'Ls n flilcprp Alnekn. LLC RKB =114,75": 43' Rig Floor to Wallhead and npotw6ttei wffn imo 1 oen8<r pni, 1 Pos&d'e Corrosion 250'-6so' 691 poor nding Ghost Role " 9674'- ,e 10.288' TOF'8 9,828' TOL @ 9,963' • Abandoned Schematic 18, DV Collar @ 2285' @&ooc 001N@&073' 5/a9�r1 1 21 3 4 s 9518" row �a 7, PBTD: 9,440' TD: 11,8W MAX HOLE ANGU 1250 .Granite Point PrSSt Well: Granite11-24 PTD: 167-057 API: 50-733-20046-00 P&A on 9/26/17 FISH Item Top of tubing fish is @ 9,833', Top of W P @ 9828'. Hole and bad spots in casing from 9,772' to 9,838. See morning reports for more detail. Updated By: CID 11/29/17 CASING DETAIL No Depth (MD) Size Wt Grade Conn ID Top Btm 18" 70.59 B Ventura surf 638' 13-3/8" 61 J-55 81d 12.515" Surf 4,030' 3 40 N-80 Butt 8.835" Surf 82' __T3 5 N-80 Butt 8.755" 82' 123' 5 40 N-80 Butt 8.835" 123' 1,955' 9-5/8 40 N-80 LT&C 8.835" 1,955' 5,547' 1/6/1968 40 5-95 ST&C 8.835" 5,547' 61537' 9,203' 43.5 S-95 ST&C 8.755" 6,537' 8,006' (KOP) 7" 29 P-110 X -Line 1 6.184" 1 9,963' 11,798' Pressure tested to 5,000 TUBING DETAIL (FISH 9,951' 9,285' 3-1/2" 9.2 L-80 SC -BTC 1 3.992" 1 9,828' 1 10,699' FISH Item Top of tubing fish is @ 9,833', Top of W P @ 9828'. Hole and bad spots in casing from 9,772' to 9,838. See morning reports for more detail. Updated By: CID 11/29/17 JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item Top 8,028' 7,437' CIBP(Set for whipstock) Date Status Zone (MD) 1 9,440 8,781' Top Cement Plug (11 BELS) -- 9,440'-9,585' 2 9,585' 8,924' HES EZ -SV Cement Retainer 3 9,587' 8,926' Bottom Cement Plug (47 BBLS) -- 9,587'-11,165' 777 I=7- fish: Wash -pipe Shoe (L=4.35', OD=8-1/2" - D 7-1/8" 8-1/2" 1/8") 4 9,828' 9,165' Top of tubing fish is @ 9,833', Top of WP @ 9828' 5 9,836' 9,173' Otis "XO" Sliding Sleeve w/valve 6 10,480' 9,805' Otis "XO" Slidin Sleeve w/ valve 7 10,699' 10,019' 2.635" 1 1 Otis "Q" Profile Nipple FISH Item Top of tubing fish is @ 9,833', Top of W P @ 9828'. Hole and bad spots in casing from 9,772' to 9,838. See morning reports for more detail. Updated By: CID 11/29/17 ABANDONED PERFORATION DETAIL Top Btm Top Btm FT Accum Date Status Zone (MD) (MD) (TVD) TVD SPF Block cmt sqz 28 cult of class "G". tested to 9,765' 9,766' 9,103' 9,104' 1' 8 1/6/1968 5,000 psi. C2 9,836' 9,866' 9,173' 9,203' 30' 4 1/10/1968 Perf f/ Production Pressure tested to 5,000 9,950' 9,951' 9,285' 9,286' 1' 4 1/3/1968 psi, no break down CS 10,095' 10,130' 9,428' 9,462' 35' 4 1/10/1968 Perf f/ Production C5 10,150' 10,240' 9,481' 9,570' 90' 4 1/10/1968 Perf f/ Production C6 10,315' 10,350' 9,643' 9,677' 35' 4 1(10/1968 Perf f/ Production Pressure tested to 5,000 y 10,400' 10,401' 9,726' 9,727' 1' 4 1/3/1968 psi, no breakdown C7 10,535' 10,560' 9,858' 9,883' 25' 8 10/25/1968 Perf f/ Production C7 10,580' 10,660' 9,902, 9,981' 80' 8 10/25/1968 Perf f/ Production C7 10,675' 10,700' 9,995' 10,020' 25' 8 10/25/1968 Perf f/ Production Pressure tested to 5,000 10,750' 10,751' 10,069' 10,070' 1' 4 1/2/1968 si, no break down Isolated below retainer C9 11,135' 11,165' 10,442' 10,471' 30' 4 12/30/1967 @ 11,108' FISH Item Top of tubing fish is @ 9,833', Top of W P @ 9828'. Hole and bad spots in casing from 9,772' to 9,838. See morning reports for more detail. Updated By: CID 11/29/17 H Hikmry Alas4a. LLC Well Work Prognosis Well Name: Granite Pt St #24-13RD2 (GP 24-13rd2) API Number: 50-733-20080-02 Current Status: Producer Leg: Leg #3 Estimated Start Date: June 24, 2019 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 217-143 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Joe Kaiser (907) 777-8393 (0) 1 (907) 952-8897 (M) Current Bottom Hole Pressure: 3,100 psi @ 10,178' TVD 0.3051bs/ft (5.86 ppg) based on offset producers Maximum Expected BHP: 3,100 psi @ 10,178' TVD 0.3051bsKt (5.86 ppg) based on offset producers Maximum Potential Surface Pressure: 2,082 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary GP 24-13rd2 is a very low rate C-7 producer completed with Gas Lift. The current completion is a 2017 side track from the GP 24-13rd a shut-in injector. This project will convert the wellbore back to injection in accordance with Area Injection Order 11. � 4.:I_�o Last Casing Test: 12/27/2017 tested packer at 11,398' MD / 10,359' TVD to 2,100 psi on chart for 30 minutes Area of Review: Status of wells within 1/4 mile radius of injection zone: API Well No Permit Well Name Current Zonal isolation (method) Status 50-733-20080-02 217-143 GRANITE PT ST 24-13RD2- Producer 12/21/2017 CBL 7" TOC @ 8,930', 5" TOC @ 11,060' i 05/25/2017 Top of balanced P&A plug at 8,781' -Bridge 50-733-20080-01 180-116 GRANITE PT ST 24-13RD P&A Plug at 8,148' 10/17/1980 P&A by Retainer Squeeze @ 9,457'w/ 500 50-733-20080-00 168-005 GRANITE PT ST 24-13 P&A sacksqueeze 07/31/1997 5" TOC @ liner top 12,909' - 50-733-20471-00 196-014 GRANITE POINT 53 Injector 7" Estimated TOC 8,713' 09/30/1997 TOC at 9,440', EZSV @ 9,585' 50-733-20046-00 167-057 GRANITE PT ST 11-24 P&A 09/25/2017 Bridge plug at 8,028' 50-733-20046-01 217-123 GRANITE PT ST 11-24RD . Producer 10/30/2017 CBL TOC 9,910' 50-733-20188-00 1 169-054 GRANITE PT ST 12-24 SI Injector 07/09/1969 TOC @ liner top 10,624' Waiver Request: Iw/fac-K ? a[ Hilcorp is requesting a variance of 20 AAC 25.265 (b) to eliminate the installation of an automated surface safety valve due to this wells injection being incapable of sustained back flow. C-) pp_w pe H Hil.p Alk., LLC Well Work Prognosis During waterflood pumping operations, GP24-13rd2 will have a full fluid column of water equivalent to —4,510 psi. The current bottom hole shut-in pressure is ^3,100 psi. This is a pressure differential deficit of 1,410 psi, indicating the well will be on a vacuum until liquid level stabilizes. Hilcorp will install a check valve adjacent to the well tree to prevent any backflow to surface as good engineering practice. Pla „ 4/. Procedure: 1. Rig -up slickline and pressure test lubricator to 250psi low/ 2,500psi high. 2. RIH and change out all live gas lift valves to dummy valves. 3. RD slickline 4. Notify AOGCC for witness of MITIA to 2,600 psi charting for 30 minutes. 5. Initiate injection. Attachments: f}�� S /: 6 f �. % �� J /w r 'EA 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic µARS R31DJG2 3R1C RIIRRE PTI GPJ1•,3 GP 11.13 OP41.1 D, G .1 D OP. . DP-E-13RD OP 3 GP•3343RD3 15 W-3, 14 1 3 18 d 43 OP -3 D GP4T14 GPM -1 OP• D3 OPJ3-13 D W. AIO GP41 OP 3R03 GP -t3.33 GP R -L GR 23 22 2 19 GP43. OF -23_RR GP•N HILCORP / LASM, LLC 666666 (ADL 18761) �HITEMN1 OP43 [LOT GMxITEv NTwnTwxm�3E, •mwfuav J o. •w ♦ e+ PtEt W81 K Hilmrp Alaska, LLC RKB to Tubing Head 50.35' PBTD: 12,893' TD: 13,493' Max Hole Angle =100.32' at 13,493' MD SCHEMATIC Casing Detail: Granite Point Platform Well: Granite Pt St 24-13RD2 Last Completed: 12/28/17 PTD: 217-143 API: 50-733-20080-02 SIZE WT GRADE I CONN ID TOP BTM. 33" 50.10' Structural Tubing Hanger Surf 229' 26" 2.313" 4.91" Conductor Surf 294' 18" 70.59 B Ventura 4,530' Surf 592' 13-3/8" 61.0 1-55 Butt. LT&C 12.515 Surf 3,960' 9-5/8" 43 5 N-80 & S-95 Butt. LT&C 8.755 Surf 8,130' (TOW) 7" Tieback 26 L-80 DWC/C 6.184" Surf 5,830' 7" 26 L-80 DWC/C 6.184" 5,821' 10,893' 5" 15 L-80 BTC (KC convertible) 4.408" 10,449' 13,023' 9,247' 2.441" 4.75" Tubing Detail: 10,343' 9,752' 2-7/8" 6.5 L-80 3 8rnd EUE 2.441" Surf 10,395' 2-3/8" 4.7 L-80 10,339' 8rnd EUE 1.995" 10,395' 11,453' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item C-7 11,550' 50.10' 50.10' Tubing Hanger 1 373' 373' 2.313" 4.91" SSSV Halliburton NETRSV 2,544' 2,499' 2.441" 4.75" GLM #1 PSPO-1M Mandrels, R-1 Valves w/ BK -2 latches 4,530' 4,386' 2.441" 4.75" GLM #2 PSPO-SM Mandrels, R-1 Valves w/ BK -2 latches 6,050' 5,855' 2.441" 4.75" GLM #3 PSPO-1M Mandrels, R-1 Valves w/ BK -2 latches 7,132' 6,915' 2.441" 4.75" GLM #4 PSPO-1M Mandrels, R-1 Valves w/ BK -2 latches 2 7,900' 7,651' 2.441" 4.75" GLM #5 PSPO-1M Mandrels, R-1 Valves w/ BK -2 latches 8,542' 8,180' 2.441" 4.75" GLM #6 PSPO-1M Mandrels, R-1 Valves w/ BK -2 latches 9,090' 8,742' 2.441" 4.75" GLM #7 PSPO-1M Mandrels, R-1 Valves w/ BK -2 latches 9,701' 9,247' 2.441" 4.75" GLM #8 PSPO-1M Mandrels, R-1 Valves w/ BK -2 latches 10,343' 9,752' 2.441" 4.75" GLM #9 PSPO-1M Mandrels, R-1 Valves w/ BK -2 latches 3 10,394' 9,789' 1.983" 3.688" 2-7/8" x 2-3/8" Crossover 4 11,349' 10,339' 1.995" 3.625" GLM #30 GLMAX-1HP Mandrels, R001 orifice w/ T-1 latches 5 11,398' 10,359' 1.940" 4.125" Packer - Map Oil Tool MFH Hydraulic Set Retrievable w/ 30K Shear 6 11,446' 10,379' 1.875" 3.063" X Nipple 7 11,453' 10,381' 2.300" 3.00" WLEG Updated By: CID: 01/16/18 PERFORATION DETAIL Zone (MD) (MD) (TVD) (TVD) SPF Date Status Comment C-7 11,550' 12,810' 10,418' 10,696' 1,260' 6 12/23/17 Open Updated By: CID: 01/16/18 K Hilmrp Alaska, LLC RKB to Tubing Head 50.35' PBTD: 12,893' TD: 13,493' Max Hole Angle = 100.32° at 13,493' MD PROPOSED Casing Detail: Granite Point Platform Well: Granite Pt St 24-13RD2 Last Completed: Future PTD: 217-143 API: 50-733-20080-02 SIZE WT GRADE I CONN ID TOP BTM. 33" 50.10' Structural Tubing Hanger Surf 229' 26" 2.313" 4.91" Conductor Surf 294' 18" 70.59 B Ventura 4,530' Surf 592' 13-3/8" 61.0 J-55 Butt. LT&C 12.515 Surf 3,960' 9-5/8" 43 & N-80 & 5-95 Butt. LT&C 8.755 Surf 8,130' (TOW) 7" Tieback 26 L-80 DWC/C 6.184" Surf 5,830' 7" 26 L-80 DWC/C 6.184" 5,821' 10,893' 5" 15 L-80 BTC (KC convertible) 4.408" 10,449' 13,023' 9,701' 9,247' 2.441" Tubing Detail: GLM#8 PSPO- SM Mand rels,—(Du m my Valve) 10,343' 2-7/8" 6.5 L-80 GLM#9 PSPO-SM Mandrels, — I Dummy Valve) 8rnd EUE 2.441" Surf 10,395' 2-3/8" 4.7 L-80 11,349' 8rnd EUE 1.995" 10,395' 11,453' JEWELRY DETAIL No (MD) Depth (TV) ID OD Item C-7 11,550' 50.10' 50.10' Tubing Hanger 1 373' 373' 2.313" 4.91" SSSV Halliburton NETRSV 2,544' 2,499' 2.441" 4.75" GLM#1 PSPO-SM Mandrels,—(Dummy Valve) 4,530' 4,386' 2.441" 4.75" GLM#2 PSPO-SM Mandrels,—(Dummy Valve) 6,050' 5,855' 2.441" 4.75" GLM#3 PSP0-1M Mandrels, — (Dummy Valve) 7,132' 6,915' 2.441" 4.75" GLM#4 PSP0-1M Mandrels,—(Dummy Valve) 2 7,900' 7,651' 2.441" 4.75" GLM#5 PSPO- 1M Mandrels,—(Dummy Valve) 8,542' 8,180' 2.441" 4.75" GLM#6 PSP0-1M Mand rels,—(Du m my Valve) 9,090' 8,742' 2.441" 4.75" GLM#7 PSPO- SM Mand rels,—(Du m my Valve) 9,701' 9,247' 2.441" 4.75" GLM#8 PSPO- SM Mand rels,—(Du m my Valve) 10,343' 9,752' 2.441" 4.75" GLM#9 PSPO-SM Mandrels, — I Dummy Valve) 3 10,394' 9,789' 1.983" 3.688" 2-7/8" x 2-3/8" Crossover 4 11,349' 10,339' 1.995" 3.625" GLM #10 GLMAX-1HP Mandrels, 13001 orifice w/ T-1 latches 5 11,398' 10,359' 1.940" 4.125" Packer- Map Oil Tool MFH Hydraulic Set Retrievable w/ 30K Shear 6 11,446' 1 10,379' 1.875" 3.063" X Nipple 7 11,453' 10,381' 2.300" 3.00" WLEG Updated By: JUL 06/04/19 PERFORATION DETAIL Zone (MD) (MD) (TVD) (TVD) SPF Date Status Comment C-7 11,550' 12,810' 10,418' 10,696' 1,260' 6 12/23/17 Open Updated By: JUL 06/04/19 R Hflroap Atawk.. MA: Granite Pdnt Platform GPP 20.13802 M X 133/8 X 95/8 X 2 X 27/9 Tubing head, Cactus-C29L, 115M FE top and bottwn, prepped f/ 9" BG bottom, w/ 2-21/165M 550 AtIachemenbpod, DCB, 13 5/8 5M API hub x 11" 5M FE top Unihrad, OCT type 2, 13 5/8 5M API hub top X 133/9 BTC caAng bottom, w/2 2" LPO on lower section, 2-2 1/165M 550 on upper sectio,, IP internal Inakpin asst' Starting Mad, OCE, 211/4 2M Hub x 24 X 1M Hub w/2-2" LPO, prepped f/18" ON hanger Cmduaw hooding, OCT, 24 N 1M Hub X 24" Buttweld 9HTA Bowen, 3 1/8 5M FE X Granite Point GPP 24-13RD2 tie -back 06/05/2019 Turing hanger, TC -IA EN - RL 31 X 3 X EUE IIM1 and susp, w/ 3Type H BIN profile, 2-X"1ont SCSSV pmts, alloy material Valvg SSV' 'Win6. WKM N, 31/9 SM, w/1, VW oper • 6 00 0 0 0 N J N O ` co • .COoCO00 0 •c cC o 0 E v. rc NZ M a ) co co •N ) 07 m N N )C m T co U Nco _ > 4 ❑ 4 4 4 4 .N N C N N C co E t` ❑ } N N 0 N N N N T C LLL T .0 .� C lLL • N d J d t1 d d @ LL O a) a) it 0 7 co C9 J (7 CD CD CD C 0 > C 0 0 ❑ 0 Q F" N N Z N N N V aI N N H aI N N N N H N Z Z E EZ E E— E EF ❑ ❑ ❑ ❑ ❑ 0 c 0 0 0 0 _ = o co co O) co CO ctJ cKJ I l a —) aJ I d I U) CO3NI N N o N N ❑ MQ 2Q 0 M co Q' coa, M Q @ LLL ii it it ii= 4Z4Z 4 4 Z 4 Z 4 0 . Q 0 J NH NI— N _1 N N N F N F N '� a) I a) C aQ a) a0 o d °I dct d a_ 0- °I 0- °I 0- _1 E.,". CO W V) - V) Co CO 2 O tr CD Cr 02 0 C0 0 tr 0 CL 0 c C I QQI aai a)Q a)Q ac @w m @u) aiaiaiv) i N ❑ ❑ .- ❑ @ ❑ c ❑ f it lit lit it ,... it LL I LL I LL to E U U U 13 CO U �j U U U U I 013 0V U U U m C 'C O N 'C O C O 'C C 'C I 'C C7 'C C7 'c I 'C c) 'C c C� 'C U C L o o❑I co o0 00 om oQ o❑I o❑I oQ o a) o 0 o ❑I o ❑I o r V Cn ts0 To DC7 qtr �p is DC7 DC7 ail a Z a Z t0 t0 N m C N m N❑ N J N M N m N m N M N 7 N m CO m N m N ce J WQit WQ WQ LTJ Q W — WQ WQ W ,— WU) WU) LL1Q WQ W 0 Y 0 Co00 00 CO co v0 1 . o 0 0 0 0 0 0 0 0 0 0 0 0 J U .> N N N N N N N N N N N N N WQ V CO cD cococ0 co c0 c0 cO cO cO cO cO W 0 o J C7 x x V = o I'�3 Z 0 c) Z - `Z Q O �_ CoJ a 01 Cn co O _ O v Co - v o d — 0 co yco co co ^J o. cO O Z Li. 0 co < C t+ «) CO Li) N 6) O in ii= CO O W G a N CO CO zs O Co co Co 0) O N N la (99 el EE '" 0 OF, 0 m m C o J7 O ... CI p OC Z c) 0Oh CO r w 0 e6 o N C N N Z G H N N°) O m co F W J co N "-, ,...t CY CO z 0W oo CD• o op Q a ❑ O J Q Z d U o1 Z E H co -o 0 Z o 0 CO CO CO CO CO CO CO CO CO co CO CO CO N N Q N (6 CO co co co co co co co co CO co co 3 CE ❑ 0 0 0 0 0 0 0 0 0 0 0 0 o CD ort, co co o) co co co m m m co co m 0 Z rn O) O O) 'o) 'p) Q) Q) 0) C) Q) Q) I& C p 2 0_ ` 0 0 0 ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ 0 co > _p CL 0 m N Lo u) u) cn u) �) r) r) cn r) H N V V v V V V V V V V V V - H t) CO E O) O) O) co) 6) 0) O) 6) O) O) 6) O) O) h Q Z d C N N O Co co Co oo co co co co co co co co CO 2 0 C O Ti 0 z N N N N N N N N N N N N N N 0 H CO E •E' LL Q co ,_ O •" LL O CA — 1 IL N 01-- w W LL O p m U w Z J o =' 0 0 0 0 0 0 0 0 0 0 0 0 U U ., J C7 N• ❑ �',, 0 H w CI) -6,-, m a p ❑ 0 0 0 0 0 p p p p 0 0 ¢ n 0 J 3 J CO 0 H W W W w W W W W W W W W W • • 0 N .. N T ''; > 'O > 'p > > _ • . • of O Z N CO N co N •'� V w I 0 N co co N ° °I CIL O "• _1 LL X LL x T m V I E E E E E N w c c FIii c N 0 R 0 E v n O 10 a W 0 0 T T i76 mi LL >. lL LL T a x J J a ci a )l) N N N N N aI aI N N~ aI N 2 NI- al v N V E �1 WI ~I ~I -o v Z 0 0 0 0 0 H '- 00ce- 00 '- 00 00 r N E 0 0 0 0 0 0 N N E M M M M M D 0 M QI M QI 01 M QI M QI 01 u) c re ce re ct re re co M M M M M 'O 'O a v v v v v v � v � 4Z 4Z c� vZ 4Z 4 1,7 v v v v v v .-- c., N N N N NJ NJ NI- NI_ N--I N~ NI- NJ M a a a a a 2 aR U°1 O°1 aC O°1 QUI aR W N a a a a a a a p i0 0 0 0 0 02 02 OX OcC 02 OW Oce 02 H u) 0 0 0 0 0 0 o o O ai ui ai ai ai ai u) ai CO ai Q ui Q gi CO ui Q ai Q CI)Cnl § @ ai ai ai gi ai ci ai hi Co U U U U U DLL DLL Um Um PLL UX 0X PLL 0� 0 0 U 0 0 0 0 0 U 7 •c •c •c •c •c E E c 6 •c i5 c 1 •EEE I O •c •c •E •c •c •c c c c O O O O O O N O N O 0 O 0 ON O 0 O 0 O N M W O O O O O O O O O N 0 «0 .`. I I 0 .1.. I I 0 .70 L. I V V) N N N N N N M N M N m N m N M C.>0 N m N M 'E. < N N N N N N N N N I~i J , W W W W W W W .. W< W< W- W< W< w,- N 2 W W W W W W W W W 0 Co'5 co co co co co co Co co co Co CO co . . . co . . . . CL g 0 0 0 0 0 O 0 0 0 0 0 0 O O O 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N N N N N W a COCOC00060C0 CO W 0 J zo o Co Q C J 0 o O. • w 0 C 00 O O M C r O 0 co co O N To. E V o O o Q N ct N ♦ Co N. a O C N N MG ~ N W N a CV o f ao Q c a CI Z E m UI c c E co Z u) CO CU m CO f0 N CO CO CO CD co co co N f0 C6 N CO CO f0 CO f0 CO '. d N f6 f6 C6 CO f6 CO CU CO f6 CO f6 f6 IO V CO CO CO RS N f6 CO f0 CO n 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o co co co co co m (U CO CO o) m .CO m I co m m m CO co m co m 'En -(5) •m •E) 'En' '5) co) •E) o) o) orn to 0) '3) 'En 'En 'En 'En 'En '5) 'En •o) 0 D D D D D D O a a a D D D J 0 0 0 0 0 0 0 0 0 0CO > Co Co Co CO 10 Co Co Co in C0 Co co CC) co Co Co CO CO Co CO Co CO CO 44. F- V C C C V V V V V V V V V V V 7 d• V V V V 0) 0) 0) 0) 0) 0) 0) O O O O) 0) O) O) O) O) O) 0) 0) 0) 0) 0) O) n CO CO CO CO CO CO co co co co CO co co co Co Co CO CO CO Co CO CO CO N N N N N N N N N N N N N N N N N N N N N N N N F M O °) V o M , `— 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 E • m 0 D D D D D O D D D D D D O o 0 0 0 0 0 0 0 0 0 d 2 W W W W W W W W W W W W W J LU W LU W LU LU LU LU LU • i o r 0 r r r ,- r r r r r r ,- .- r r r ,- r T 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 o ca c o a a 0. 0. 0. 0. a a 0. a a a a a a a a Z a) a) a) a) a) a) a) a) a) a) a) Cl) Cl) U) U) U) U) N X X X CC d X CC CC CC CC CC X X CC X X W T M C) 0) 0E) 0) o) 0) 0) Eo) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) (q C C C C C C C C C C C C C C C C C m r, c c E c E c c c c c c c 0 0 0 0 0 0 0 0 0` 0 0 0 0 0 0 0` `o 0 ci E N N N N N N N N N N N N N N N N N Z 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N a' a' a' a' a' a' a' re ce a' a' a' a' a' a' a' ce Y. P. _M M M M M M M (+) co co_ _M M M M M M M Q Ch • R V 7 V 7 7 V V d. . . . . . . 4 N N N N N N N N N N N N N N N N N N a a a a a a a a a a a a a a a. a. a o) 0 (.7 0 0 0 0 0 C) C) 0 CD C9 CD CD CD 0 0 ( U) U) as as as as as as N N as as as as N N N N Ll it. LL LE U. LL LL LL it it it 11 it it LE it it it C) U Uw C)4- U U U U U Uw Ur- Uw Uw U 0 0 Uw Uw 0w Z 'E 'E V 'E V c'o E'a "E V E V E IR •E 74 •E V •E •o 'E •° E 34 •E V E V •E 14 •E V 'E 7, 0 0 4- 0 4 0 4 o — o — o �- o �- o °- 0 4 2 — o — o — o — o — o — 2 — o a Imm (p 0 0 - i)r 0,- c8- Ns- Ns- �s �.- t— N.- N.- N.- 0.- N.- d.- �e- 0 oe J N . . a), 0 0 N M V In (O n CO O N M J N W M2 Mo W.- W.- W.- W.- W.- W.- M.- W.- W .- W,- ON MN ON MN MN 0 / = Co co Co Co Co Co Co co co co Co Co Co co co co Co Co a g U o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N W Q 43 43 CO CO Cfl (D (O c0 c0 (O (O 43 CO (O c0 cfl CO (O cc ✓ r r r r r r r r r r r r r r r W 0 U • 0 Z a_ w J a• @ ' 0. ° Oco va N E U ill Q 0 g M t` 4 O 5 N N /2 ~ N W co y- a p w a) CO I— Z al oI QCD c o a) Q 0 a Z E o Q ▪ U m Z 0 CO m a) CO CO 0 CO m CO 0 a) CO m m CO o m O N 0 0 0 0 M 0 (0 0 0 0 0 0 M fO fO fO fO 0 r 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o as (0 (0 CO CO CO (0 CO CO CO Cl) CO CO Cl) CO CO CO CO 10 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 M > o o c0 c0 (o Co o Co (o o c0 co Co co o co o co. er F Cr C) C) C V V V V C) C) V Cr V 0) V 7 7 V r 0) 00) 0) 0) 0) 0) 0) 0) 0) 0) 0) o) 0) 0) CO 0) CD CD CD CO CO CO CO CO CO CO CO CO CO CD CO CO CO CO CO N N N N N N N N N N N N N N N N N N N TE M O V O co w 0 U 0 0 0 0 0 0 U 0 0 0 0 0 0 0 0 U F . F.• 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a. 2 W W W W W W W W W W W W W W LU W W W I • c. • c . • N r r r r r r r r r r r - o 0 0 •co CO a a C U J J U U "C "C "C -C "C 'C r r V C . . 0 C C G 0 O O O O O O O O O O O C C C 0) O) cc c 0 1 0. a a 0. a 0. a a a a a a r • o o E E O Z 0) a) a) a) 0) 0 0) 0) 0) a) 0) 0) o W f0 T >. N C' CC d' a' CL CC 2' CC R' Cr CC d' 0 N E E 0 0 > CA CO O) O) CO 0) 0) C) 0) 0) O) d' O) O) 4.1 ? C O)C C C C C C C C C C C > L0 l0 C C g' E E •E •E E E E E E •E E m o O O O O O O O O O O O O 0 C c C 'e) 2 2 2 M M 2 2 2 2 2 2 W it CO i0 0 0 C N N N N N N N N N N N N N N N N N N Z 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Ce CC CC Ce Ce Ce Ce Ce CC W Ce W Ce ft CC CC It CC Er. M M M _c) CO_ M M CO CO M CO M M M c C7 M M Q 4 4 4 4 4 4 4 4 4 a 4 4 4 4 N N N N N N N N N N N N N N a Q. a a 0- a a a a a a a a s a a a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 R 0) 0) 0 0 as 6 6 0) 0) 6 6 N 6 N N 0) as 0) u LL it LL LL LL LL IL it LL It LL LL it LL. it it it•.Q LL C U..- U.4- U_w _U U U U..- U..- C..).u- U w 0 w 0..- U 0-0 C.) C.) 0 a 0 • 0 0. co cv0 cv Cv c '0 c-0 C"0 cv0 ca cv cv0 cv cv0 c c 0 c c'.- E E0 00 o0" o0- o - oa oa 04 04 04 00. 04 04 0 0 -e o13 oa o0 0> @ y� U O a H (4 (D i) v ( U ( ( (0 (D a v a a v> v rn o) J N L N C 0) ^ N co 0)co _N 0' _N_ _N N 0) 0).a _N N N E) a) 0)0 0)> N O 0 O Ce J ` WN WN WN WN WN WC) WO WO WO WO WO WO W WLe WM WH WJ CU_1 0 0 co co co O W co co co co co co co co co co CO CO CO Om g 0 0 0 0 0 0 0 0 E. 0 0 0 0 0 0 0 0 0 N N CO N N N N CO N CD N CO N N N N N N N CO N N N W w < W Z o• q Q J o co CL � � o Oo• a N V1 t> 0 o Q N0 oh :a Lr CCM ■ P N N C f.. M /cam N N W F- n a w a, CO z 0 Q 0 o m 1' Q o a coo z 2 co co co co co m 0) co co m m co co co 0) m CO O N 1 0) CO CO @ CO (0 fd l0 CO 0) CO co CO CO 0) (0 00 CO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Ho CO co co CO CO CO CO CO CO CO CO CO CO CO CO CO CO - o) o) rn o) o) "m rn C) "rn m cm m o '0) t0 rn rn 0) c 0 0 0 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 cl > co (0 CO CO CO CO CO (0 CO CO CO (0 CO CO CO CO co CO et I ,v v v v v v v v v v v v v v v v v . r 0) a) o) 0 0) 0) o) o) o) a) o) o) o) 0) o) o) o) o)• • cc co co cc co co W W cc W co co cD W co co co co r N N N N N N N N N N N N N N N N N N N co o M0 w - 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 £ • d 0 ID 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 d 2 W W W W W W W W W W W W W W W W W W 0 • o 1 o oo o o U 0oo J • •U v v J J CC C C CO CO C) C) m m J J N N >O J J 0 a aOJJ E E 0 0 N O O O O E E E E 0 O O O O O E o LL LL A M U - U U 0Ce W p m m U U a a II' € E co v, '0 0> W a E E y 0 0' 0 In 1 U L.L. C7 C7 J J In in 0 0 LLL IL (7 0 J 6 N N N N N N N N N N N N N N N N . . Z 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 m co cc CC ce a' a' a' a' a' [Y a' a' co co QM M M M M _M M M M M M M M M co M < < 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 2- 2- N N NN N N N N N N N (N N N N N 0 U a a a a a a a a a a a a a a a a 0) m 0 CD CD CD CD (7 C7 CD C9 C7 C9 CD CD CD C7 0 2 a =a O ai 6ai 6 66 6 6 6 iiiai i 6 6 ai 6 6 45 4, ai b LL L• it it it it it i it ii y- i it it t I • it IL M it m co U U U U U U U U U 4-•, U '•'• U U U U U U U U T- Z C •C •C •C"- •C •C'.- •C -C C C 0 .0 •C •C C 'C •C •C •C m O-'gyp ° a 2 2R O-p 2R 21.. E".5 22 OOH 2..- 217 O,.- O:E 12 .- O:t 20 20 V to , ii0 ami> CDCI aa)> CD0 15 > a"i0 aa))° N o Q)) o a 15 0ia .i> co0 CD 00 amiCI a°)> amiM a�0iM IX J Ii W 2 W F- 63 2E W F- W 2E W F- W 2E W� W J W J W 2E W F- W 2E W ~ W 2E W H W� W.- O ` !ao co ao co co co co CO co W co co a0 co co co co co CL (00 ,io 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N LU I(aCO1-5 COCO Ce Lt. W 0 J " V o Z a 0 0 d 7 CL 0) . 00 0 E C) U J v el OA czt re r- ‘- 4 v o N 5 co N CO ~ N W co a p w cu 01 Q g 0 c o ' °) Q O a z E ' )a z a) co m a) a) m co as co a) co a) a) a) co m co co 3 N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a) CO CO CD CO CO .a CO CO m CO CO CO CO CO CO CO m c !0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 co > ,co co m m co co c0 m co co co co co co co co m co v ,C) a a a a a Tr a Tr Tr a Tr Tr a a a .4- C) r m m m m m m m m m m m m m m m m m m P Ac M co co M W co coN co co co a0 co (N (N co co (N N N N N N N N N N N N N N N N N N N N M 0 m , V r « O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 P. a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a. 2 W W W W W W W W W W W W W W W W W W 11111, • o I • o v v v v v v v v v v v v v v v v v v CO N N N N N N N N N N N N N N N N N N 7. CO a a a a a a a a a a a a a a a a a a t o Z U C5 C7 CD CD U U U 0 U U 0 U 0 0 U U U N LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL CI) U a a a a a a a a a a a a a a a a a a II. C7 U U 0 0 0 CD U C7 U U U U C7 0 0 0 U - U U U U U U U U U U U U U U U U U U C J J J J J J J J J J J J J J J J J J ID J J J J J J J J J J J J J J J J J J 6 CO Y Y Y co co co Y Y Y Y Y Y Y co co Y Y co Y Z to co co co co m co N to co co M co co co N co N ^ co co co to co to co co co m co m co co co O co N B: Q Q Q Q Q < Q Q Q Q Q Q Q Q Q Q Q Q EL e C? e EL e a e e e Q EL e e" UU d� U d� U d� U d� UUU d� UUU d� U � U d� U d� U � U d� UU cn J S I . 2 I . 2 I. I . 2. S.d 2.d 2 I. .d S.d 2 I. S.d S I . 2 I . .Q . .d X. y0 ,D CD 00 00 00 00 y0 yO 00 y0 00 y0 wO 00 00 00 ca c) y0 OD V r O M OD CO CO N ( (N St r O M CO I1 m I1 O it O Il O LL ,- LL— it�— LL�— LL LL N LL N it N it M I1 co I1 M LL v ii v it v O U O U U U U U U U U U U U U U; U; U U i C C •C •C C •C •C C •C C •C C C C .0— C C C O N O N O N O N O N O N O N O N O N O N O N O N O N O N O N O N O N O N ` co 2❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ r v CL v CL t3 re ti ce %ice %6� T.')Lt iii 6 cc U� i re U� 6 w 6� �r its �w v ce _1 0M OM O 2 OM a)M M CDM 0M 0M M 0M Q)M CDM OM OC7 OM M CDM J N w w w w.- W w w w w w w w w W r• w.- w.- W w OW co co co co co oo oo oo ao W co co oo co co co Ci. 3 U 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N W tDCOCOCB CB COZro Cl.IX r r r r r r r r r r r r r r r r r --- W • J V = o Z QI. co O O J0. w CL O u) '. 03 O � N a E U ilj 0 o Ja) `<` Noh � : 1 ft M r l_ 5 N N MG N M W W 1.- a. a CO I- o ICC co Q o Z Eo I, 0 E U ca Z (o co co co co co co co co co co co co co co co co CO CISrl's co co co irs' co co crs co as co co co 3 N r a a a a aCO 00 al (6 a ❑ ❑ ❑ ❑ in ❑ ❑ a ❑ ❑ a o co �a coo ca co co co as co co �a q a co co co co co :� cn :� :� , C ❑ a a a a a a a a a a a a a 6 a b a a el > co co co co co co co co co co co co co co co co co co ' Tr F v v v v v v v - v v - - . . v v v - rn -a- as a) a> a) a) rn rn rn cc rn co cc co) rn co) rn rn ti co co co co co co co co co op w co co co co co co co ✓ N N N N N N N N N N N N N N N N N N N .` CO CI O) V O co w ,- 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a) ❑ i❑ a a a a a a a a a a a a a ❑ ❑ ❑ ❑ a Iw w w w w LU w LU LU w w w w w w w w w L 0 • 0 . 0 o v v v v v v v v v v v v v v v v v v N N N N N N N N N N N N N N N N N N T CO O l a a a a a a a a a a a a a. a a a. a a ro o z I CD 0 00 0 00 0 0 0 CD CD CD C7 0 0 CD 0 CD 0 N LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL >+ 01 U 'a a a a a a a a a a. a a a a a. aa. a 5 0 CD 0 0 0 CD 0 0 0 0 0 0 0 CD 0 0 0 CD U U U U U U U U U U U U U C.) U U U C.) o I J J J J J J J J J J J J J J J J J J in 1 J J J J J J J J J J J J J J J J J J O co Y co Y CO CO co CO co Y co Y Co Co CO co CO co Y co Y co Co co Z co co co co co co CO co co co co co co co co co co co a < < < < < < < < < < a < < < < < < < EL a a a e- a e- e- a a e- a e- a a a a a S J 20 a a a a a a a a a a a a a a a a a y. S X. 2 . 2.� 2 I . 2 I. _I . 2 I . 2 I. 2.� S. _ . 2. 2.� 2. S . 2. 2 I. Q aj O aj O o O aj O 00 aj O aj O aj O aj O aj O aj O aj N_ o O aj O o O o O_ aj O aj O O N In Lo ro 1� O M N- O N W C 0) lL d' Ern Ito IL� I1 CO Il CO I1 f0 ll I� I.L � lL h 11 f� I.L 00 Eco Il 00 Eco LL O) lL O) lL O w U‘- .0— .0— 0`-* .0‘- .r.)‘- .c.)‘- 0. - U� .0� U— 0'- c>� U� 3.)7 U7 U7 U7_ _ C C C C C C C •C •C C •C •C C C C •C CC O N O0 0 O N O0 0 O0 0 O N O N O N O N O0 0 O0 0 O N O N O N O N O N O N O N V co a a a U� ta itc ita iia cta Ua Ua Ua to ta Ua iia tw Ua ., J N N N N N N N N N N N N N N O N N �/ M ,-,co M M M M M M M M M M M M M M M M J N W W W .- W W )- W,- W )- W ,- W )- W., W)- W W W )- W )- W,- W W,- 0 1 `= — 00 00 co co co a0 00 00 00 00 00 co co co a0 00 00 0.. co 0 0 0 0 0 0 0 o s o 0 0 0 0 o s o N N N N N N N N N N N N N N N N N N W (a N43 CO Ce re r r r r r r r r r r r r r r r r r r r r r - r r r r r r r r v- ...... W 0 J C.) ▪ o Z 8 Q L. N J co co 0. ° W CO G g o O N a E J Q N03 Ilm CeM r 4O 5� N N CO F- CON N F- O. p w a 0 Q CDco ra) Q c a zE G -ib- 0I co z N N N co (o co co co co co co l6 co co co co co f6 co co ,- 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 oI co co co co co co co co co co co co co co co co co CO 0 '0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M > c0 co co co c0 co c0 co c0 c0 cC c0 c0 c0 co c0 c0 c0 a •v V v v v v v v v v v v v v v v v v rn o) 0) a) a) a) a) a) a) rn 0) 0 o) rn 0) a) a) a)n w co co co co co co ao CO CO CO CO co co co o co CO N N N N N N N N N N N N N N N N N N N ` M O V O M .-�" U U U U U U U U U U U U U U U U U U E • d 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a M W W W W W W W W W W W W W W W W W W i • O _ N O' tii NN ETTI N N N FTI aa a a 00 U U U LL LL LL LL LL a a a a a U U U U U J J J J J J J J J J co Y Y Y Y N N N N co") co") N N N 7l < Q < < < Q < < < < Q < Q Q < < Q Q E' e- e- E" E' EL EL EL e- E' U O O O 1.3 O O O O O O O O O O O O O O O OE O O O E O V O -902- Oe O e O (32. E O e O J 2 O. I.d I.d I .a I a = a 2 a =a 2 a = 2. = O. 2 Q = O. = O. = a 2 Q. = O. = O. Q N O 6b N Q N N N N N N O N O N O N 00 N M N 0 N 0 N N N 0 N C N O UO I1 O LL O LL O LL I1 LL LL N LL N LL N LL M LL M Eco Eco LL 4 LL d' LL V IL tO N O N O N V N O N V N V N U N U N U N V N V N V N V N O N O N O N O N V N 7 C C T C C C C C C C C C C C C „ C o, c" c „ C , 20 O N 20 20 O N E N E N E N E N E N E N E N E N E N O N O N O N O N o o o �o .o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 co Ua O O O UQ Ua Oa Ow Ow Ow O Ua OQ Ua Oa' UQ Ua tot IX J O) N _N N _N _N _N _N _N o 0) O) _N _N _N O) N _N M M M M M M M M M M M M M M M M M M J W W W W W W W W W W W W W W W W W W 0 W cc W W CO CO '33 a . o 0 0 0 0 o s o s o 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N LU CO (O CO c0 CO CO (O CO CO CO Cfl CD (O CO cfl CO c0 0 IX re r r r r r r r r r r r r r r r r Wo o U J J = o Z T g 43N J o c a. N 2 - o Tfp 1 Co 0E 05 U o Q Nis D re M n r O N N 2 ~ N W NCV ~ a M Lu o CO ~ co 0 Q Q O a z E o Q £ U ca z m m m m m m m m m m m m m m co m m m d N '�.t0 CO CO CO t0 t0 CO CO t0 CO CO CO CO CO CO CO t0 CO n 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o Os Os m CO CO CO CO m CO co CO m CO CO os m CO CO cn o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O co > co co co co co co co co co co co co co co co co co co v v v v v v v v v v v v v v v v v v T O 0 0 00 0 0 0 0 0 0 0 0 0 0 0 0 0 n o 0 00 o CO CO 00 (N o W 00 co W W W o 0 N N N N N N N (N T N N N N N N N N N N N N E M 0 o M O T y U U U U U U U U U U U U U U U U U U E • d 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a. M w w w w W W W W W W W W W W W W W W • • 0 O - N O V 4 7 V R 4 V 4 V . d' V V V 7 V V C N N N N N N N N N N N N N N N N N N >, CO O a a a a a a a a a a a a a a a a a 0 ,ca 0 z C9 C9 C9 C9 C9 C9 C9 C9 C9 U C9 C9 CD C9 C9 C9 C9 U co N LL LL LL LL LL w L_ LL LL w LL LL LL LL LL LL LL LL r) U a a a a a a a a a a a a a a a a a a. g (9 C9 C9 0 0 0 C9 C9 C9 0 C9 C9 C9 (9 C9 C9 0 (9 ki U U U 0 U U U U U U U 0 U U U U U U ° o J J J J J J J J J J J J J J J J J J N J J J J J J J J J J J J J J J J J J O co Y co Y co Y co Y co Y co Y CO CO CO CO co Y CO CO Y CO Z 0 0 0 N 0 C) U) 0 0 N N (I) N N N (0 N N co co co Co CO Co co co co Co CO CO COCOCOaCO co Co Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q (t e- e- E- E• E- E• E• E• e- E_ E- 2- E- E• e- E- e- EL 12 en O 0) O C O C O En 12 C O C O C U C O C O O O C O O C O C) O CD O O cn O J 22. 20. 20. 20. 2a I. Sc- 22. 20. 20. 20. 20. 20- Z2- Z0. 20. 20. 22- '60 '6 c) QjO 6O yO 6 6O 6 yO 6_O 6O 6O 6 6 6O 6O 6O QjO U. ))) U. 011 000 LL CMO IL co u:cco Il n Il n LL°r° LL O co Il LL co LL 00) LL C) LL O) 11 00) LL O LL O U) O N O N O N O N O N U N U N O N O N O N O N O N O N U N O N O N O M O M 7 C C C N C C N C T- C N C N C N C N C C N C C C C C C N e N O N O N O N O N O N O N O N O N o N O N O N O N O N O N O N e N e N co 0 0 0 t-0 1-0 1-11 0 0 0 „I,0 0 15 re 1.5 CC ti CC i)� DS CC v� 15 Ce 15 CC UCr 'Li CC 15 re ti cc i)ce i)ce — va 5w i)ce IX J U a)M O M O 3 O M j M cll M M M CD M O M O M O M j ? M M M O MCD c,„ J C CO y- wy- 65 y- W y- di di y- wy- di y- di y- COy- al w.- y- al y- di y- al y- di w Og _ Co Co co Co co Co co co co Co Co co co Co Co Co a c o 0 0 0 0 0 0 0 0 0 0 0 0 0 E. 0 0 E. N N N N N N N N N N N N N N N N N N LU (aZo 45 Ce 0 r r r r zz r r r r r r r r r r r r r r W J U J Z o a oglIC 6 N a`) J o CL cn co O � N o_ E U o Jli a s .� LL CC N. r 4 O 5 N N Gco M COco N ~ M w CV w a) F CO m 0 a g 0 _o O m a O a Z E o G £ U co Z CO as m a) m CO CO CO CO CO CO CO m m a) CO CO M =0 ) N 03 CO f0 @ (0 co co co co f0 fa tco (a N co co m , 0 0 a a a a a a a a a a a a a a a a O Co co co co co co CO co CO co Co co CO Co CO CO CO Co O a a a a 0 a a 0 a a a 0 0 a a a 0 O o"> > O co Co co co co co co co co co co co co co co co co. et F C) v -4- v v 0) 0) 0) 0) v v v v v v 0) v N. rn rn CD CD 0) 0) CO 0) CD CD C) CD CD CD CD CD CD CD ts CO CO CO Co CO OD 00 CO CO Co 00 Co CO Co OD CO Co N N N N N N N N N N N N N N N N N N N N .` cn O CD o w - U U U 0 U U U U U U U U U U U U U U E • d a s a a a a a a a 0 a a a 0 a a a a a d M 1 W w w w w w w LU w w w w w LU w W w w • 0 0 'S c o N N N N N N N N N N N N N N N N N N N CO p, 0 0- a a LL LL a a LL LL LL LL a n. LL LL LL cs o z iO 0 0 O O 0 O O O O O O 0 0 O 0 O N N i LL LL LL LL LL LL LL LL LL Il LL LL LL LL LL LL LL LL w T es v a a a a a LL a 0.. a a LL a Cl. CL a a Cl o n 5 '0 0 0 0 00 0 0 0 0 0 0 0 0 0 0 0 0 O a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N J J J _I J J J J _J _J J J J _I J J J J 4 E. J _J J J _J J J J J _J J _J J _I J J J J a— co c6 CD N co co co as N co co co co co N co co co O o Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Z CO co Cl) CO N CO CO CO mm CO CO CO N CO N CO CO- - CD Co CQ CO c6 co co CO co co co co co C6 CD Co co co < < < a < < < < a a < < < < < < < <C) 4( 2- EL EL EL a e- e- e- EL e- 2- EL e- e- e- e� e-°' EL o 0 0 0 0 0 o O o 0 0 0 0 0 0 0 0 O `2 rn `• m `• rn `—' rn `—' co CD `3 En `—' rn `2 C) `2 C) `2 rn `2 co CD `—' CD `2 rn ° O) `. co `13 t J °- (1 d d d 0- 0- d d d °- °- 11 d °- °- °- 2. 2. 2. 2 . 2 . 2. 2. 2 . 2 . 2. 2. 2. 2. 2. 2. 2. 2 . 2 a O o yo a)o o 00 4)o a)o a)o a)o yo a)o yo yo a) u") a)o a)o a)co o m r W Q h O M CO O N t0 r D) 4 r CA I1 O CE LE CL I1 NCE N CL N CL N CL M CL M L M Cit M CL V CL v ll V U:V CL Tr I1 coM M co co co co co co co N N N M M M M CO U,—C1U U U U U U U U U U U U U U U V p . C C C C C C C C C C C C C C C C C C . O N O N O N O N O N O N O N O N O N O N O N O N O N O N O N O N O N O co UQ' U(L' w Ud' U!Z' UC ULL' ULL' UIX ULL' Ud' Ud' UQ' ULL' UEI Ud' UR' tJN IX JO M O M O M 0 M O M O M 0 M W M W M 0 M 0 M 0 M O M 0 M W M 0 M O M o o N J W .- W W W W W CO W W W W W W W W W CO r- W 2 0 1 ' W co co co co co co co co oo co co co co co co co co CL u) U O O ‘.- co O O O O O O O O O O O O O O O N N N N N N N N N N N N N N N N N N W (O CaCOZa ODid a/ I`- rr 0 W 0 U J Z • of Q .+ COt 7 J °• o a ° � � o s O • N 0 05 o J Q CI 0 Nto re a � M C— r r• 4 O N N ~ N M co W M 0. H O N Q C0 0 0 1.• N Q ° C z E▪ . Ci VI, co Z coco coo co coo co o co co co co co co co 03I CO CO 3 N COm c0 COco o' co co N co co co co co co co co f6 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N. O co co co co co co co co co co co co co co co co co co a a C a C a 0 C a C C .E 5 a C m .5 C) 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C') > coo co co co c0 co co co co co co co co co co co c0 er I— v v a V V V a v V a V v v v v v v 7 rn rn rn o o rn rn o rn co rn rn rn co co 0 o) m n co op op w co co co co co co w co co w co o oo co ✓ N N N N N N N N N N N N N N N N N N N .` M i G o O M 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CJ 0 .) E 0 c. m 0 D 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 d 2 W W W W W W W W W W W W W W W LU LU W ___I • • o o N o co M M co co co N N > o Z IN N N N N N Q M M a 0 � , N 0 ' 'T 0 co U Ua 0n C7a 0a C7a 0a N N N N it `6j r' 7 U coNU� 0 op U COO Urn U O d' d n- J W o JM J0 JO J4 JCO JM _M o 0 0 U M N J O J JN JN JN JM m7 CO 7 m 7 m7 m 7 m7 4 rn m N N N 4 o CO° Y 0 Y M Y N Y- Y O N - PO E E 0 N Z CON (O N Com m•' m 4 C0 8 I— 0E- 00) c c W I— I E ¢ o ¢‘ ¢, ¢ c ¢CV ¢01 W J C$JJ a� U Q �N �M C . e� eco En a ° E o o LL 6: c° N a Oft °fit o O* O* O* 41::1:0 •- - �- a J T.F. It IO It It It ~ m C 0 € € Cn . 0) p 0 o� �� CD 0) a) a.) CL) (1) 11) a) 0)co ' >rO O m co c d < m LE Il 0: Il LE U: J 0 0 0 0 0 0 p 0- LL c 1 rn �' 3 c� i c� 3 ° 3 c2 3 c� 3 U� »» > .20 .93 C�cn o L C L C L C L C L C L C t M w 7 t t t t t C c 0 ,- 0 M W E m ou) o0 o� oCO oU o� v0 X00000 �', o c o �0 E V _ ioopopopopopW $ w0op op op op op N- c. . o m '-- V Lf. JJ t ',WCC Woc Ww Ww WR' Ww N2 U NN NNiA W c W c W N2 O Y coM coW coW a0 co co co co co co C+' ,fD 0. O U o 0 0 0 0 0 0 0 E. 0 EEI(0 N N 5....._1 N N A. N N N N CCI C6 O W CO CO fCfl CO CO (.52.!_l CO CO CO (/O Z a/ a CO 1 lbw W 0 0N J J > . V • 0 Za) < irs co O M N OCO O O CV O J a. .2 II CL 0 ii CO Gr _O O M M co O N co co I 0 coO -ti EI U U o J ! Q o I Menmt I— IaIsH _ • N N• N 11 2 1— W • N C m a. co _M Cl) W O-• w r p N ao I Q A211 °' 1 QH • E . n 0 li 0 o c c co 8z_ in co I m N m CO m m co m -o m CO m y 0 0 0 0 0 0 coo 0 0 0 c o co co co co co co I -J m m m 2 o _m _m _) o) _rn _rn 0) j _rn rn_ 0) rn o 1 0 0 0 0 O 0 J 2 0 0 0 J E ,0 C 01 o Co CO CO CO CO CO CC CO M M M M w W Tr H v v v v v v v v r- N- r- r- c > T- rn rn CD rn rn op rn rn CD co rn rn , W o CO CO co op o co CO 0 0 CO CO N N N N N N N N N N N N I CO to W N 1 D. d c_ c E E g Z .` OMiTr N 1 o Z �j ! 0 a cco a) Q « 0 0 0 0 0 0 0 0 0 0 0 0 p < Io E 0 • d 0 0 0 0 0 0 0 0 0 0 0 0 0 d z a w co w w w w J J w w w J 3 • • O 1 •• T1 •- N O ou C Z >- y >- 1 N N cn 0 a) - cl En o > - as mac m a 1►l o a o z Z t L o a U d ES 112 m 2, o o I o 0 -J J r QQ m Z Z :° C) ZCI) as J ` p LL 1 OO .O. @ 'I. ; CL g o 0 W a 6. m i0 as Z E w m O J a) ua)i V 0 a = p E _° E m O rn N 1 v, ---1a c -). co M o 7 Co O. O 2 U U 1 ii 03 r o I I o a ON o Q Q E o J ' o £ ICC c ° ° co H M N. co E l I O 5 V. G N C7 O C li CO N N o a) E a ° >, o M la m f0 N 2q 1 c COa) .) a) C co V/ Za p C c O QCre \ I— (9 a) c 76 c- a II 11' Q a O o 0 1 Z o N U T IP 1 0 U 0 2 0 co 1 Z r-- e- a) a) N 1:- Q N N IIl OZ N CO C 0 O ~ E O No F N t c C w d a)0. N ` W m d' rn H m V 0 w c a) CI C Z c N 0 y 0 wO 0 J O O C c co c v m n cu E a • Tx o a a) E 0 o ° aa)) O c7) d o 0 d M O a c9 0 0 oe G 0 0 FILULIVLO • STATE OF ALASKA • JAN 19 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AI' la.Well Status: Oil J. Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ • Exploratory ❑ GINJ ❑ WINJ ❑ WAGE WDSPL❑ No.of Completions: _1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp., Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC , Aband.: 12/23/2017 • 217-143/317-533 '' 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 November 8,2017 50-733-20080-02-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2392'FSL, 1376'FEL,Sec 13,T1ON, R12W,SM,AK December 4,2017 Granite Pt St 24-13RD2 d + Top of Productive Interval: 9.Ref Elevations: KB: 115' 17. Field/Pool(s):Granite Point Field 617'FNL, 1794'FWL,Sec 24,T1ON, R12W,SM,AK GL:0 BF:53.9' Middle Kenai Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2501'FNL, 1784'FWL,Sec 24,T1ON, R12W,SM,AK 12,893'MD/10,708'TVD• ADL018761 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 263406 y- 2544538 Zone- 4 13,493'MD/10,712'TVD . N/A TPI: x- 263758 y- 2541025 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 263710 y- 2539142 Zone- 4 373'MD/373'TVD N/A 5. Directional or Inclination Survey: Yes U (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 75' (ft MSL) 8,130'MD/7,872'TVD 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to: mud log,spontaneous potential, gamma ray, caliper, resistivity, porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary ROP DGR ADR CTN ALD ABG MD/ ALD DGR ADR CTN ABG TVD/FORMATION LOG MD ND/LWD COMBO LOG MD ND/ GAS RATIO LOG MD ND/DRILLING DYNAMICS LOG MD ND, 12/21/17 CBL 23. CASING, LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD FT. TOP B M4,j...,.{k-TOP BOTTOM PULLED 7" 26# L-80 5,821' 10,893 , 5,634' 10,108' 8-1/2" 241 sx 5" 15# L-80 10,449' 13,023' 9,828' 10,730' 8-1/2" 392 sx 7" 26# L-80 Surface 5,830' Surface 5,643' Tieback Tieback Assembly ''''' 24.Open to production or injection? Yes 0 No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/ND of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number; Date Perfd): 2-7/8"x 2-3/8" 11,453'MD 11,398'MD/10,359'ND 11,550'-12,810'MD/10,418'-10,696'ND, 1,260',6 SPF, 3-1/8", 12/23/17 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No Q Per 20 AAC 25.283(i)(2)attach electronic and printed information 12-Z3-11- DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LA- 27. PRODUCTION TEST `ate First Production: Method of Operation(Flowing,gas lift,etc.): '29/2017 Gas lift of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: )18 24 Test Period �41..8 527 61 N/A 65,875 thing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): 63 514 24-Hour Rate — 8 527 61 32 Revised 5/2017 CONTINUED ON PAGE 2 RPrlttfi a., i,� IA., r •-•..1,$ubmit ORIGINIAL onI -PVk' �ithOiri r1, 5i-- `1-0C`-I° I Y V tl • • 28.CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No If Yes, list formations and intervals cored(MD/TVD,From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q Permafrost-Top If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base N/A N/A Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval Tyonek C7 11,550' 10,418' information, including reports,per 20 AAC 25.071. Tyonek Cl 9,254' 8,877' Tyonek C5 9,968' 9,467' Tyonek C5 Base 10,141' 9,601' Tyonek C7 10,876' 10,098' Formation at total depth: Tyonek C7 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys,Casing and Cement Report. Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey, core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title:Drilling Manager Contact Email: cdingera@hilcoro.com Authorized �,, Contact Phone: 777.8389 Signature -� Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Granite Point Platform n 411 • Well: Granite Pt St 24-13RD2 Last Completed. 12/28/17 SCHEMATIC PTD:217-143 :lamp Alaska,LLC API: 50-733-20080-02 RKB to Tubing Head 50.35' Casing Detail: [[ SIZE26" WT ConductoGRADE CONN ID TOP BTM. .. 26 s• 18" 70.59 B Ventura Surf 592' 78^ , 1 13-3/8" 61.0 J-55 Butt.LT&C 12.515 Surf 3,960' DV Collar t 4 2198 40& 9-5/8" 43.5 N-80&S-95 Butt.LT&C 8.755 Surf 8,130'(TOW) 7"Tieback 26 L-80 DWC/C 6.184" Surf 5,830' 13-3/8" At s 7" 26 L-80 DWC/C 6.184" 5,821' 10,893' Casing Leak BTC(KC -1,550' 5" 15 L-80 4.408" 10,449' 13,023' convertible) 2 Tubing Detail: 7"Tieback Seals#5,830' 2-7/8" 6.5 L-80 8rnd EUE 2.441" Surf 10,395' i 2-3/8" 4.7 L-80 8rnd EUE 1.995" 10,395' 11,453' J JEWELRY DETAIL No Depth Depth ID OD Item (MD) (TVD) 50.10' 50.10' Tubing Hanger TOC @7,970' €ii 1 373' 373' 2.313" 4.91" SSSV Halliburton NE TRSV 0 2,544' 2,499' 2.441" 4.75" GLM#1 PSPO-1M Mandrels,R-1 Valves w/BK-2 latches 4,530' 4,386' 2.441" 4.75" GLM#2 PSPO-1M Mandrels,R-1 Valves w/BK-2 latches 6,050' 5,855' 2.441" 4.75" GLM#3 PSPO-1M Mandrels,R-1 Valves w/BK-2 latches ti 7,132' 6,915' 2.441" 4.75" GLM#4 PSPO-1M Mandrels,R-1 Valves w/BK-2 latches i 2 id Is 7,900' 7,651' 2.441" 4.75" GLM#5 PSPO-1M Mandrels,R-1 Valves w/BK-2 latches f�' p >� 8,542' 8,180' 2.441" 4.75" GLM#6 PSPO-1M Mandrels,R-1 Valves w/BK-2 latches 9-5/8 i 9,090' 8,742' 2.441" 4.75" GLM#7 PSPO-1M Mandrels,R-1 Valves w/BK-2 latches TOC @s,93o' 9,701' 9,247' 2.441" 4.75" GLM#8 PSPO-1M Mandrels,R-1 Valves w/BK-2 latches 0 10,343' 9,752' 2.441" 4.75" GLM#9 PSPO-1M Mandrels,R-1 Valves w/BK-2 latches 3 10,394' 9,789' 1.983" 3.688" 2-7/8"x 2-3/8"Crossover 41 4 11,349' 10,339' 1.995" 3.625" GLM#10 GLMAX-1HP Mandrels,RO01 orifice w/T-1 latches 5 11,398' 10,359' 1.940" 4.125" Packer-Map Oil Tool MFH Hydraulic Set Retrievable w/30K 11 Shear ti"' 6 11,446' 10,379' 1.875" 3.063" X Nipple �: 7 11,453' 10,381' 2.300" 3.00" WLEG s r;_ 3 E L. PERFORATION DETAIL Squeeze Perfs 10,50040l04 ,„ v`1�?' Top Btm Top Btm 7„ aII Zone (MD) (MD) (TVD) (TVD) FT SPF Date Status Comment TOC @11,065' C-7 11,550' 12,810' 10,418' 10,696' 1,260' 6 12/23/17 Open sI 10,—.4 5 7 i C7 Sand c. 5" , ra PBTD:12,893' TD:13,493' Max Hole Angle"100.32°at 13,493'MD Updated By:CJD:01/16/18 • • Hilcorp Energy Company Composite Report Well Name: GPF GP 24-13RD2 Field: County/State: ,Alaska (LAT/LONG): ?Nation(RKB): API#: Spud Date: Job Name: 1711829P GP 24-13RD2 PreDrill Contractor AFE#: AFE$: 5/19/2017 Load out rig 404 f/Dolly varden Ti G.P Platfrom Arrive Platform.Platform Orientation.Safety meeting and permits.,Prep drill deck.Work M/V.Offload front and rear carrier beams and set in place on drill deck.Install spreader bars between carrier beams.Set racking mat beam in place on drill deck.,Set and mount carrier in place on beams.Install carrier walkways and landings.Mount draw works on carrier.,Offload derrick and release boat to return to Dolly Varden for next load.Mount A-frame and derrick on carrier. 5/20/2017 Continue to load out the second boat F/G.P. Platform. M/U drill line to draw works. Set koomey and choke house in place,M/U koomey hoses to koomey. Set stairs and landings across rig beams. Set racking mat in place,Load scaffolding on flat prepping for backload of scaffolding to beach,Offload M/V Resolution.Spot rig pump and tank in place on drill deck. Mount gas buster on rig tank. Set drillers shack on rear beam. Backload scaffolding flat to boat.,Stand derrick up half-mast. Spool drill line and cat line. Connect brake linkage. Mount control panel on derrick. Lay derrick down.,Installed stairs&landings to carrier walkways. Installed stairs to doghouse. Ran air and hydraulic lines from koomey to remote panel in doghouse. Removed all hoses and lines stored and shipped inside rig tank.,Manifold hoses and lines from rig tank to choke house and rig pump,M/U carrier stabiliz r cables. Clean and oraanize ria connex. 5/21/2017 Continue to flange up on top of tree for E-line work.,Rig up and install K5 hoses to choke manifold,place cutting box on pit side and fill pits up w/FIW 70 BLLS .,Continue rig up mud pump and pits,organize connex and rig up test pump. NOS rep cycles well head lock down screws.,Bleed Down Tubing pres T/0,Rig up and set BPV. N/D Tree 10000K,Wood Group Valves piece at a time.,NOS rep M/U 3 1/2"blank test sub in hanger-prepped flange and hanger for BOP N/U. N/U 13 5/8"5M BOPE w/11"10M adapter on btm.,Torqueing up all flange bolts to specs starting at hanger head and working up the stack.Stand up and scope out derrick.,Continue torqueing up ROPE flange bolts.M/U guide wires.Set driller shack and stairs.Hang floor and wind walls. 5/22/2017 Finish torqueing up all ROPE flange bolts and hanging wind walls. Run koomey lines to ROPE. M/U coflex hose from choke to K3 valve. M/U all choke and kill lines.,Tighten up all derrick and carrier cables. Function test BOP rams and remote panel. Prep for BOPE test.,Hang tongs,set up handling tools,3-1/2"test jt,IBOP,pump-in sub and safety valve on floor. Run power pack lines to tongs. MN Resolution arrives.Work boat offloading ELU and power pack.,M/U safety valve,IBOP and pump-in sub to 3-1/2"test jt w/ported sub on bottom, NOS rep on floor. Fill BOPE w/FIW.,Test all BOPE 250 psi low 3500 psi high as directed in Sundry(annular tested 250 psi low 2500 psi high),in accordance with Hilcorp and AOGCC requirements. Performed successful koomey drawdown test. Witnessed waived by Mr Regg/AOGCC 9:57 AM 5/22/217.,Rig down test equipment. Prep for ELU rig up 5/23/2017 R/U Pollard ELine w/full lubricator-M/U 2.5"Jet tb cutter WI ccl&wt bar-pulled inside lub and M/U to string(setting on hanger). RIH to'X'nipple at 9,341' and tied in-continued in hole and set down at 9,358'(know tight spot in tb)-P/U to 9,356'and fired cutter(1st jt above pkr at 9,380'). POOH and rigged to side w/ELine.,Displaced well with clean FIW at 2 bpm 400 psi sending returns to production disposal well tank(rate dictated by lead op).,Reduce well clean displacement rate to 1.60 bpm,250 psi(rate dictated by lead op).,Stop pump and displacement,clean returns to surface,well static. 700 bbl FIW total(19617 stks) NOS rep backs out hanger lock down screws.,Latch onto string and P/U,hanger off seat at 65K,string travelling free at 87K. Pull hanger to floor,break out and lay down same with NOS rep on floor. Complete ELU R/D,clean and organize floor and drill deck prepping to POOH with string.,POOH with 3-1/2"8RD L-80 tubing standing back in derrick and strapping stands. Pump 4 bbl FIW every 20 stands. 60 stands in derrick(3756'),Continue POOH with 3-1/2"8RD L-80 tubing standing back in derrick and strapping stands. Pump 4 bbl FIW every 20 stands.,Cut joint to surface. 148 stands plus 1-single,x-nip w/pups&1-cut joint=9301.17'+38'=9,339.17'(standing strap). Rig motor began running rough-changed fuel filters but motor failed to run-called for Moncla mechanic to repair fuel pump issue.,Moved(KOT)8-1/2"bit and scraper w/XOs to rig floor-BHA#1 (8 1/2"x 2"Varel rock bit,5 1/4"x 1 1/2"casing scraper,5 1/2"x 2"bit sub,4 1/2"x 2 1/4"XO sub=9.47'). Pumped 30 bbls of FIW for tb displacement. • • 5124/2017 Worked thru fuel pump issue and cranked rig motor-problem found with an fuel sensor.,M/U BHA#1 (8 1/2"x 2"Varel rock bit,5 1/4"x 1 1/2"casing s•raper, 5 1/2"x 2"bit sub,4 1/2"x 2 1/4"XO sub=9.47').,TIH WI bha on recovered 3 1/2"9.2#L-80 EUE production tubing to 9,059'(PM)(144 stands+1-si ,.le+ 11.5')-lightly tagged TOL and P/U to 9,050'-B/O single and M/U SV w/pumpin.,Lined up to reverse out sending returns across shaker. Circ hole volu e+ around at 3.3 bpm 350 psi(700 bbls)-1215 hrs worked MN onloading Halb cementing equip,cutting boxes for cleanup,8rd pups and Expro caliper tool-. Shutdown pump and prepped to POOH.,POOH w/bit&scraper pumping displacement every 20 stands.,Bit and scraper out of hole. Cleared and cleaned rig floor. M/U mule shoed 3-1/2"SMAX pup with 3-1/2"SMAX Pin X 3-1/2"8 RD Box crossover.,Run mule shoe in hole with 3-1/2"8RD L-80 tubing 67 stands in hole(4197.08'),Continue RIH with 3-1/2"8RD L-80 tubing,3-1/2"8RD tubing on depth=9347.79'(148 stands, 1 single,2(10')pups, 1 sin.le. Safety meeting with HES,Moncla, Peak and Production Operators in attendance.,R/U HES cement unit to rig floor. Pumped 3 bbls FIW to prime lines- pressure tested to 500 psi low 3500 psi high-batched cement,checked density on mud scale to be 15.8 ppg-pumped 2 bbls FIW at 2 bpm 50 psi.,Pu p 24.6 bbl 15.8 ppg neat cement-displace to tubing with 76 bbl FIW for balance at 8853'(calculated—495'of cement plug).,Broke off Halliburton iron and pre.ped to pull above cement. 5/25/2017 PUH laying down 4-singles and 2-pups plus standing back 11 stands to 8,496'.,Lined up and reversed out 2 tb volumes at 2.75 bpm 230 psi-no ceme tin returns. B/O hose.,POOH laying down 234 of 298 jts of 3 1/2"9.2#L-80 EUE 8rd tb-racked back 32 stands in derrick for kill string. 1330 hrs worked N Resolution onloading pipe rackets and Moncla winch-released boat due to crane issues. 2030 hrs MN Resolution returned-backloaded HES cementin. kit and loaded pipe rack-offloading empty pipe rack and 2 dumpsters.,Cleared and cleaned rig floor.Loaded hole with FIW and prepped for casing pressure test.,Pressure tested 9-5/8"casing to 2500 psi f/30 minutes on chart-Good Test. Rigging up ELU.,ELU running in with GR/CCL,junk basket and 8.37"gauge ring. Tagged TOC at 8781'corrected depth. 0:30 hrs working MN Titan offloading 7"and 9-5/8"RTTS packers,7"and 9-5/8"circ.valves and Moncla cable spool. Load 114 joints of 3-1/2"9.2#L-80 EUE tubing in pipe rack.,ELU breaks off GR/CCL,junk basket and gauge ring. —1/2 pint of tacky cement recovered n junk basket ELU M/U CBL tool suite and TIH to 8,770'. Recording CBL at report time. Near miss incident reported on SO1-broke NE corner marker light on platform while moving bundle of tb w/crane. 5/26/2017 Recorded Pollard CBL from 8,770'to 6,550'(log recorder w/0 psi on well)(correlated to Schlumberger DIL log dated 2-27-68)-top of good cement calle• at 7,900'. POOH&B/O CBL.,M/U Expro 2 3/4"multi-finger imaging tool(casing caliper)on Pollard ELine-checked out tool string on surface. TIH to 8,76°'and recorded log to surface-POOH and B/O tool string-R/D ELine.,M/U 8'(jet cut)piece of 3 1/2"9.2 L-80 EUE 8rd tb on btm of 1st stand-TIH w/32 stand (64 jts)of same recovered production string=2,011'.,NOS rep M/U hanger and landed string in tb head(EOT at 2,049)(SOW 18k PUW 19k)-installed BPV.,Began prepping to N/D BOPE.,Continue clearing floor removing tongs,windwalls,stairs and rig floor. Breaking bolts on BOPE stack. Bleed down koomey,break down all koomey lines..,Remove guide lines,half mast derrick and lay down derrick.,N/D BOPE R/D choke house,N/U Dry Hole Tree. Break off carrier stabilizer cables. Move stairs and walkway from across double and racking mat beam. Pulled BPV and installed 2-way check. NOS rep pressure tests pack-off void 500 psi(5 mins),5000 psi(15 mins)-Good Test NOS rep pressure tests Dry Hole Tree 500 psi(5 mins),5000 psi(15 mins)-Good Test. Pulled 2-way check.,Move racking mat beam to expose GP 22 13RD well hatch. Mark out skid beams for rig skid.,Crane operator shutdown operation to check crane systems-brought mechanic up to check functions. 0600 hrs resum=d moving equip in preparation to skid rig. This will be the last report for predrill phase, 11/4/2017 Prep rig for skid.Pull dn sperry standpipe,pull section out of flowline,Turn flowline drop from shakers back toward power module.[Had Pollard recover.ar and plug from X-nipple on 11-24RD].,Continue prepping for rig skid.Taking extra time to prep and hook up lines that are going to be out over the water.Cut d•wn cutting dump shoot and re-install.Remove upper earthquake clamps.,Have PJSM and skid top section of sub away from power module 4'2 5/8".Re-inst=II earthquake clamps.,Get 50'X 50'herculite bolted onto 40'hanger.Begin patch work in pits.Remove earthquake clamps&PJSM on skidding sub.Start oving sub over well.,Finish spotting sub over well and start rigging up.Move drilling line spool&set cat walk.Install landings&handrails. Install hurricane clamps. Bolt together riser. 11/5/201 Pull rotary.Tie up and secure hoses at deck level under sub.Install BPV.,Nipple dn tree and remove from wellhead room.Clean up hanger,and check al the lock dn screws.Install blanking sub. Nipple up riser.,PU BOP stack and nipple up BOPs on riser.MU choke and kill lines.Tighten bolts on bottom of sng gate. Prep flow box and drip pan for installation.Change out air boots for flow nipple.Install flow box and get measurement for the flow nipple.Spot jet heater o C 4' camp side of sub.Work on adjusting equalizer cables in the mud pits.,Tighten bolts on BOPE.Install drip pan&rotary table. Install flow line.Hook up h.Ie fill line.Hook up turn buckles. Inspect Pit#1 w/TEAM inspector.,Cont.to tighten BOPE bolts.Work on housekeeping, PM's&tool pushers check list.,M/U te-t jt& RIH&attempt to M/U over planking sub.POOH&inspect&dress threads. Not able to make up with several more attempts. Break out overshot&clean dress in welding shop.,M/U test it(good).Fill stack w/H2O&R/U to test BOPE. 11/6/2017 Press up on BOP w/upper pipe rams closed on 4 1/2 DP to perform a shell test to 3500 psi.Everything held good.Swap over to annular an do a pre-test to 250 and 2500 psi.Looked good.Got a call from state inspector Guy Cook at 8:20 and he waived the witness of the test due to choppers on weather hold for h gh winds.,Test BOPS.Test annular on 4 1/2 to 250 and 2500 psi for 5 min ea.Test all other BOP equip on 4 1/2 to 250 and 3500 psi for 5 min ea.Also test.d annular and upper rams on 3 1/2".,RD test equp.Pull blanking sub,and pull BPV.,MU landing jt and screw into hanger.BOLDS, Pull hanger to floor w/ .4k wt.,RU Weatherford,LD hanger and prep to LD 3 1/2 8rd tbg.,POH laying down 3 1/2 tbg.LD 64 jts and a cut off jt. RD Weatherford.,RU pollard a-line. -IH to set BP @ 8148'. No indication of BP set.Make several attempts with no success.POOH.Break down tools&inspect tools. M/U tools&getting good signal.,RIH&set BP @ 8148'.POOH&RID E-Iine.,M/U cleanout BHA#1 (mills&18 jts HWDP)to 569'.,RIH while picking up 4-1/2"DP to 3500'. 11/7/2017 RIH w/whipstock mill assem PU 4 1/2 DP f/3500'ti 5538'.Continue RIH with pipe out of the derrick to BP at 8148'.Set dn 5k.PU to 8145 and prep to circ.,Circ hole clean at 412 GPM,824 psi.,RU and test csg to 1500 psi for 30 min on a chart.,POOH w/clean out mill assembly f/8145'to 3821'.,Service rig.,Cont.POOH w/clean out mill assembly f/3821'to Surface.,C/O saver sub&grabber dies on top drive.Prep MWD tools for whipstock/milling BHA., U whipstock/milling BHA to 589'.Shallow hole test MWD tools.,RIH whipstock/milling BHA f/589'to 5315'. 11/c/2017J RIH with whipstock/milling assembly from 5315' to 8039'.,Establish circulation.Orient and set whip stock at 53R.35K down.TOW will be 8130'.,Drain •its of 5fri. V\.y�y FIW.Clean pits as necessary and take on OBM.Secure spill containment curtain on east side of rig under shaker pits.,Hold PJSM. Displace well with 9.0 ppg V:✓,j" OBM taking FIW returns to production well-clean tank.OBM to surface at 555 bbls pumped.Shut down.Open annular. Circulate and condition mud.Sh t �" � down pumps.,Remove pulsars from shakers and prepare for transport. Obtain SPR's.,Mill window as per Baker rep TOW—8130'/BOW 8147',400 GP 1700 PSI,90-110 RPM,7 K TRQ.,Drill new formation f/8147 to 8160',400 GPM 1700 PSI, 110 RPM,7 K TRQ. tfr 11/9/2017 Drill new formation f/8160'to 8167',400 GPM 1700 PSI,110 RPM,7 K TRQ. Pumped sweep with no increase in cuttings.,Circulate and condition mud o 8.9 ppg in/out.Pull into window.,Perform FIT to 12.5 ppg EMW.,Drill new formation f/8167'to 8175',415 GPM 1800 PSI, 110 RPM,7 K TRQ.,Pump dry jo.. POOH with milling assembly BHA#2.Starter mills 1/8"under gauge.Upper mills in gauge,M/U stack washer&flush stack.Blow out choke lines. Flush ill line.R/U Geo-Span hard lines&pressure test to 3500 psi.,M/U 8-1/2"Geo-Pilot BAH as per DD • 11 Hilcorp Energy Company Composite Report Well Name: GPF GP 24-13RD2 Field: County/State: ,Alaska (LAT/LONG): evation(RKB): 52.65 API#: Spud Date: 11/10/2017 Job Name: 1711829D GP 24-13RD2 Drilling Contractor Kuukpik 5 AFE#: AFE$: .... u..:........ :.....:::::::... 11/9/2017 M/U 8-1/2"Geo-Pilot BHA to 432'(shallow pulse test tools&load sources.;RIH f/432'to 4842;Ann Pressure:20"=7 psi/13-3/8"=230 psi Dowhhole Losses:0 bbls/Cum:0 bbls Code 8:O Hrs/Cum:O Hrs Metal Recovered:0 lbs I Cum:365 lbs 11/10/2017 RIH with BHA#2 from 4842'to 8059'filling pipe every 2500'.;Cut and slip 130'of drill line while circulating and conditioning mud at window.70 GPM/180 psi. Service rig and adjust service loops.;Wash down through window from 8059'to 8165.Did not see window.Wash and ream 8165 to 8177'.;Directional drill f/8177'to 8310'. P/U 121,S/0 104,ROT 40 RPM at 109 wt./8.5 K torque. 410 GPM/2380 psi. 8-12 k WOB.;Directional drill(/8310'to 8501' P/U 118,S/O 98, ROT 105,120 RPM 8.5 K trq 410 GPM/2350 psi. 8-12 k WOB.;Directional drill f/8501'to 8743' P/U 118,S/O 98,ROT 106,120 RPM 8.5 K trq 420 GPM/2500 psi. 10 k WOB.;Distance to Plan:42.87'(8.96'High/41.92'Right).;Ann Pressure:20"=4 psi/13-3/8"=200 psi Dowhhole Losses:0 bbls/Cum:0 bbls Code 8:0 Hrs/Cum:0 Hrs Metal Recovered:34 lbs/Cum:399 lbs 11/11/2017 Directional drill(/8743'to 8998' P/U 118,S/O 98,ROT 106,120 RPM 8.5 K trq 420 GPM/2500 psi. 10 K WOB.Pumped sweep at 8880' with 10%returns and back on time.;Directional drill(/8998'to 9490' P/U 160,S/0128,ROT 130,120 RPM 5-9 K trq 448 GPM/2680 psi. 10-12 K WOB.;Circ B/U with 448 GPM, 2650 PSI,Pumped sweep at 9431' with 10%increase in returns and back on time.;Short trip f/9490'to 8872'.(30 K tight spot©9372'work thru once on elevators&clean.Tight spot @ 9086'not able to work thru on elevators.W&R f19086'to 9064',work thru&clean).;Tight spots correlated with coals.RIH(/8872' to 9490'with no issues.;Service top drive,draw works&crown.;Directional drill(/9490'to 9559', P/U 160,5/0 128,ROT 130,120 RPM 5-9 K trq 448 GPM/2680 psi. 10-12 K WOB.;HPU#2 over heated.Circ.©reduced flow rate&repair exhaust leak on HPU#2.;Resumed drilling ahead from 9559'@ 6:00 Hrs.;Distance to Plan:11.06'(3.44'High/10.51'Right).;Ann Pressure:20"=20 psi/13-3/8"=440 psi Dowhhole Losses:0 bbls/Cum:0 bbls Code 8:1 Hrs/Cum:1 Hrs Metal Recovered:47 lbs/Cum:446 lbs 11/12/2017 Directional drill f/9490'to 9630' P/U 160,SIO 128,ROT 130,120 RPM 5-11 K trq 450 GPM/2680 psi. 5-12 K WOB.;Directional drill f/9630'to 9887' P/U 165,S/O 130,ROT 142,120-160 RPM 5-11 K trq 460 GPM/2700 psi. 10-12 K WOB.Pump sweep at 9640'with 20%increase on time.;Not able to maintain adequate ROP&stick slip is severe.Decision made to POOH for BHA. Distance to Plan:7.42'(6.29'High/3.94'Left).;Rack back partial stand to 9866'.Pump sweep&circ hole clean,420 GPM,2300 PSI,150 RPM,7 K Trq.Saw 25%increase in cuttings with sweep&on time.;F/C(static)POOH(/9866'to 8065'(couple tight spots that correlate to coals,worked thru once&clear).BHA came thru window with no issue.;Circ&cond mud inside casing while clean floor&service rig.425 GPM,2150 PSI.;Ann Pressure:20"=9 psi/13-3/8"=410 psi Dowhhole Losses:0 bbls/Cum:0 bbls Code 8:0 Hrs/Cum:1 Hrs Metal Recovered:12 lbs/Cum:458 lbs 11/13/2017 Finish circulating&conditioning mud inside casing while cleaning floor&service rig.425 GPM,2150 PSI.;POOH with BHA#2 to 490'. Laid down 1 bad joint on top of stand#53 with damaged box end.;Download MWD and work BHA.Bit graded 1-2 and 1/16"under gauge.Photos in O-drive.;Make up BHA#3 Geo-Pilot& wait on bit sleeve to arrive from beach.;Cont.to M/U BHA#3.to 155'.Load sources&plug into MRIL tool.Shallow test tools.;RIH to 1500'.Fill pipe&break in Geo- Pilot.M/U agitator.;Cont.to RIH to 8074'filling pipe every 2500'.;Circ&cond mud&service rig prior to going into open hole.;Cont.to RIH from 8074'to 9622'.(No issues running thru window)W&R thru tight spot @ 9364').;W&R with full drilling parameters f/9622'to 9800'while trouble shoot MWD.Pulsar not working&not getting telemetry.Cycling pumps&sending downlinks with no success.;Ann Pressure:20"=6.5 psi/13-3/8"=190 psi Dowhhole Losses:0 bbls/Cum:0 bbls Code 8:0 Hrs/Cum:1 Hrs Metal Recovered:0 lbs/Cum:458 lbs • • 11/14/2017 Wash and ream to TD at 9887'.Circulate sweep with 5%excess on time.;POOH on elevators from 9887'to inside window at 8125'. Tight spots at 8800'and 8620'but able to work through with 40K.;Pump dry job and clean rig floor.;POOH from 8125'to top of BHA,laying down agitator.Rack back HWDP,jars and DC's.Broke of float sub and inspected top of pulser in TM collar(clean and OK).;MU float sub on TM collar,MU shock sub and XO.TIH with DC's,HWDP and jars.Shallow pulse test was good.Cont TIH and pulse checked at 3000'and 5761'after filling pipe.At 8118'filled pipe.;At 8118'(just above window)hung off blocks,cut and slipped 113'of drill line.Calibrated hookload and block height.;Cont TIH from 8118'but set down at top of window(8130')numerous times.MU topdrive and turned string in 1/2 round increments and cont to set down.Increase set down weight to 30K and broke through.;Did not see any more loss in string weight with stabilizers or other BHA components going through window.Cont trip in open hole from 8130'to 8575'and set down twice(sandstone).;Third ti e was clean on elevators.Set down at 8707'and after working numerous times on elevators,MU topdrive and washed/reamed down to 8739'at 200 gpm-30'pm with no issue(40'coal).;Set down at 9010'and worked one time on elevators.Cont TIH to 9790'on elevators with no problem.MU topdrive at 9790'and washed/reamed to bottom.At 9880'located fill.Worked slowly to bottom at;400 gpm-2545 psi,120 rpm-7100 ft/lbs off bottom torque.Seeing some slight packoff. Getting good detection on MWD tools and no issue with stick/slip.;Ann Pressure:20"=5 psi/13-3/8"=210 psi Dowhhole Losses:0 bbls I Cum:0 bbls Code 8:0 Hrs/Cum:1 Hrs Metal Recovered:0 lbs/Cum:458 lbs 11/15/2017 Cont to wash/ream slowly to bottom from 9883'to 9887'at 402 gpm-2557 psi,120 rpm-6500 ft/lbs off bottom torque.Seeing some slight packoff and quarter size coal chips at shakers.BGG 16 units.;Directional drill 9887'to 9979'.425 GPM/2700 psi.130 RPM 6-12K ft/lbs.8-20K WOB.;Directional drill 9979'to 10,293'. 430 GPM/2800 psi.130 RPM 6-12K ft/lbs.8-20K WOB,MW 9.4/vis 91,ECD's at 9.8 ppg,BGG 46 units.;Directional drill from 10,293'to 10,410',7 to 17K wob, 435 gpm-2874 psi,140 rpm-7,000 to 13,800 ft/lbs on bott torque,5 to 40 ft/hr ROP,MW 9.4/vis 85,ECD's at 9.7 ppg,BGG 48 units.;Pumped a 20 bbl hi-vis hi- wt sweep at 10,386'.Came back 15 bbls late and had 5-10%increase in cuttings. Distance to Plan=9.64',9.64'high,0.1'right of the line. We have drilled through the C-6A;Ann Pressure:20"=6 psi/13-3/8"=310 psi Dowhhole Losses:0 bbls/Cum:0 bbls Code 8:0 Hrs I Cum:1 Hrs Mpbal Rprnvprprl•R Ihs/Cum•driRi Ihs 11/16/2017 Cont directional drilling 8 1/2"production hole from 10,410'to 10,504',10-20 wob,435 gpm-2851 psi,120rpm-6-12 ft/lbs on bott torque,16 ft/hr ROP,MW 9.4/vis 80,ECD's at 9.6 ppg.;Cont directional drilling 8 1/2"production hole from 10,504'to 10,590',10-20 wob,435 gpm-2851 psi,120rpm-6-12 ft/lbs on bott torque,16 ft/hr ROP,MW 9.4/vis 80,ECD's at 9.6 ppg.;Cont drilling from 10,590'to 10,692',20K wob,408 gpm-2606 psi,100 rpm-6000 to 13,000 ft/lbs on bott torque,11 to 80 ft/hr ROP,MW 9.5/vis 79,ECD's at 9.8 ppg,BGG 30 units.;Had some trouble building inc between 10,490'and 10,511'.Reduced RPM from 120 to 100 and gpm from 440 to 420.Saw 0.24 deg/100'build rate. Increased wob to 25K and saw 4 to 6 deg/100'build rate.;Cont drilling from 10,692'to 10,765',21k wob, 412 gpm-2710 psi,100 rpm-6700 to 11,800 ft/lbs on bott torque,14 to 29 ft/hr ROP,MW 9.5/vis 86,ECD's at 9.7 ppg,BGG 43 units.;Current distance to plan is 14.41',5.11'high,13.47'right of the line. At 06:00 hrs we have an Azimuth of 178.46 deg and Inclination of 52.25 deg. Drilling through the Coal_16(many small coals).;Ann Pressure:20"=10 psi/13-3/8"=560 psi Dowhhole Losses:0 bbls—/Cum:0 bbls Code 8:0 Hrs/Cum:1 Hrs Mabal Rprnvprpri•7 Ihs/Cum•474 Ihs 11/17/2017 Cont directional drilling 81/2"hole from 10,765'to 10,889',18K wob,439 gpm-3000 psi,120 rpm-10,000 ft/lbs on bott torque.;Cont directional drilling 8 1/2"hole from 10,889'to 10,970',18K wob,439 gpm-3000 psi,120 rpm-10,000 ft/lbs on bott torque.;Cont directional drilling 8 1/2"hole from 10,970'to 11,032',18K wob, 439 gpm-3000 psi,120 rpm-10,000 ft/lbs on bott torque,26 ft/hr ROP,MW 9.5Nis 78,ECD's 9.8 ppg,BBG 43 units.;Logged the C-7A top at 10,875'md/10,097' tvd,and the C-7B at 10,966'md/10,150'tvd,at which point the torque reduced significantly,and ROP reduced as well.Dip appears to be running at 21 degrees.;Obtained survey then pumped a 20 bbl hi-vis hi-weight sweep around at 400 gpm-2600 psi,80 rpm-7800 ft/lbs off bott torque.Had 5 to 10%increase in cuttings to surface.Did one more bottoms up.;Pulled wiper trip from 11,032'to 9846'on elevators with no issue at all.Up wt 170K.;Serviced rig and topdrive.Crew found a broken parking brake bracket on drawworks drum during rig service.Finished rig service and decided to pull to shoe to repair drill side parking brake bracket.;Cont pulling up hole on elevators from 9846'to 8114',up wt 154K.Had one 15K overpull at 8758'.Most likely the lower stabilizer pulling into the bottom of a coal at 8725'.No issue pulling BHA.;into and through the window at 8147'.MU topdrive at 8114'and circulating at 258 gpm-1058 psi while prepping to remove brake bracket for welding.Drill string sitting in slips.;Calculated hole fill=18 bbls,Actual hole fill=22.5 bbls. Distance to plan 26.5',0.7'high,26.5'right of the line.;Remove drill side e-brake assembly,stage assembly in welding shop for repair.Clean rig floor.Install sight glass fittings in rig floor hydraulic winches.Service HPU#2.;Ann Pressure:20"=10 psi/13-3/8"=550 psi Dowhhole Losses:0 bbls/Cum:0 bbls Code 8:2.5 Hrs/Cum:3.5 Hrs Metal Recovered:7 lbs/Cum:480 lbs 11/18/2017 Cont repairing(welding)drawworks e-brake bracket.Circulate at 258 GPM/1065 psi.;Finish repairing and installing DW brake bracket.Circulate at 258 GPM/1065 psi.;RIH on elevators from 8114'to 10,645',the first of 4 large coals.Tried working through on elevators,MU topdrive,washed and reamed down to 10,750',200 gpm-30 rpm.At 10,750'(3rd large coal)we;packed off.Worked with various pump pressure and rates,rpm's and jars and managed to regain circulation.Worked pipe numerous times through the coals and cleaned up.Cont to wash and ream from;10,750'to bottom at 11,032',at which point we increased pump rate to 425 gpm-2975 psi,80 rpm-8400 ft/lbs off bottom torque.(Exiting the window at 8,147'we saw nothing,good and clean).;Circulated one bottoms up and hole unloaded pea sized coal.Pumped a 20 bbl hi-vis hi-wt sweep around at 443 gpm-3285 psi,120 rpm-8400 ft/lbs off bott torque.Hole continued to unload various sized;coal until sweep returned to surface.Actual sweep had 10%increase in cuttings at shakers,10 bbls late.Once sweep reached surface shakers cleaned right up.Max gas of 923 units at first bottoms up.;Resumed directional drilling 8 1/2"hole in the C-7 from 11,032'to 11,096',wob 20K, 400 gpm-2662 psi,120 rpm-8200 to 13,000 ft/lbs on bott torque,0 to 40 ft/hr ROP,MW 9.5/vis 84,BGG 41 units.;Drilling off the WP-16 look ahead directional plan.After making connection at 11,096'we lost a swab on#1 pump.;Replace swab on#1 pump while working pipe.258 gpm-1221 psi,60 rpm-6800 ft/lbs off bott torque.Last survey at 11,096'has us 4.44'low and 25.97'right of the new line.;Ann Pressure:20"=7 psi/13-3/8"=190 psi Dowhhole Losses:22 bbls/Cum:22 bbls Code 8:10.5 Hrs/Cum:14 Hrs Metal Recovered:1 lbs/Cum:481 lbs • • 11/19/2017 Cont directional drilling 81/2"hole from 11,096'to 11,168'. 450 gpm-3150 psi,120 rpm-8400 Nibs off bottom torque.MW 9.5Nis90.Still seeing some oil shows. ROP very low.;At 11,168'we are 4.5 low and 25.07'right of the line.;Circulate bottoms up.Stand back one stand.Circulate sweep bringing back 50%excess 20 bbls late while working pipe.;POOH on elevators from 11,043'to 8109'(inside casing).Pulled 35K over at 10,810',20K over at 9120'and 9076'(coals).Worked a couple times each on elevators and cleaned up.No issue at window.;Monitor well,no flow,while mixing dry job,securing lube pump jumper wire on service loop and cleaning rig floor.MU topdrive and pumped dry job.;Cont POOH from 8109'to BHA at 483'.We stopped at 6444',PU MWD tool from pipe deck and broke connection for next BHA.Racked back HWDP,jars and NMDC.,LD shock sub and float sub.;Remove pulser from TM collar and LD TM.Plugged in and downloaded MRIL collar.LD MRIL collar,removed RA sources and LD CTN collar.Plugged in and downloaded MWD.LD ALD,PWD,DGR,DM and ADR collars.;Ann Pressure:20"=8 psi/13-3/8"=550 psi Downhole Losses:7.5 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:14 Hrs Mptal Rprnvprprl• the/Cum 4R4 the 11/20/2017 LD geopilot and Kymera bit.Bit graded a 2-5,in gauge and had 440 K-Revs.;Clear and clean rig floor.Stage BHA#4 items for PU. Finish servicing#1 mud pump.;Pick up BHA#4.Shallow hole test tools.;RIH with BHA#4 to 8086'.Fill pipe every 2500'.;Slip and cut 97'of drill line and condition mud at 200 GPM/720 psi.Calibrated block height and crown saver.Set upper and lower set points.;Pump one full circ to ensure no air in wellbore and troubleshooting MWD tool that wouldn't turn off.Flow check=static.;Drain stack and riser,MU test joint assembly and test plug on drill string.SO and land test plug.Flood surface equipment with water and purge air.Attempt to shell test stack but bleeding off.;Chase for potential leaks.Found manual demco kill valve leaking by.Isolated and rebuilt kill valve.Cont with shell test with no further issue.;Test BOPE at 250/3500,250/2500 on annular for 5 min each.Performed koomey draw down test.;Break down TIW/IBOP's,RU hose to drain stack to Production.Unseat test plug and drain stack/riser.Pull test plug to floor breaking down test jnt assembly and LD test plug. Blow down choke manifold.;MU topdrive and break circ above window to turn on MWD tool,break in seals and bearings and test GeoPilot.;Exit window at 8147' with no issues,cont trip in open hole to 8202'.;Ann Pressure:20"=3 psi/13-3/8"=180 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:14 Hrs Metal Recovered:0 lbs/Cum:484 lbs 11/21/2017 At 8202'we set down twice 15K.MU topdrive and washed down pumping 1/2 bpm,no rotation,with no issue.At 8583'set down 20K.Worked 3 times on elevators and cleaned up(coal).At 8610'we set down;20K.Worked two times on elevators and cleaned up(coal).At 8700'set down 20K.Worked 3 times and had to MU topdrive.Washed/reamed down to 8759'at 100 gpm-30 rpm(coal).At 9315'we set down 20K.;Worked twice on elevators and cleaned up (sandstone/claystone).Filled pipe at 9760'.RIH to 10,625'and washed and reamed to 11,015'.Kept packing off and getting a lot of coal over the shakers.;Wash and ream f/11,015'to 11,163'350 GPM,2030 Psi,60 to 80 RPM.8.5k TQ.Still having to take small bites then PU,due to packing off. Still getting a lot of coal but smaller chunks.;Pump 20 bbl 11.1 ppg,500 vis sweep. Wash and ream f/11,163'U 11,168'while sweep getting out of bit.;Directional drill 8 1/2"hole f/ 11,168'U 11,180'.400 GPM, 2570 psi,140 RPM,9 to 10k TQ.Sweep came back 25 bbls late w/a 5%increase in cuttings.;Made a connection and brought the pumps back up to drilling rate.Liner cage bolt broke on#1 pump.PU and dr w/#2 pump while repairing#1.;Resumed drilling 8 1/2"hole from 11,180'to 11,240', 7 to 12K wob,422 gpm-2700 psi,140 rpm-11,000 ft/lbs on bott torque,20 to 60 ft/hr ROP,MW 9.5/vis 104,ECD's at 9.9 ppg,BGG 26 units.;At 11,240'obtained SPR's and made connection.Upon starting rig pumps MWD unable to decode pulses due to high pump noise,pump#1 discharge hammering bad.Cont to work pipe on#2 pump,;tore down pump#1, CO seats,checked pulsation dampeners(both reading 3000 psi).Bled off both dampeners,re-charged both to 600 psi and pumps smoothed out,MWD detection back to normal.;Resumed drilling 8 1/2"hole from 11,240'to 11,380',7 to 12K wob,425 gpm-2700 psi,140 rpm-8000 to 11,000 ft/lbs on bott torque,6 to 50 ft/hr ROP,MW 9.5/vis 103,ECD's at 9.8 ppg,BGG 25 units.;Currently+/-45 vertical feet above the C7-C target zone base. Formation dip appears to be running at 22 degrees.Last survey has us 6.78'low and 24.64'right of the line.;Ann Pressure:20"=11 psi/13-3/8"=210 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:O Hrs/Cum:14 Hrs Metal Recovered:2 lbs/Cum:486 lbs 11/22/2017 Cont directional drilling 8 1/2"hole from 11,380'to 11,401',9K wob,425 gpm-2627 psi,140 rpm-8000 to 13,000 ft/lbs on bott torque,20 to 30 ft/hr ROP,MW 9.5/vis 90,ECD's at 9.8 ppg,BGG 42.;Suction valve cap on#1 mud pump started leaking.Work the pipe and circ w!#2 pump while changing out washed out center mud end on#1 pump.Got old mud end pulled off and new mud end dressed.;lnstalled new mud end and attempt to get the suction manifold put back on. Flange size and bolt pattern are different on the new mud end so it wouldn't bolt up to the suction manifold.;Pull new mud end off pump.Waiting on new mud end that is headed out on the boat.Unload mud end off Boat and set in pump room.Prep mud end for installation.Set cement pods for offload into silo.;lnstalled new mud end pod on#1 mud pump.MU suction and discharge manifolds.Installed swab and buttoned up pump.Test ran OK.Received 700 sx liner blend cement and released SLB crew for boat ride.;Drilled 8 1/2"hole from 11,401'to 11,426',9K wob,422 gpm-2700 psi,140 rpm-8400 to 13,600 ft/lbs on bott torque,6 to 40 ft/hr ROP,MW 9.5/vis 89,ECD's at 9.8 ppg,BBG 19 units.;At 11,426'shut down#1 pump and checked torque on all bolts.All good.Serviced drawworks.;Drilled 8 1/2"hole from 11,426'to 11,466'.6 to 9K wob,422 gpm-2671 psi,140 rpm-10,200 to 11,200 ft/lbs on bolt torque,20 to 50 ft/hr ROP,MW 9.5/vis 87,ECD's at 9.8 ppg,BGG 92 units.;Drilled 8 1/2"hole from 11,466'to 11,521'.6 to 9K wob,422 gpm-2671 psi,140 rpm-10,200 to 11,200 ft/lbs on bott torque,20 to 50 ft/hr ROP,MW 9.5/vis 87,ECD's at 9.8 ppg,BGG 92 units.;At 11,521'auto driller stopped working.Attempted to PU off bottom but e-brakes not releasing.Then hydraulic pump#1 shut down.Re-set breaker for aux pump and able to get pump#1 running.;Had to release e-brake manually and able to PU off bottom. Mechanic and Electrician troubleshooting the drawworks pressure transmitter failure.When they went to open top panel on Drillers;console we lost all 24 volt PLC power at console and both rig pumps shut down.Started pump#2 in manual mode,circulating at 234 gpm-938 psi,80 rpm-8270 ft/lbs off bottom torque,with bit at;11,490',Mechanic and Electrician troubleshoot 24 volt power loss to console.Found bad ground in doghouse PLC cabinet and re-gained PLC power.Cont troubleshooting drawworks pressure transmitter;failure.Checked all bolts on#1 pump for torque.Were able to tighten 3 bolts.;While drilling we were experiencing a fair amount of stick/slip.Reduced weight on bit to 6K and saw improvement,while still maintaining good ROP. Currently 1.46'high and 26.92'right of the line.;Ann Pressure:20"=13 psi/13-3/8"=360 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:20 Hrs/Cum:34 Hrs Metal Recovered:3 lbs/Cum:489 lbs 11/23/2017 Cont troubleshooting drawworks pressure transmitter failure with bit parked at 11,490'.Circ at 423 gpm-2700 psi,80 rpm-8000 ft/lbs off bott torque.BGG 36 units.;Shut down#1 pump and run#2 at 240 GPM,980 Psi,60 RPM.Were able to manual bypass brake and slack off to 11,492'.Replaced a card and problem was resolved.Work pipe and set high set on blocks.;Directional drill 8 1/2"hole f/11521'U 11,630'.425 GPM,2652 Psi,160 RPM,9 to 16k TQ,8 to 15k WOB, max gas 146 units.Changing parameters to keep stick slip down.;At 11,600'started our planned build to 75.5 deg Inclination and turn to 172 deg Azimuth.;Directional drill 8 1/2"hole f/11,630'U 11,718'.12K wob,425 gpm-2642 psi,160 rpm-8000 to 14,000 ft/lbs on bott torque,24 ft/hr ROP,MW 9.5Nis 86, ECD's at 9.8 ppg,BGG 89 units.;Directional drill 8 1/2"hole f/11,718'to 11,812'.10K wob,425 gpm-2650 psi,140 rpm-8800 to 17,000 ft/lbs on bott torque,12 to 50 ft/hr ROP,MW 9.5/vis 81,ECD's at 9.8,BGG 63 units.;At 06:00 hrs we lost GeoPilot detection/communication.Currently 30'above the C7-7 target zone base, formation dip running at 19 deg.Survey at 04:00 has us 30.37'high and 38.72'right of the line.;Ann Pressure:20"=13 psi/13-3/8"=450 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:7 Hrs/Cum:41 Hrs Metal Recovered:2 lbs/Cum:491 lbs • • 11/24/2017 DD troubleshooting lost detection/communication with GeoPilot.Tool not responding.Circulate at 435 gpm-2848 psi,150 rpm-9300 ft/lbs off bott torque,pumped sweep around to clean hole.BGG 33 units.;Sweep came back 20 bbls late with a 5%in cuttings.;POH pumping out at 90 GPM,270 psi.Had overpulls at 11,266', 12,202',12,179',10,916',10,805',10,771',10,726',10,694'.Highest overpulls were 30k.No packoff issues.POH good f/10,694'to 9992';TD shut do with a VFD fault when we were breaking out with it up in the derrick.Re-set at VFD and everything worked good.Could have something to do with bad weather conditions. High winds.;Continue pumping out of the hole f/9992't/9340'with no issues.Started having overpulls again at 9340',9066',9026',8990',8767,8757',8555'. Pumped out the rest of the way to the window with;no issues.Still never had any packoff issues at any time while pumping out.TD did kick out 2 more times while breaking out of the stds.Mech working with NOV tech on TD issues.Parked bit at 8112'.;Circ bottoms up lx at 425 GPM 2400 Psi at window with little if any show of cuttings,cleaned up rig floor.(Did not see anything pulling BHA through window).;Serviced rig and topdrive.Electrician adjusted parameters on topdrive as per NOV tech.Flow check=static,pumped dry job.;POOH from 8112'to BHA at 445'.Racked back HWDP,jars and NM flex DC.LD shock sub and XO.Serviced shakers and pump#2 during trip.Cleaning suction manifold on pump#2 and pulled seats and valves.;Removed pulser from TM collar and LD TM.Removed RA sources and LD CTN collar.Plugged in and downloaded MWD.LD ALD,PWD,DGR,DM and ADR collars.LD geopilot and Reed PDC bit.Bit graded a 1- 3.;Cleared and cleaned rig floor.Staged BHA#5 components for PU.Cont servicing pump#2.;PU Sperry GeoPilot,MU bit sleeve and Varel V711 PDG1 HRU bit, jetted w/3x12's and 5x1 l's.MU ADR,DM,DGR and PWD collars at 06:00.;Ann Pressure:20"=11 psi/13-3/8"=310 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:41 Hrs Metal Recovered:0 lbs I Cum:491 lbs 11/25/2017 Cont MU of directional BHA#5.MU ALD,CTN and TM collars.;MU XO,pup,and TD.Shallow pulse test tool and tool is not pulsing.;Trouble shoot tools,Break connections and check same.All good.Plug into tools and determine the pulser is bad.;Prep another pulser and change them out.Everything checked out good. Up load tool.;MU XO and pup.MU TD and shallow test tool.Tested good!PU have PJSM and Load sources.Run in and LD XO and pup.;RIH WI Flex collars, jars,and HWDP.Continue to RIH w/41/2 DP to 4170'.[Check swabs and liners in#2 pump while RIH and they all looked good].;Fill pipe and test tool.Good test.;Continue RIH from 4170'to 8084'(stand 123)MU topdrive.Started racking and tally of 7"liner off boat.;Filled pipe,hung off blocks with string in slips.Cont to circ at 260 gpm-1150 psi,cut and slipped 81'of drill line.Finished rack and tally a total 143 joints 7"liner(includes shoe track).;Calibrated block height and checked saver sub(good),checked crown saver and serviced HPU's.C/O a 3"nipple on HPU hydraulic line that had a drip.;TIH on elevators from 8084'to 10,716'.Clean exit through window.Filled pipe at 10,372'.Had our first set down at 10,716'(bit between 2nd and 3rd large coals).Could not work through on elevators.;MU topdrive,filled pipe and washed reamed from 10,700'to 10,751'.Saw some packoff,had to take bites and work pipe accordingly.TIH on elevators from 10,751'to 10,792'and set down again.Couldn't;work through on elevators.MU topdrive and washed reamed from 10,790'to 10,809'.TIH on elevators from 10,809'to 10,904'and set down again.Could not work through on elevators.MU topdrive,;filled pipe and washed reamed from 10,900'to 10,932'.TIH on elevators from 10,932'to 11,737 with no further issue.PU was always clean,bit was always between coals on set down.Possibly in-line;stabilizer was hanging us up in the large coals.(set down depths=10,716',10,792'and 10,904').Had indication of packoff on all three tight spots.Washed reamed from 11,737';to bottom at 11,812'gently, in hopes of no bit damage from GeoPilot carbide roller that was lost on last BHA,and to break in bit pattern.Had a max of 547 units gas at bottoms up.;Resumed drilling 8 1/2"hole from 11,812'to 11,831',11K wob,410 gpm-2685 psi,160 rpm-10,000 ft/lbs on bott torque,8 ft/hr ROP,MW 9.5/vis 178,ECD's at 10 ppg,BGG 88 units.;Started building to 77 degrees inclination as per Geo,to get further off bottom of the C7-C sand.;Ann Pressure:20"=20 psi /13-3/8"=150 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:41 Hrs Metal Recovered:0 lbs/Cum:491 lbs 11/26/2017 Cont drilling 8 1/2"hole from 11,831'to 11,901',7 to 10K wob,418 gpm-2625 psi,156 rpm-10,000 ft/lbs on bott torque,12.7 ft/hr Avg ROP,MW 9.5/vis 106, ECD's at 9.9 ppg,BGG 40 units.;Directional drill 8 1/2"hole f/11,201't/11,917',10k WOB,418 gpm,2619 Psi,160 rpm,10k TQ,15 FPH Avg ROP,MW 9.5 ppg,Vis 90,ECD 9.7 ppg,BGG 50 units.;Directional drill 81/2"hole f/11,917'U 11,928'.Not getting the build we want so we backed off on the parameters to break through a hard streak.400 gpm,2440 Psi,120 rpm,9.5k TQ,5 U 6k WOB.;Directional drill 8 1/2"hole f/11,928'U11,959',7 to 12K wob,381 gpm-2182 psi, 120 rpm-7400 to 13,000 fUlbs on bott torque,2 to 5 ft/hr ROP,MW 9.4+/vis 77,ECD's at 9.7 ppg,BGG 77 units.;Time drilled from 11,918'to 11,938'(20')in hopes of working through hard streak and gaining inclination.Decision made to get more aggressive with bit weight as per Geologist at 11,938', f/100'.;Troubleshoot ABI G total errors/severe housing roll at 11,959'.Drilled 5'and housing roll stopped,tool sending good G totals again.DD thinks the cutter wheels were in a washout or;dogleg,allowing sleeve to spin on GeoPilot.Currently at 100%deflection and may be contributing to stick slip.;Service rig and topdrive.;Directional drill 8 1/2"hole from 11,959'to 11,994',11 to 13K wob,391 gpm-2300 psi,160 rpm-9100 ft/lbs on bolt torque,2 to 25 ft/hr ROP,MW 9.5/vis 76,ECD's at 9.7 ppg.BGG 37.;Seeing very little stick slip at 70%deflection and increased weight on bit vs 100%deflection. At 03:15 at a depth of 11,982'We lost communication with ALD.;Tried re-setting w/mode switch,sensor reset,and pumps off intervals.Tool would not respond.Notified Geo and decision made to drill the remaining 50'of 100'planned earlier(can madd pass later).;After making connection at 11,989',ALD started working again.Drill string walking right but not building Inc.Last survey at 11,922'has us 66'high and 78'right of original plan.;Ann Pressure:20"=20 psi/13-3/8"=380 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:41 Hrs Metal Recovered:1 lbs/Cum:492 lbs 11/27/2017 Cont drilling 8 1/2"hole from 11,994'to 12,052'.6 to13K wob,308 gpm to 384 gpm-1517 to 2233 psi,160 rpm-9.3 to 11 ft/lbs on bott TQ,3 ft/hr ROP,MW 9.5/vis 74,ECD's at 9.7 ppg,BGG 32 units.;Tried the different parameters to build inclination and break through the hard streak we got under.Still not getting through the hard streak.;Time drill 1'per hr f/12,050'U12,055'.250 GPM,1010 Psi,110 RPM,8k TQ.Started w/73.22 Inc.,73.13 Inc at 1800 hrs.;Cont time drilling from 12,055'to 12,061',3K wob,250 gpm-1086 psi,120 rpm-7900 ft/lbs on bott torque,1 to 2 ft/hr ROP,MW 9.5/vis 83,ECD's at 9.7 ppg,BGG 17 units. At 12,061'the GeoPilot ABl;shows 73.66 degrees inclination,indicating a 3.5 deg/100'build rate.Current lithology=90%tuffaceous sandstone and 10% tuffaceous siltstone.;Cont time drilling from 12,061'to 12,068',3K wob,250 gpm-1085 psi,120 rpm-7700 ft/lbs on bolt torque,1 to 2 ft/hr ROP,MW 9.5/vis 84, ECD's at 9.7 ppg,BGG 17 units.;We are 17'into time drilling,current ABI inclination is 73.66 degrees.;Ann Pressure:20"=20 psi/13-3/8"=430 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:41 Hrs Metal Recovered:2 lbs/Cum:494 lbs • 11/28/2017 Cont time drilling from 12,068'to 12,075',4K wob,250 gpm-1080 psi,120 rpm-7700 ft/lbs on bott torque,1 to 2 ft/hr ROP,MW 9.5/vis 84,ECD's at 9.7 ppg, BGG 16 units.At 12,070 to 12,071 the tool;broke loose and went into housing roll for a short period.We are thinking that this may affect the Inc readings we are getting right now.Inc is currently at 73.66 degrees.;Called Geo and decision was made to keep time drilling for up to 6 more hrs to get more angle built.Cant to time dril at 1 FPH f/12,075'U 12,078'.Decided to quit time drilling and push on it;w/the inc staying at 73.48 deg.;Bring everything back up to drilling rate. Bringing the WOB up in stages to 15k.160 RPM,400 GPM,2525 Psi.Drilling f/12,078'slow like we were in the hard formation at 2 to 6 FPH.Inc built up to;74.81 deg by the time we made a connection at 12,109'.ROP also got up as high as 18 FPH.Drilled to 12,109'.;Directional drill 8 1/2"hole f/12,109't/12,183', 7 to 9K wob,410 gpm-2600 psi,160 rpm-11,000 ft/lbs on bott torque,13 ft/hr ROP,MW 9.5/vis 79,ECD's at 9.8 ppg,BGG 38 units.Inc at 77.71 deg.;Cont drilling from 12,183'to 12,235',8 to 10k wob,396 to 412 gpm-2400 to 2614 psi,142 to 160 rpm-9800 to 10,300 ft/lbs on bott torque,8 to 30 ft/hr ROP,MW 9.5/vis 77,ECD's at 9.8 ppg.;BGG 32 units.Seeing better florescence in cuttings.Increased bit wt results in significant stick/slip.Saw some occasional GeoPilot housing roll.Still holding 78 deg inclination,180 deg azimuth.;Ann Pressure:20"=15 psi/13-3/8"=320 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:41 Hrs Metal Recovered:3 lbs/Cum:497 lbs 11/29/2017 Cont drilling 8 1/2"hole f/12,235'to 12,296',410 GPM,2650 Psi,160 RPM,10k TQ,9k WOB,9.5 ppg MW,vis 77,ECD 9.78 ppg,Avg ROP 10.2 FPH,ABI inc 78.15.Working on bringing Inc to 80 degrees.;Cont drilling 8 1/2"hole f/12,296'to 12,369'.400 GPM,2500 Psi,140 RPM, 10 to 11 k TO,8 to 10k WOB,9.4+ ppg MW,74 Vis,9.7 ppg ECD,Avg ROP 12.1 FPH,ABI inc 79.48.Azi 190.13.;Drill 8 1/2"hole f/12,369'U12,420',wob 8K,404 gpm-2502 psi,120 rpm-1',000 Ribs on bott torque,12 ft/hr ROP,MW 9.5/vis 72,ECD's at 9.8 ppg,BGG 41 units.Will stop at 12,450'f/survey.;Service rig and topdrive.Checked torque on mud pump#1,#2 pod,liner retainer and pod bolts.;Cont drilling from 12,420'to 12,450',wob 8 to 9K,402 gpm-2487 psi,120 rpm-10,400 ft/lbs on bolt torque,12 ft/hr ROP,MW 9.5/vis 77,ECD's at 9.8 ppg,BGG 36 units.Survey shows we are still;turning right.Azimuth went from 192.93 at last connection survey at 12,357',to 194.06 at checkshot survey at 12,390',projection at the bit is 196.16 at 12,450'.;Pump a 20 bbl hi-vis hi-wt sweep around at 427 gpm-2743 psi,156 rpm-9200 fUlbs off bott torque.Had 100%increase in pea sized coal 30 bbls early,100%increase in fine sand 29 bbls late.Calculated;surface to surface=850 bbls.Cont circ until clean on shakers.;Ann Pressure:20"=16 psi/13-3/8"=510 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:41 Hrs Metal Recovered:3 lbs/Cum:500 lbs 11/30/2017 POOH on elevators from 12,450'to 11,304'nice and smooth.Up wt 124K.Cont to pump out of hole from 11,304'(top of BHA just under the bottom coal)to 8,083' up inside window.95 GPM,314 Psi,;with no rotation.Had one spot at 10,786'where we pulled 20k over and it packed off.Shut pump down,bled it off,broke it loose going dn,Brought pump back on and pulled thru with no over pull.;Service Rig and pump dry job.;POH f/8,083'U 3,187'.;Continue POH f/3,187't/885', then LD 14 jnts 4 1/2"DP(no room in derrick),rack back HWDP,LD jars,rack back NM flex DC,LD shock sub/float sub.;PJSM,removed RA sources,break off TM collar and remove pulser,plug in and read MWD data,LD remaining BHA.ILS is basically worn smooth,GeoPilot OK,bit graded a 2-3 and 1/16"under gauge.;Bit sleeve,near the pin where there is still hard band,was 3/16"under,and about 5/8"under toward the middle and box end.;Clean and clear rig floor, stage BHA#6 items for PU,cont shaker service,cont pump#1 service.;MU new GeoPilot and 8 1/2"Kymera bit jetted w/2x18's and 2 x 14's.MU DM,new LS, ADR,DGR,PWD,ALD,CTN and TM collars.MU float sub,XO and pup,MU topdrive.Plug in and upload MWD.Shallow pulse;test(OK),PJSM and loaded sources.;MU shock sub w/XO's,1 stnd HWDP,new jars,5 jnts HWDP.Directional BHA#6=445'.Start in hole with 14 jnts DP off catwalk to 553'.;Ann Pressure: 20"=11 psi/13-3/8"=200 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:41 Hrs Metal Recovered:1 lbs/Cum:501 lbs 12/1/2017 Cont TIH w/directional BHA#6 from 553'to 4029'.;Fill pipe and test tools.Everything tested good.;RIH to just above window at 8,076'.;Fill pipe and service rig.;RIH f/8,076'U 10,358'and fill pipe.continue RIH to 10,655'and sat dn 25k.;Attempt to work through.Wash and ream ff 10,655'U 10,682'.Run in U 10,718' and W&R U 10,750'.Run in U 10,776',W&R U 10,807',Run in U 10,852',W&R U 10,991'.Lower coals started at;10,616'and went to 10,890'.We ended up washing and reaming until the upper stab cleared the lower coal.That put the bit depth at 10,983'.W&R @ 2 BPM,390 psi,60 RPM,9k TQ.;RIH on elevators f/ 10,991'U 12,416'with no issue.MU topdrive and filled pipe,then washed to bottom at 12,450'.Downlink to 100%left deflection and break in bit.Max of 246 units gas.;Ease into drilling from 12,450'to 12,491'.9K wob,373 gpm-2445 psi,120 rpm-9475 ft/lbs on bott torque,6 ft/hr ROP.Increased to 20K wob,406 gpm.2681 psi,120 rpm-10,100 ft/lbs on bott torque,;15 to 45 ft/hr ROP,seeing no stick/slip at all.MW 9.5/vis 113,ECD's at 10.0 ppg,BGG 59 units. Did not have a significant amount of coal on shakers at bottoms up.;GeoTech estimates we are about 12 vertical feet above the C7-C Target Zone Base and advises building to 83 degrees inclination.Formation dip appears to be running about 9 to 10 degrees.;Cont directional drilling 8 1/2"hole from 12,491'to 12,595'.18 to 20K wob, 409 gpm-2757 psi,140 rpm-11,000 fUlbs on bott torque,20 ft/hr ROP,MW 9.5/vis 97,ECD's 9.9 ppg,BGG 96 units.;Check shot at 12,481'showed we were turning hard left.Reduced deflection from 100%to 55%left.Survey at 12,540'showed a DLS of 8.22 deg/100'.That survey has us 0.56'high and 1.90'right of the;line going off the Dec 1st look ahead directional plan.Checked torque on new bolts,pump#1 during connection.;Ann Pressure:20"=16 psi/13-3/8"=200 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:41 Hrs Metal Recovered:0 lbs/Cum:501 lbs 12/2/2017 Directional drilling 8 1/2"hole from 12,595'to 12,664',410 GPM,2650 psi,160 RPM,9-10k TQ,14 to 20k WOB.81.77°ABI Inc,186.32°Azimuth.At 12,648'it went f/20s to 6 on the ROP.;Directional drill 8 1/2"hole f/12,664',U12,693'.ROP is still dn between 4 to 7k.Tried different parameters on pump,RPM,and WOB.Also pumped nut plug pill in case bit was balled up.Looks like;we are going through a hard streak.Finally stayed w/368 GPM,2335 Psi,130 RPM,J to 10k TQ,25k WOB.MW 9.5 ppg,ECD 9.8 ppg.;Directional drill 8 1/2"hole f/12,693'U12,735'.15 to 25K wob,360 to 403 gpm-2234 to 2600 psi,140 to 160 rpm- 9600 to 10,000 friths on bott torque,3 to 25 ft/hr ROP,MW 9.5/vis 73,BGG 21 units.;At 12,697'it looked like we broke through hard spot and ROP increased to 25 ft/hr.At 12,710'ROP dropped back down to 7 ft/hr.GeoTech recommends building to 84°Inc to drill through hard streak.;Directional drill 81/2"hole f/12,735' to 12,811'.15 to 25K wob,403 gpm-2600 psi,140 rpm-9800 to 11,700 ft/lbs on bott torque,5 to 35 ft/hr ROP,MW 9.5/vis 78,BGG 109 units.Went through hard;streaks at 12,735'and 12,764'.At+/-12,770'we broke through and ROP increased to the point we could back off to 16K on bit and still make 20+ft/hr. GeoTech has since called for dropping to 81°;Inc by 12,900',and cont turning left to 179°Azimuth.Survey at 12,697'has us 1.95'high and 10.04'left of the Dec 1st look ahead directional line.;Ann Pressure:20"=20 psi/13-3/8"=340 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:41 Hrs Metal Recovered:2 lbs/Cum:503 lbs • 12/3/2017 Directional drill 8 1/2"hole f/12,811't/12,912',17 to 21k WOB,400 GPM-2590 Psi,140 RPM-11,100 ft/lbs on bolt torque,MW 9.5 ppg,ECD 9.8 ppg.;Directional drill 81/2"hole f/12,912'U 13,053'.19 to 21 WOB,400 GPM-2595 Psi,140 RPM,11.5k TQ.9.5 ppg MW,ECD 9.87 ppg.ABI Inc 82.91°, 175.17°Azimuth.;Directional drill 8 1/2"hole ff 13,053'U 13,104',20K wob,402 gpm-2620 psi,140 rpm-11,200 ft/lbs on bolt torque,27 ft/hr ROP,MW 9.5 is 76, ECD's at 9.8 ppg,BGG 97 units.Building to 95°inc,;and 180°Azimuth as per Hilcorp Geologist.At 13,104'Kuukpik electrician found a bad 480 receptacl=in MCC room,while troubleshooting low voltage electrical issue in doghouse.;Racked stand back.Circulated and worked string while servicing topdrive and d aw works,electrician prepped to C/O receptacle in MCC room.;Shut down pump#1,HPU's and centrifuge,circ on pump#2 at 3 bpm,C/O 480 receptacle(rec-ptacle and plug were welded together).;Made connection and resumed drilling from 13,104'to 13,115',21K wob,406 gpm-2710 psi,140 rpm-13,500 ft/lbs on bo torque,25 ft/hr ROP,MW 9.5/vis 80,ECD's at 9.9 ppg,BGG 134 units.;Drill from 13,115'to 13,132',21K wob,406 gpm-2710 psi,140 rpm-13,500 f/lbs o bolt torque,25 ft/hr ROP,MW 9.5/vis 80,ECD's at 9.9 ppg,BGG 134 units.#1 pump suction line airboot leaking.;PU off bottom,shut down and shut in#1 pum.. Cont circ with#2 pump,C/O airboot on#1 suction line.Put pump back on Iine.;Drill from 13,132'to 13,236',21K wob,406 gpm-2710 psi,140 rpm-13,500 lbs on bolt torque,25 ft/hr ROP,MW 9.5/vis 80,ECD's at 9.9 ppg,BGG 133 units.;Centrifuge feed pump wouldn't move fluid after receptacle issue.Flushed centrifuge,verified feed pump suction and discharge lines clear,spear and drum not packed off,centrifuge runs fine.;Had to tighten feed pump belts,centri uge back up and running fine.At 6AM we are+/-63 vertical feet above the C7-C Target Zone Base and at 90°Inc/179°Azi,building toward 95°Inc.;Survey at 14,1 30' and has us 22.37'high and 29.79'left of the Dec 1st look ahead directional plan.;Ann Pressure:20"=18 psi/13-3/8"=250 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:1.5 Hrs/Cum:42.5 Hrs Metal Recovered:2 lbs/Cum:505 lbs 12/4/2017 Cont directional drilling 8 1/2"hole f/13,236'U 13,352',18K wob,406 gpm-2682 psi,140 rpm-13,600 ft/lbs on bott torque,30 ft/hr ROP,MW 9.6/vis 78,El D's at 9.9 ppg,BGG 160 units.;Cont directional drilling 8 1/2"hole f/13,352'U 13,463'.17 to 19k WOB,401 GPM,2628 Psi,160 RPM,13k TQ,MW 9.5 ppg,Es°9.8 ppg,BGG 107 units,Up wt 154,Dn wt 106,Rt wt 122.;Cont directional drilling 81/2"hole f/13,463'U to 13,493',10,712'tvd where we called TD due to ge ing into a couple coals and being at 100°inclination.20K wob,409 gpm-2694 psi,160 rpm-;13,400 ft/lbs on bott torque.Torque got very erratic.Notified servi reps and Geologist of TD.At this point,Kymera bit has 500 k-rev's but still drilling good.;Downlinked to zero deflection and obtained survey on bottom.LD one si gle jnt,racked back one stnd to get clear of coals,circulated bottoms up 1 X at 429 gpm-2940 psi,160 rpm-12,300 ft/lbs off bott;torque,to allow mud loggers to•btain sample.Circulated at 13,416'.;Pulled up hole on elevators from 13,416'to 13,204'with no problem.Up wt 152K.This puts us back in 90°inclination portio of the wellbore.;At 13,204'pumped 35 bbls 11.5 ppg weighted pill followed with 168 bbls 9.5 ppg mud and spotted all but 15 bbls of pill outside drillstring.;Pulled p hole from 13,204'to 12,700'on elevators with no problem.Up wt 148K.We will no longer make any trips below 12,700'.;At 12,700'pumped hi-vis hi-weight sweep around at 429 gpm-2974 psi,160 rpm-9800 f/lbs off bottom torque.Had 100%increase in cuttings to surface,sweep came back 35 bbls late.Folio ed ti sweep with;an additional bottoms up at same rate.;Pulled out of hole from 12,700'to 11,334'on elevators with no issue.At 11,334'top of BHA is just below large i coals.Cont pumping OOH from 11,334'to 9800'.Had a 30K over pull at 10,985',a;50K over pull at 10,870'and seeing slight packoff and a 25K over pull a 10,406'.Worked these areas a couple times and cleaned up.Pumping at 80 gpm-224 psi,no rotation.;Ann Pressure:20"=16 psi/13-3/8"=240 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:42.5 Hrs Metal Recovered:1/Cum:506 lbs 12/5/2017 Pump out of the hole ff 9800'U 8122'.;Clean floor and cut 135'of drill line.;Service rig and draw works.;POOH from 8122'to 445'.(UD last 24 jts of DP).;M/ test plug&test jt&hang off BHA.C/O lower pipe rams to 7".R/U to test BOPE.;Test BOPE w/4-1/2",7",&2-7/8"test jts.Tested gas alarms.Witness waived b AOGCC Jim Regg.;R/D testing equipment.Break down&UD test jt.UD test plug.C/O air boot on bell nipple.;Rack back HWDP&jars.Remove sources&up- load LWD data.LID BHA#6 as per Sperry.;Ann Pressure:20"=16 psi/13-3/8"=240 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:42.5 Hrs Metal Recovered 0/Cum•506 lbs 12/6/2017 Download MWD and lay down BHA#6.Graded bit 3-2-RO-N-E-I-WT-TD.;Clean and clear rig floor.;Make up BHA#7 clean out assembly.;RIH with BHA#7 o 8110' filling pipe every 2500'.;Circulate and condition mud at 430 GPM/1900 psi.;RIH on elevators f/8110'to 10,630'.W&R thru coals w/2.5 bpm&30 rp (/10,630 to 10,950'.Cont.to RIH on elevators f/10,950'to 13,015'.;Circ&cond mud for liner run w/420-450 gpm,2400-2600 psi,160 rpm,9.5-10 k trq. s.5 ppg In/Out.;POOH on elevators f/13,015'to 11,396'.;Pump OOH with 2 bpm,250 psi f/11,396'to 10,999'.;Ann Pressure:20"=14 psi/13-3/8"=130 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:42.5 Hrs Metal Recovered:0/Cum:506 lbs 12/7/2017 Pump OOH with 2 bpm,250 psi f/10,999'to 8100'.;Clear and clean rig floor.Pump dry job.;POOH from 8100'to 5016'.;Service rig.;POOH laying down exc=ss drill pipe 150 jts f/5016'to 357'.;Rack back HWDP&UD clean out BHA.;Clean&clear floor.of BHA tools&equipment.Remove Sperry transducers from m d lines.Break down Sperry Geo-Span.;R/U Weatherford&prep to run liner.Work boat.;PJSM.M/U shoe track&check floats(good).;RIH 7"DWC liner as pe tally to 1,281.;Ann Pressure:20"=20 psi/13-3/8"=170 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:42.5 Hrs Metal Recovered.0/Cum•506 lbs 12/8/2017 RIH 7"DWC liner as per tally from 1,281'to 4,114'._Fill pipe every 10 joints.Ran a total of 96 centralizers.;Continue RIH 7"DWC liner as per tally from 4,1 4'to 5,037'.Confirm 17 joints and 1 shoe joint left on pipe deck.;Make up liner hanger assembly as per BOT hand.Fill with ZanFlex. RIH one stand to 5128'.;Cir ulate one liner volume at 5 BPM/480 psi.;RIH with liner hanger assembly from 5,128'to 8,080'.;Circ&cond mud while slip&cut drill line.;Obtain torque and drag parameters.PU 125,SO 108,ROT 115,20 rpm/6200,30 rpm/6500,2 bpm/320 psi,4 bpm,450 psi.;M/U cement head&space out pumps&stage on dan•e floor for cement job.;Cont.to RIH with liner f/8,080'to 10,730'.Started taking wt in coals.P/U to 10,720'.Break circulation&start washing&reaming liner wi h various parameters.5-2 bpm&20 rpm to 10,790'.;Hole trying to pack off&torqueing up.Inching our way thru the coals.Bottom of coals 10,900'.;Ann Pre -ure: 20"=20 psi/13-3/8"=170 psi Downhole Losses:0 bbls/Cum:29.5 bbls Code 8:0 Hrs/Cum:42.5 Hrs Mafia)Rarnvararl 0/num'5r1B Ihs • • 5- 12/9/2017 Wash and ream liner 10,790'to 10,820'at 1 BPM/200 psi,20 RPM/14-18 K torque.130K Rot,115 S/O,165 P/U.;Work s ck pipe ith pack off 10,820'an• finally able to get movement and circulation after working between 110 k down and 220 K up.;Wash and ream 10,820'to 10,8 0 with above parameters an fighting pack-off issues.;Work stuck pipe with pack off 10,820'and finally able to get rotation but not circulation.;Ream down at 30 RPM/13-18K torque fro 10,820'to 10,893'.Not able to make forward progress.;Work stuck pipe @ 10,893'.Not able to circulate or rotate.;Discuss plan forward options with town. Decision made to release from liner without setting packer.;Secondary release from liner as per Baker rep rack back DP to 5,722'. Packer not set.Top of li -r 5821'/Shoe 10,893'.;Circ B/U w/6.2 bpm,475 psi.Pump dry job.;POOH f/5,722 to liner running tools.;Break out&UD liner running tools.Break down ce ent head&M/U Baker handling pup.;M/U test plug&test joint.C/O lower pipe rams to 2 7/8"x 5"VBR's.Test lower rams 250/3500 psi.R/D testing equipment Stage Pollard E-line unit&tools.;Ann Pressure:20"=37 psi/13-3/8"=150 psi Downhole Losses:5.5 bbls/Cum:35 bbls Code 8:0 Hrs/Cum:42.5 Hrs Metal Recovered:0/Cum:506 lbs 12/10/2017 Rig up Pollard e-line unit.;RIH and set CIBP at 10,550'. RIH and perforate 10,500'to 10,504'with 20 shots/.42 diameter.All shots fired. RIH and set cern:nt retainer at 10,475'.;Rig down Pollard e-line unit.;Pick up cement stinger,drill collars and HWDP.RIH with stinger assembly to 10,420'.;Circ&cond mud w/'..2 bpm,1090 psi.;Cont.to RIH f/10,420'w/1 bpm @&sting into retainer @ 10,472'.Break circulation&stage flow rate up to 4 bpm.;Circ&cond for cement jo.. Stage flow rate to 5 bpm,980 psi,full returns.;Ann Pressure:20"=34 psi/13-3/8"=160 psi Downhole Losses:0 bbls/Cum:35 bbls Code 8:0 Hrs/Cum:42.5 Hrs Metal Recovered:0/Cum:506 lbs 12/11/2017 Circ&cond for cement job.Stage flow rate to 5 bpm,980 psi.,full returns.Mix mud push.Rig up SLB cementers.;Hold PJSM with all to be involved in ce ent job.Pressure test lines at 500 U3800 H.;Pump 20 bbls/12 ppg mud push at 5 BPM/980 psi.SLB pump 56.5 bbls of 15.3 ppg EasyBlok cement.Rig chas>with 134.5 bbls OBM(caught pressure at 72 bbls).Final pressure 1700 psi.Un-stung from;retainer with 600 psi and pressure went to 0 psi.Cement in place at 1:15 hours.Pull up an additional 5'.Circulate bottoms up at 7 BPM/1700 psi.No cement at bottoms up.;Rig down cement lines and side entry sub.Pump pipe w per& circ clean at 8 BPM/2250 psi.Pump dry job.;POOH with cement stinger f/10,450'to surface.(UD 2 jts 4-3/4"collars&UD cement stinger).;Service rig,top drive &draw works.;M/U Baker dog sub BHA&RIH to TOL @ 5,821'.;Set packer as per Baker rep with no issues.R/U to test packer.While attempting to pressu test packer started having communication with 13-3/8"X 9-5/8"annulus.:Pressure up to 500 psi&saw a 500 psi increase on OA.Bleed off pressure&R/D testi g equipment.;Ann Pressure:20"=35 psi/13-3/8"=160 psi Downhole Losses:0 bbls/Cum:35 bbls Code 8:0 Hrs/Cum:42.5 Hrs Metal Recovered:0/Cum:506 lbs 12/12/2017 Pump dry job.POOH with packer setting tool.Lay down 61/2"collars and setting tool.;Clear and clean rig floor.;P/U M/U milling assembly.RIH with same tiling pipe every 3000'. Hit obstruction at 1547'with 15K set down.Had to rotate 90 degrees to get past.Cont TIH to 4728',then PU and singled in to 7059'.;Saw just a slight bobble with bit entering top of liner hanger at 5821'.Set down a couple times at 5834'(6.16"ID of ZXPN packer assembly).MU topdrive and rotated- 10 rpm.Took some weight then;fell through.Saw nothing at the 6.22"ID of the lower liner hanger assembly.;Serviced rig and topdrive,swapped elevators arou d to trip from derrick.;Cont to TIH with stands from 7059'to 10,421'.Filled pipe at 10,421'.Up wt 153K,dwn wt 123K.;Cut and slipped 119'of drill line.Calibrate• block height.;MU topdrive and eased down tagging solid at 10,467'.PU,break circ at 6 bpm-1436 psi,80 rpm-6750 ft/lbs off bott torque.Ease down and s.rt drilling cement/retainer with 5K wob,80 rpm,250 gpm.;Top of retainer at+/-10,472'.frilled out bottom of retainer at 10.474'.then tagged cement again at 10,500'.Cement appears to be good and hard.Bit depth at 6AM=10,501',CIBP=10,550'.;Ann Pressure:20"=50 psi/13-3/8"=175 psi Downhole Losses:0 bbls/Cum:35 bbls Code 8:0 Hrs/Cum:42.5 Hrs Metal Recovered:0/Cum:506 lbs 12/13/2017 Cont drilling cement from 10,501'to 10,548',8K wob,250 gpm-1452 psi,90 rpm-6817 ft/lbs on bott torque,;Drill CIBP from 10,548'to 10,551'with above q4parameters.;TIH from 10,551'to 10,762'.Drill landing collar at 10,762'to 10 766'.;Fj1H to 10,807'.Drill float collar 10,80T to 10,809'.RIH to 10,890'.Drill flo:t O collar 10,888'to 10,893'.;Circulate 10 bbl sweep around while rotating and reciprocating pipe.250 gpm-1400 psi.;TIH on elevators from 10,893'to 13,020' ith no issue.;Pump hi-vis hi-wt sweep around at 275 gpm-1663 psi,60 rpm-8100 ft/lbs off bott torque.30%increase in cuttings to surface and back on time.Shut•own and flow check=static.;Pulled up hole on elevators 34 stands from 13,020'to inside 7"casing at 10,844'.Up wt 170K.No issues.Offloaded PH-6 workstrin•and 5"liner from boat.;CBU 1 time at 400 gpm-2800 psi,50 rpm-6793 ft/lbs off bott torque.Pumped dry job.;Service rig and topdrive.;POOH from 10,10,844'to 944' racking DP back in derrick,then start LD DP from 2944'to 1964'.Did see 6K drag while pulling 6 1/8"bit up through 7"liner top packer(6.16"ID);;Ann Pre sure: 20"=38 psi/13-3/8"=170 psi Downhole Losses:0 bbls/Cum:35 bbls Code 8:0 Hrs/Cum:42.5 Hrs Mptal Rprovprpd n/Cum•Sns the 12/14/2017 Cont POOH LD 4 1/2"DP from 1964'to HWDP at 812'.Lay down drill out jewelry.Recover 35 lbs metal from boot baskets.;Clean and clean rig floor.;Make p 8 1/2"casing milling BHA.;RIH through 1500'to 1600'with 8 1/2"milling assembly.Encountered nothing.POOH and lay down milling assembly.;Clear floor. 'ig up 'Weatherford.Hold PJSM.;MU up 5"shoe track and check floats(OK).Shoe track is DWC,torqued to 10,400 ft/lbs and Baker Locked.Cont to PU RIH with .:total �}� of 56 jnts 15#,5",BTC-TKC,L-80 liner torqued at 7000 ft/lbs,top;filled on the fly and topped off every 10 jnts.Total length of liner=2539'.Ran no centraliz-rs. V 12 jnts left on deck.;Cleaned and cleared rig floor,CO elevators to 3 1/2",MU Baker Production Liner Hanger Assembly(HRD-E ZXP liner top packer,"RS" packoff seal nipple,Flex Lock Liner Hanger),mixed and poured PalMix;CO elevators to 4 1/2",RD Weatherford tongs and removed from rig floor,RIH one nd 4 1/2"HWDP,MU topdrive,circulated one string volume at 213 gpm-188 psi.Up wt 47K,dwn wt 47K.;Cont TIH 17 more jnts HWDP,then 4 1/2"DP to 5757',just above 7"liner top,MU topdrive and filled pipe every 10 stands.Saw nothing when shoe or liner hanger went past 1547'(bad spot in casing).;MU topdrive, pumped one full circ at 207 gpm-376 psi,MU pup joints on Baker cement head while circulating,staged cement head on catwalk.;;Ann Pressure:20"=31 •si/ 13-3/8"=160 psi Downhole Losses:0 bbls/Cum:35 bbls Code 8:0 Hrs/Cum:42.5 Hrs Mptal lg. nvorari•15 i ri im SA1 the • • 12/15/2017 At 5757',up weight 84K,down weight 80K,rotating weight at 20 rpm 82K.Torque at 20 rpm=3000 ft/lbs.Cont TIH entering 7"liner top at 5821'with no issue. Cont filling pipe every 10 stands.;Continue RIH with liner assembly from 5821'to 10,843' filling pipe every 10 stands.;Circulate and condition mud at 3 BPM/600 psi.;RIOH with liner assembly from 10,843'to 13,018'filling pipe every 10 stands.;Obtain parameters after making up cement head:158 P/U,114 S/O,132 Rot at 20 RPM/9 K torque.3 BPM/630 psi.;Stage pump rate up to 4.5 BPM/990 psi while rotating/reciprocating pipe.Circulate and condition mud until 9.6 ppg in and out.RU SLB cementers.;Held PJSM with SLB crew,rig team,Baroid and Baker Reps on upcoming cement job.;SLB pumped 5 bbls water to flush lines,then 5 bbls to fill lines.Shut in cement head and PT lines at 850 and 4400 psi.Rig pumped 19.3 bbls of 12 ppg Mud Push II at 4.5 bpm-906 psi,lined up cement;head to SLB.SLB pumped 95 bbls(392 sx)15.3 ppq Class"G"Easy Blok Lead cement at 4 to 5 bpm,800 to 500 psi,with full returns and shut down.Baker released dart,then rig displaced with 9.6 ppg;OBM mud at 5.5 bpm-218 psi.Slowed to 2 bpm with 125 bbls displaced and saw dart latch wiper plug 135 bbls into displacement(calculated at 140 bbls).With 10 bbls to bump,reduced rate to 2 bpm-900;900 psi and bumped plug/landing collar 183 bbls into displacement (calculated at 186 bbls).FCP 900 psi.Rig pump increased to and held 1442 psi(500 over fcp)for 3 minutes.Bled back 1/2 bbl to pit;#1 and floats held.Lined up to SLB and pressured up to 2800 psi to shear pins,then increased to 4100 psi to release HRD-E run tool,bled off as per Baker Rep.Slacked off on blocks from 155K to 60K;giving us a good indication hanger was set.Pumped a total of 114 bbls with a total of 107 bbls returned. Lost 7 bbls during displacement. CIP at 20:16 on 12-15-17.;Rotated and reciprocated throughout entire job,20 rpm-8700 to 9300 ft/lbs torque.Estimated TOC=11,008'(92.5 bbls cement x 21.780 linear feet per bbl)5"shoe at 13,023';PU to 150K and marked pipe,then PU 6'to clear dogs from hanger top and had good indication we released liner string.SO to 80K to set packer with good indication of shear.PU,rotated at 20 rpm,;7000 ft/lbs torque,SO and set down to 90K to ensure weight transfer to set packer.Top of liner hanger at 10,449',top of landing collar at 12,889'.Due to hole in 9 5/8"casing at+/-1547',we;could not shut in and pressure test against HRD-E ZXPN liner top packer.LD SLB circ lines and manifold,LD Baker cement head.;MU topdrive.Pressured up to 500 psi on drill string and PU 45'.Once psi dropped rig started pumping and did one bottoms up at 266 gpm-1280psi. Had 19 bbls of MudPush and no cement to surface.Shutdown pump,racked back one stand, installed wiper ball in drill string,MU topdrive and pumped second circulation at 263 gpm-1175 psi.Pumped dry job.;POOH with Baker HRD-E running too from 10,479'to 4106'.;;Ann Pressure:20"=32 psi/13-3/8"=160 psi Downhole Losses:7 bbls/Cum:42 bbls Code 8:0 Hrs/Cum:42.5 Hrs Metal Recovered:0/Cum:541 lbs 12/16/2017 At 4106'shut down and service rig and topdrive.Mechanic replacing a couple broken bolts on draw works hydraulic drive motor.;Repair broken bolts on 5th gear hydraulic motor.;POOH with running tool from 4106'to BHA.;Clean and clear rig floor.Rig up Weatherford.;Make up 5"scraper assembly.RIH picking up 81 jnts 2 7/8"PH6 work string.MU XO's,3 boot baskets,7"scraper,XO's,ran 19 jnts HWDP then TIH on 41/2"DP to 12,895'tagging landing collar on;stand 158 and single.LD top single off stand 159 and MU topdrive to circulate.Cleaned pits and loaded them with diesel while tripping.;Break circ with OBM at 112 gpm-847 psi,park drill string in slips and cut/slip 124'drill line while circ.Transferred excess OBM to beam tank,prep hi-vis spacer for displacement.;;Ann Pressure:20"= 31 psi/13-3/8"=150 psi Downhole Losses:0 bbls/Cum:42 bbls Code 8:3 Hrs/Cum:45.5 Hrs Metal Rpcov"r'rl•0/Cum 541 lbs 12/17/2017 Cont circulating at 12,890',on top of landing collar,while finish up cut and slip drill line.112 gpm-864 psi,no rotating.;Displace well with diesel at 6 BPM taxing OBM returns to platform beam tank.Pumped a total of 634 bbls. 13 318"x 9 5/8"annulus dropped down to 15 psi.;Function rams.Flush kill line,choke lines,gas buster,rig floor bleeder and trip tank fill line.;Service rig.;POOH with dual wiper assembly from 12,895'to 11,650'.Began pulling wet.;Pump 7 bbls water wi:h test pump for dry job.;POOH with dual wiper assembly from 11,650'to 2862'(3 stands HWDP racked back).Broke off next single HWDP.;MU XO's and Tri-Point 9 5/8"storm packer.MU assembly on stump and RIH 329'.Set packer on third attempt.Filled stack and riser with diesel,closed upper rams and pressured up to 1543 psi through;kill line.Saw no increase in psi in the 13 3/8"annulus.Good test.Bled off psi and opened upper rams.Rotated left with topdrive 15 turns and un- stung run tool.POOH racking back 2 stands;DP and 3 stands HWDP.LD single HWDP and run tool.Top of storm packer at 329'.;Drained stack and riser of diesel by pumping same into trip tank,blew down mud lines,cleaned and cleared rig floor,pulled mouse hole,removed flow line,shut down and bled off koomey unit,pulled;rotary table,ND choke and kill lines,pulled flow riser.Start ND of BOP stack from riser.Finished offload a total of 154 jnts 7"casing.;;Ann Pressure: 20"=38 psi/13-3/8"=60 psi Downhole Losses:0 bbls/Cum:42 bbls Code 8:0 Hrs/Cum:45.5 Hrs Metal Recovered:0/Cum:541 lbs 12/18/2017 P/U BOP's and set on trolley.R/U lift plate and pull riser.Remove adapters and casing spool off of riser.Install new 2 1/16"valves on wellhead.Set new 7"casing spool.Set spacer spool.;Set riser,set BOP stack.Install graylock clamp,hammer up flange bolts,install choke and kill lines,install flow box,flow riser and flow line.Set drip pan and rotary table.Open bottom gates and;swap to 7"rams.Cleaned pits and troughs.Offloaded seal assembly from boat.;Finish ram change and button up doors.MU 7"test joint and 7"hanger w/2 way check for test plug.Land test plug in wellhead and flood stack and riser.Tighten up loose flanges(oaks). RU test chart;Test upper wellhead,riser and bottom of BOP flange against lower 7"rams at 250/3500 psi.Good tests.Close annular and attempt test,kill line leaked.Tighten same.Test 7"on annular,choke line;breaks and kill line breaks at 250/3500 psi.Good tests.Drain stack/riser,pull test plug,break down and lay down test joint assembly.Finished cleaning pit#5.;;Ann Pressure:20"=38 psi/13-3/8"=60 psi Downhole Losses:0 bbls/Cum:42 bbls Code 8:0 Hrs/Cum:45.5 Hrs Metal Recovered:0/Cum:541 lbs 12/19/2017 Cont drain stack and riser,pull test plug and LD 7"test joint assembly.PU single jnt HWDP and MU XO's+storm packer stinger. New RKB=52.65';TIH 3 stands HWDP and 2 stands DP.Tag storm packer at 329'.Engage storm packer with 12 rnds to the right with no issue.Fill stack,close upper rams,pressure up to 1500 psi testing lower flange on;new casing head through kill line.20"psi=0,13 3/8"psi=36.No leaks on casing head,increased pressure to 3000 psi and held 5 minutes on chart.No leaks.No change in outer annulus pressures.;Bled off pressure,opened upper rams,straight pull up and released storm packer with no issue.Allowed packer to relax 10 minutes.;POH f/3196't/2495',LD packer.Continue POH to 2473'and LD scrapers and boot baskets.Recovered sand and small chunk of BP slip segment.;RU and circ on tbg due to it flowing back and out of balance.MU tbg XOs for safety valves.;Hold PJSM and RU Weatherford tongs.Tongs leaked hyd fluid.RD tongs and RU spare set.They tested out good!;POH standing back 18 stds of 2 7/8"PH6 tbg and laying do the last 45 jts.LD i, clean out tools.Clean and clear rig floor.;RD power tongs.RU 7"power tongs,swap elevators and slips.MU XO/TIW and stage on floor.Service rig and topdrive, ./ CO airboot on flowline.Held PJSM with Weatherford,Baker and crew.;PU Baker 7.625"tie back bullet seal assembly with 8.25"no/go.Overall length=13.56'.PU and single in with 7"26#L-80 DWC/C casing.Torqued to 19,300 ft/lbs.At 5552'at 6AM.Liner top at 5820'.;;Ann Pressure:20"=36 psi/13-3/8"=50 psi Downhole Losses:0 bbls/Cum:42 bbls Code 8:0 Hrs/Cum:45.5 Hrs Metal Recovered:0/Cum:541 lbs • • , a'� f 12/20/2017 Cont PU single in with 7"tieback liner from 5552'to 5799'(jnt 146).Up wt 124K,dwn wt 105K.;At 5799'CO elevators to 4 1/2",hang a stand 4 1/2"DP,M XO's and MU on 7"stump.MU topdrive and break circ at 2 bpm-Opsi.SO slowly with 5'stick and saw pressure building at 5831,;33.5'in on stand of DP.Down ump and bled off.SO and tagged NO-GO 41'in on stand,set down 10K.PU to 7"liner.Rack back stand,broke off XO's,LD jt 146.MU 19,71'pup,XO pup,an• hanger w/pup.;Land hanger putting the top of the liner hanger pkr 7'deeper than it was previously thought to be at 5828'.Pack-Off liner hanger and RILDS.;RU and test 7"liner hanger,7"seal assem,and 5"liner top to 2600 psi for 30 min on a chart.Lost 100 psi in 30 min.Took 7 bbls to pressure up and got back bbls when we bled it off.;Pump out stack and set BPV in 7"liner hanger.Break out bottom XOs on landing jt and LD same.;Swap from drilling AFE to completion AFE at 1200 hrs.;Ann Pressure:20"=36 psi/13-3/8"=50 psi Downhole Losses:0 bbls/Cum:42 bbls Code 8:0 Hrs/Cum:45.5 Hrs moat Rpcnvprpd•0/Cum•541 the • • Hilcorp Energy Company Composite Report Well Name: GPF GP 24-13RD2 Field: County/State: ,Alaska (LAT/LONG): ?Nation(RKB): API#: Spud Date: Job Name: 1711829C GP 24-13RD2 Completion Contractor AFE#: AFE$: l;w*ttY :. ,s.. \,..\;�,\' >,.:..:...............:................. MINOES. . .ITirl+er3t.:.:'::::':.:'::':+.::.'.:::::::,..,,,...... 12/20/2017 Swapped to completion AFE at 1200 hrs.Pull back floor plates,rotary table, drip pan,flow line,flow nipple,flow box,and get PU slings strung and rigged up to stack.Break off kill and choke lines.Break bottom bolts on BOP stack.PU stack and get it set on the trolley.Roll trolley back out of the way.,Hook up PU slings to Riser and start removing bolts at wellhead.Pull riser out of wellhead room to rig floor and crane out on the deck.,Remove adapter and spacer spool from riser. Make up adapter spool to tubing spool with lift plate and lower to well head room. Prep flanges.,Nipple up tubing spool,test void 500/5000 psi for 15 minutes- good. Lower annulus valves into well head room. Pick up riser and lower it to wellhead room.,N/U spacer spool,riser,and BOPE. Hook up choke,kill I ne and demco line. Torque all bolts to spec. Install flow line,fill p line,and flow box. Add 6.5"to bell nipple and install. Chain off stack. Install mouse hole. Charge koomey. Flood choke lines.,Ann Pressure:20"=37 psi/13-3/8"=48 psi Downhole Losses:0 bbls/Cum:42 bbls Code 8:0 Hrs/Cum:45.5 Hrs Metal Recovered:0/Cum:541 lbs 12/21/2017 Change lower pipe rams f/7"t/2 3/8".MU 4 1/2"test jt.,Pull BPV.Run in and land out test jt. RU to test BOPs.Work air out of system and do pre-test on annular and outsides choke valves.,Test BOPs.Test annular to 250 and 2500 Psi.Test all other BOP equip to 250 and 3500 Psi.Test PVT both gains and losses. Pull and break dn 4 1/2"test jt.,MU 2 3/8 test jt and test annular to 250 and 2500 Psi and lower pipe rams to 250 and 3500 psi.Had 2 of the packing nut for the lock down screws leak.Tightened packing nuts and it tested good.LD 2 3/8 test jt and PU 2 7/8 test jt.Test upper VBRs to 250 and 3500 Psi.Perform accumulator test.Test blind rams to 250 and 3500 psi.Test manual and remote choke.Rig floor gauge for remote wasn't operating.,BOPE test witness by AOGCC rep Matt Herrera.,Electrician working on remote choke gauge.Pull test plug and drain water out of stack to production.Break down test equip. [Bringing on 2 7/8"completion tbg from boat while testing BOPs.],Clean and clear rig floor. RU Pollard E-Line. M/U CBUCCL/Gamma tool string.,RIH with CCUCBUGamma on E-line. Set down at 11,354',attempt to work past but unable to. Log from 11354'up. Send logs to town and discuss.,R/D E-Lin Electrician continued working on remote choke gauge,functioning properly now.,PJSM. R/U to RIH with 3-1/8"6SPF SDP TCP assembly.,RIH with TIP assembly picking up TCP's from basket to 1261'. P/U and M/U firing head and packer assembly.,Ann Pressure:20"=0 psi/13-3/8"=0 psi Downhole Losses:0 bbls/Cum:42 bbls Code 8:0 Hrs/Cum:45.5 Hrs Metal Recovered:0/Cum:541 lbs 12/22/2017 Continue PU perf assem.Run 10 jts 2 7/8 EUE tbg,RA marker sub,36 jts 2 7/8 PH6 tbg,and XOs to DP.,RD tbg tongs and RU to run DP.RIH w/18 jts 4 1/2 CDS-40 HWDP,and continue RIH with 43 stds of CDS-40 DP.Put 200 psi on DP to check and see if the fast fill valve closed. It held press so it was closed.,Continue RIH w/3 1/8 perf guns on DP with no issues when the guns entered the 5"liner.When packer got to liner top at 10,449'it started taking wt.,Attempt to work packer through the 5"liner top.Unable to make any progress.Appears as though the packer has the same OD as the liner hangers ID. [4.25]Decided to POH.,POH standing back the DP,begin pulling wet at stand 43(5938),where the stop fill valve was close.,Service rig:draw works,tcp drive. Change oil in draw works gear box.,Continue to POOH,pulling wet,racking back DP to 2833'.,Rig up Weatherford tongs,observe leak on first set of tongs. Set back down and bring up backup set of tongs.,Continue to POOH racking back PH6 and 2-7/8"tubing.,Lay down JS-2 packer and Hydraulic stop fill valve. Pick up and inspect firing head and 1st joint of TCP-good. Pick up new packer,OD gauge rings(4-1/8").,RIH with TCP assembly 2-7/8"tubing from derrick to 2728'. 12/23/2017 Continue RIH w/3 1/8 pert guns on 4 1/2 DP to 5930'.[43 stds] Fill pipe and pressure up to 200 psi to ensure Fast Fill Valve was closed and it was.,Continue RIH w/3 1/8 pert guns.Took about 1 to 2k when packer went through liner hanger packoff seal nipple.No other drag going in 5"liner.Set bottom shot 6'low on the upstroke as per DP tally.,RU Pollard E-Line to correlate.RIH with E-Line to 11,450'and log up 10,620.Send logs to town. Geo determined we needed to PU 25'to get guns in place and put bottom shot at 12,810'.up wt 165k,dn wt 95k.,RD Pollard and pull pipe up the hole 25'. Put in 4 rounds to the righ:and slacked of setting 15k on the packer.RU Tripoint sensor on the pipe,close annular,and lined up on the choke.Press up the ann to 2000 psi seeing indication of guns firing at 1180 psi.Gun fired at 1600 hrs.Open port on DP side and had a slight blow.Bled ann dn to 500 psi.,PU to 182k and pressure bled off indicating bypass was open.Start pumping dn the DP and caught pressure w/53 bbls away.Kept pumping and got returns from poorboy at shakers at 80 bbls away.This was about 26 bbls early.At 92 bbls away pressure went from 780 psi to 3700 psi by the time the driller got the pump shut down.,Attempt to work pipe from up wt to down wt to see if we could get circ back through the bypass valve. Rig up hose to reverse circulate. Attempt to establish reverse circulation;pressure up to 1200 psi. Slack off on drill string,packer appears to still be set with 15K down on it. Pick up to attempt and open packer bypass,no circulation. Pressure up on drill string to 1400 psi and bleed off quickly attempting to,break loose potential pack-off. Continue working pressure on both drill pipe and casing trying to get circulation. Slack off and verify packer is set. Pressure up on casing to 2200 psi and slowly pick up on pipe to open packer bypass,pressure slowly bleeds off. Establish reverse circulation at 13gpm,pressure building but with returns. Shut down pumps at 2300 psi and allow pressure to bleed,then bring pumps back up,13 gpm with pressure increasing,still with returns. Shut down pumps and bleed pressure.,Circulate hole volume down drill pipe at 2bpm with CP 380 psi,and slowly climbing. Pressure peaked at 497psi at 131 bbls into circulation,discoloration in diesel coming back,weighing 8.1 ppg. Pressure started falling to 90 psi at bottoms up and then down to 0 psi. Shut in and troubleshoot pumps-appears to be fine. Switch mud pumps and continue circulating with ICP 53 dropping to 0,still getting returns„with gas breaking out of it. close choke slightly and observe pump pressure. Continue circulating at 2.5 bpm opening choke as pressure increases from 101 psi to 151,full open choke FCP289 psi. Shut in and check for pressure under bag=0. Open bag.,Well is static. Circulate one more annular volume at 3bpm 500 psi,no losses. Monitor well-out of balance. Pump additional 100 bbls. Monitor well,static. RID hoses.,POOH to'1698', • putting the packer at 10408'and annulus valve(circulation point)at 10382';above the 5”liner top. Calculated displacement. PUW 190K.,Circulate hole volume at 3.5bpm,250-400 psi;fluid still has heavy spots.,POOH laying down drill pipe from 11698'to 11390'. • • 12/24/2017 POH w/pelf gun assem laying dn 4 1/2 DP f/11,390't/7076'.,Continue POH laying dn 4 1/2 DP f/7076't/3278',LD 18 jts 4 1/2 HWDP.,RU Weatherford tbg tongs; R/D rig tongs. Change pipe handling equipment.,Continue to PPOH laying down 36 joints of PH6,standing back 5 stands of 2-7/8"EUE tubing.,M/U crossovers,Pup and TIW on joint of drill pipe for safety joint,swap elevators.,UD Packer,F.F.valve,hydraulic annulus pressure valve,firing head. Lay down 38 joints of TCP guns.,Change out Weatherford tongs due to leak.,Lay down 7 more joints. Tongs leaking. Remove off floor and continue laying down TCP guns,breaking by hand and spinning out the remaining 15 joints. All shots fired.,Clean and clear rig floor. Change out pipe handling equipment to UD remaining drill pipe in derrick. 12/25/2017 LD 25 stds of 4 1/2 DP out of the derrick using the mouse hole.,RU Weatherford tongs to run completion.Hold PJSM.,RIH w/completion.MU wireline guide,X- nipple,packer assem.Run 1 jt 2 3/8 tbg and PU the first GLM. Run 29 more jts of 2 3/8 then cross over to 2 7/8 tbg.Continue RIH PU GLMs as per tally to 3034'.,RIH w/completion f/3034 t/6555'picking up GLMs as per tally.,Continue to RIH with 2-3/8"x 2-7/8"GL completions as per tally.,M/U SSSV and RIH 10 more joints of 2-7/8"tubing,banding SSSV control line at the top and bottom of each joint 21 SS bands used.,Make up hanger and landing joint. Terminate control line and feed through hanger. Land hanger. RILDS and drop ball and rod.,Rig up and pressure up down tubing to 3500 psi to set packer and test tubing to 3500 psi for 30 minutes-good.,Run hose down to annulus valve with pressure sensor. R/U to test annulus to 2000 psi for 30 minutes. Pressure bleeding off,attempt again and still bleeds. Pressure appears to be tracking mud pump pressure. Change out Lo-torq valve that isolates mud pumps,tighten lock down screws. 12/26/2017 Attempt to get pressure test on packer.Pressure up ann to 2300 psi numerous time with the same bleed off results.Go through all surface equip and bleed of air at highest point but pressure still bleeding off.Let pressure bleed off for 1 hr and it went from 2300 psi to 750 psi.Bled off ann and pressured back up on tbg to 3700 psi. Hold for 20 min.Pressure ann back up and had the same bleed off rate.,Bled off ann,Back out LDS,leaving 2200 psi on tbg.Pull hanger off seat and PU to 62k where it looked like it was our up wt.Only moved pipe about 1'not wanting to shear upper shear pins set at 6k over.Bled press of DP and string wt increased to 64k.Land hanger back out and RILDS.Press up on ann to 2200 psi and it bled to 1800 psi in 5 min.Decision was made to POH and change out packers.(Lost 5.3 bbls testingj.,Bleed of pressure and blow dn lines.BOLDS,pull hanger off seat and pull packer free at 90k. Packer was set for 30k overpull.LD 15'DP pup.,lnstall floor valve and RU Pollard slickline lubricator.Test lubricator to 1000 psi.Had issues getting lubricator to hold RIH to retrieve bar.RD pollard.,Well out of balance.Pump 10 bbls water.LD landing jt,XOs,and hanger.MU XOs and floor valve for tbg.,Monitor well while having PJSM for POH standing tbg back in the derrick f/11,445't/11,109'.LD SSSV.,POH standing back 2 7/8 tbg f/11,109't/10,316'.Pulled 10k over 3 times to work packer through the 5"liner hanger.Came through the third time.,M/U FOSV. Slip and cut 221'of drilling line.,Continue to POOH from 10316'to 6952';standing 2-7/8" tubing back,laying down GLM's in order,numbering.,Continue to POOH from 6952'to 56'(packer);standing tubing back,laying down GLM's in order, numbering.,Ann Pressure:20"=9 psi/13-3/8"=10 psi Daily Diesel Losses:5.3 bbls/Cum:5.3 bbls Code 8:0 Hrs/Cum:45.5 Hrs Metal Recovered:0/Cum:531 lbs 12/27/2017 POH standing back 2 3/8 tbg to packer,Break out and LD old packer.Packer looked good with no visible damage.MU new packer.,RIH w/2 3/8 tbg to the xo. Break tbg out of the top of the xo and the threads galled in both the xo and the 2 7/8 jt of tbg.Break out cross over and change out jt of tbg.,Have new XO coming out on a boat due to being weathered in.Work on cleaning pits while waiting on XO.,XO arrived and was made up.Continue RIH w/2 7/8"completion picking up GLM as per tally to 2642'.,Continue RIH with stands out of the derrick for completion to 8420'.Had to change out 1 jt and a collar on the#6 GLM pup due to crossed threads.Also changed out jt#245 due to pulled thread.,Continue to RIH with stands out of the derrick to 11,072',with no issues.Make up SSSV and test. Continue to RIH to 11,399'. PUW 70K,SOW 58K.,Make up hanger. Feed SSSV through hanger. M/U landing joint,drain stack. Land tubing at 11453.86'.,RILDS. Drop rod and wait for 20 minutes. Attempt to pressure up on tubing,rod not landed. Pump rod down 20 bbls,still not landed. Shut down pumps and wait additional 5 minutes. Pressure up on tubing and test tubing to 3800 psi for 30 minutes,good. Rig up and test packer to 2100 psi for 30 minutes-good.,Rig down testing equipment.,Rig up Pollard wireline. RIH and attempt to retrieve rod,first run miss. RIH and retrieve rod.,Ann Pressure: 20"=11 psi/13-3/8"=10 psi Daily Diesel Losses:0 bbls/Cum:5.3 bbls Code 8:0 Hrs/Cum:45.5 Hrs Metal Recovered:0/Cum:531 lbs 12/28/2017 RIH w/slickline run#3 and retrieve the RHC plug. RD Pollard and set TWC.,Go into nipple dn mode.Open ram door and remove all the rams,tighten doors back up.Pull back rotary plate,rotary table,drip pan,flowline,flownipple,and flowbox.,RU PU slings and get tied on to top of Shafer annular.PU stack and pull the studs out of the bottom of the sng gate.Pull stack over onto trolly and set it dn.Secure stack.RU to riser.Pull riser in 2 pieces and set out on the deck.,Clean up hanger seal and prep for tree.Land tree and MU to wellhead Prep to test void.,Rig up and Test tubing head void to 500/5000 psi for 15 minutes. Good.,Install SSV,choke and production piping to tree. Pull BPV,Set TWC.,Fill tree with water and drop test hose down. Test tree to 5000 psi,no leaks held pressure.,Flush out choke manifold and blow down lines. RID testing equipment and clean up wellhead room.,Install rotary table. Prep to skid rig;move jet heater,landing,beaver slide,and flowline. Remove earthquake clamps.,Skid rig 6-7'to the west away from the water. skid support beam for catwalk and reset. Install earthquake clamps.,Remove bails from top drive. Remove rig tongs. Prep to slip on drill line. Hang top drive,slip on 22 wraps. M/U deadman. Note:Change to Kuukpik 5 Demobe&Release AFE as of 06:00. • Hilcorp Alaska, LLC Granite Point Granite Point Platform GP 24-13RD2 50-733-20080-02-00 Sperry Drilling Definitive Survey Report 07 December, 2017 HALLIBURTDN Sperry Drilling • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-24-13RD2 Project: Granite Point TVD Reference: GP 24-13RD2 @ 129.00usft Site: Granite Point Platform I MD Reference: GP 24-13RD2 @ 129.00usft Well: GP-24-13RD2 North Reference: True Wellbore: GP 24-13RD2 Survey Calculation Method: Minimum Curvature Design: GP 24-13RD2 Database: Sperry EDM-NORTH US+CANADA Project Granite Point 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 GP-24-13RD2,Leg3 Slot6 Well Position +N/-S 0.00 usft Northing: 2,544,538.84 usft Latitude: 60°57'29.201 N +E/-W 0.00 usft Easting: 263,406.53 usft Longitude: 151°19'52.249 W Position Uncertainty 0.00 usft Wellhead Elevation: 129.00 usft Water Depth: 75.00 usft Wellbore GP 24-13RD2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2017 10/2/2017 16.05 73.84 55,439 Design GP 24-13RD2 J Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,123.00 Vertical Section: Depth From(TVD) +N/-5 +EI-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 169.00 Survey Program Date 12/7/2017 . i From To ° ,-' Its ut• t (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 123.00 8,123.00 GP 24-13RD CB-GyroA1180G0087(GP 2_CB-Film-GMS A022Ga:Film camera gyro multi-shot 11/03/1980 8,130.00 8,313.74 MWD_Interp Azi+Sag(GP 24-13RD2) 2_MWD_InterpAzi+Sag H003Mb:Interpolated azimuth+sag correction 11/07/2017 8,373.44 13,461.18 MWD+AX+Sag(GP 24-13RD2) 2_MWD+AX+Sag A004Mb/ISC4:BGGM dec&axial+sag corr. 11/11/2017 Survey , .....,e . 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 0.00 0.00 0.00 0.00 -129.00 0.00 0.00 2,544,538.84 263,406.53 0.00 0.00 UNDEFINED 123,00 0.75 118.00 123.00 -6.00 -0.38 0.71 2,544,538.45 263,407.23 0.61 0.51 2_C8-Film-GMS(1) 223.00 1.00 195.00 222.99 93.99 -1.53 1.06 2,544,537.29 263,407.56 1.11 1.70 2_CB-Film-GMS(1) 323.00 2.25 247.00 322.95 193.95 -3.14 -0.97 2,544,535.72 263,405.49 1.81 2.90 2_CB-Film-GMS(1) 423.00 4.00 186.00 422.82 293.82 -7.38 -3.14 2,544,531.53 263,403.24 3.51 6.64 2_CB-Film-GMS(1) 523.00 5.50 184.00 522.47 393.47 -15.62 -3.84 2,544,523.30 263,402.37 1.51 14.60 2_CB-Film-GMS(1) 623.00 6.00 177.00 621.97 492.97 -25.63 -3.90 2,544,513.30 263,402.11 0.86 24.41 2_CB-Film-GMS(1) 723.00 5.00 183.00 721.51 592.51 -35.20 -3.86 2,544,503.73 263,401.96 1.15 33.81 2_CB-Film-GMS(1) 823,00 5.00 188.00 821.13 692.13 -43.86 -4.69 2,544,495.08 263,400.95 0.44 42.16 2_CB-Film-GMS(1) 923.00 3.50 190.00 920.85 791.85 -51.19 -5.83 2,544,487.79 263,399.66 1.51 49.13 2_CB-Film-GMS(1) 1,023.00 4.00 187.00 1,020.64 891.64 -57.65 -6.78 2,544,481.34 263,398.58 0.54 55.30 2_CB-Film-GMS(1) 1,123.00 6.00 151.00 1,120.28 991.28 -65.69 -4.67 2,544,473.26 263,400.52 3.63 63.59 2_CB-Film-GMS(1) 12/7/2017 1:19:26PM Page 2 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-24-13RD2 Project: Granite Point TVD Reference: GP 24-13RD2 @ 129.00usft Site: Granite Point Platform MD Reference: GP 24-13RD2 @ 129.00usft Well: GP-24-13RD2 North Reference: True Wellbore: GP 24-13RD2 Survey Calculation Method: Minimum Curvature I Design: GP 24-13RD2 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section ? ,Z-; i. (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) rimy) (ft) Survey Tool Name 1,223.00 7.25 150.00 1,219.61 1,090.61 -75.73 1.02 2,544,463.11 263,406.01 1.26 74.53 2_CB-Film-GMS(1) 1,323.00 8.25 158.00 1,318.70 1,189.70 -87.84 6.86 2,544,450.88 263,411.60 1.47 87.54 2_CB-Film-GMS(1) 1,423.00 8.75 163.00 1,417.60 1,288.60 -101.77 11.77 2,544,436.86 263,416.23 0.89 102.15 2_CB-Film-GMS(1) 1,523.00 10.25 158.00 1,516.23 1,387.23 -117.29 17.33 2,544,421.22 263,421.47 1.71 118.44 2_CB-Film-GMS(1) 1,623.00 11.25 131.00 1,614.53 1,485.53 -131.95 28.03 2,544,406.35 263,431.87 5.09 134.88 2_CB-Film-GMS(1) 1,723.00 11.75 133.00 1,712.52 1,583.52 -145.30 42.84 2,544,392.71 263,446.40 0.64 150.80 2_CB-Film-GMS(1) 1,823.00 13.00 131.00 1,810.20 1,681.20 -159.62 58.77 2,544,378.07 263,462.05 1.32 167.90 2_CB-Film-GMS(1) 1,923.00 14.25 136.00 1,907.39 1,778.39 -175.85 75.81 2,544,361.49 263,478.75 1.72 187.09 2_CB-Film-GMS(1) 2,023.00 15.00 136.00 2,004.15 1,875.15 -194.02 93.35 2,544,342.98 263,495.92 0.75 208.26 2_CB-Film-GMS(1) 2,123.00 15.75 140.00 2,100.57 1,971.57 -213.72 111.07 2,544,322.91 263,513.23 1.30 230.99 2_CB-Film-GMS(1) 2,223.00 17.50 136.00 2,196.39 2,067.39 -234.94 130.24 2,544,301.31 263,531.96 2.09 255.47 2_CB-Film-GMS(1) 2,323.00 19.00 140.00 2,291.36 2,162.36 -258.22 151.15 2,544,277.61 263,552.39 1.95 282.32 2_CB-Film-GMS(1) 2,423.00 20.50 141.00 2,385.47 2,256.47 -284.30 172.63 2,544,251.10 263,573.34 1.54 312.02 2_CB-Film-GMS(1) 2,523.00 21.00 141.00 2,478.99 2,349.99 -311.84 194.93 2,544,223.12 263,595.07 0.50 343.30 2_CB-Film-GMS(1) 2,623.00 21.25 144.00 2,572.27 2,443.27 -340.42 216.86 2,544,194.09 263,616.42 1.11 375.55 2_CB-Film-GMS(1) 2,723.00 21.00 142.00 2,665.55 2,536.55 -369.21 238.54 2,544,164.88 263,637.51 0.76 407.94 2_CB-Film-GMS(1) 2,823.00 21.50 141.00 2,758.75 2,629.75 -397.57 261.11 2,544,136.07 263,659.49 0.62 440.08 2_CB-Film-GMS(1) 2,923.00 19.50 141.00 2,852.41 2,723.41 -424.78 283.14 2,544,108.41 263,680.97 2.00 471.00 2_CB-Film-GMS(1) 3,023.00 18.75 142.00 2,946.89 2,817.89 -450.42 303.54 2,544,082.37 263,700.85 0.82 500.06 2_CB-Film-GMS(1) 3,123.00 17.25 140.00 3,042.00 2,913.00 -474.44 322.97 2,544,057.95 263,719.78 1.62 527.35 2_CB-Film-GMS(1) 3,223.00 17.25 142.00 3,137.50 3,008.50 -497.49 341.63 2,544,034.54 263,737.97 0.59 553.53 2_CB-Film-GMS(1) 3,323.00 16.50 145.00 3,233.20 3,104.20 -520.80 358.90 2,544,010.87 263,754.77 1.15 579.72 2_CB-Film-GMS(1) 3,423.00 15.50 145.00 3,329.32 3,200.32 -543.38 374.71 2,543,987.98 263,770.11 1.00 604.90 2_CB-Film-GMS(1) 3,523.00 15.00 140.00 3,425.80 3,296.80 -564.24 390.70 2,543,966.80 263,785.67 1.41 628.42 2_CB-Film-GMS(1) 3,623.00 16.25 143.00 3,522.11 3,393.11 -585.33 407.43 2,543,945.38 263,801.98 1.49 652.32 2_CB-Film-GMS(1) 3,723.00 18.25 140.00 3,617.61 3,488.61 -608.50 425.92 2,543,921.84 263,819.99 2.19 678.59 2_CB-Film-GMS(1) 3,823.00 19.50 143.00 3,712.23 3,583.23 -633.83 446.03 2,543,896.11 263,839.58 1.58 707.29 2_CB-Film-GMS(1) 3,923.00 18.50 142.00 3,806.78 3,677.78 -659.66 465.85 2,543,869.88 263,858.86 1.05 736.43 2_CB-Film-GMS(1) 4,023.00 18.00 140.00 3,901.75 3,772.75 -684.00 485.55 2,543,845.15 263,878.06 0.80 764.08 2_CB-Film-GMS(1) 4,123.00 18.00 141.00 3,996.86 3,867.86 -707.84 505.20 2,543,820.91 263,897.23 0.31 791.23 2_CB-Film-GMS(1) 4,223.00 17.50 144.00 4,092.10 3,963.10 -732.01 523.76 2,543,796.37 263,915.29 1.04 818.50 2_CB-Film-GMS(1) 4,323.00 16.75 145.00 4,187.66 4,058.66 -755.98 540.86 2,543,772.06 263,931.91 0.81 845.29 2_C8-Film-GMS(1) 4,423.00 16.00 140.00 4,283.61 4,154.61 -778.34 557.99 2,543,749.35 263,948.57 1.60 870.51 2_CB-Film-GMS(1) 4,523.00 16.50 143.00 4,379.62 4,250.62 -800.24 575.40 2,543,727.10 263,965.53 0.98 895.33 2_CB-Film-GMS(1) 4,623.00 15.00 147.00 4,475.86 4,346.86 -822.44 590.99 2,543,704.60 263,980.67 1.85 920.10 2_CB-Film-GMS(1) 4,723.00 15.00 147.00 4,572.46 4,443.46 -844.15 605.09 2,543,682.61 263,994.32 0.00 944.09 2_CB-Film-GMS(1) 4,823.00 14.00 152.00 4,669.27 4,540.27 -865.68 617.82 2,543,660.82 264,006.61 1.60 967.66 2_CB-Film-GMS(1) 4,923.00 14.50 153.00 4,766.20 4,637.20 -887.52 629.18 2,543,638.76 264,017.53 0.56 991.26 2_CB-Film-GMS(1) 5,023.00 13.75 150.00 4,863.17 4,734.17 -908.96 640.80 2,543,617.08 264,028.71 1.05 1,014.53 2_CB-Film-GMS(1) 5,123.00 13.75 153.00 4,960.31 4,831.31 -929.84 652.14 2,543,595.97 264,039.62 0.71 1,037.20 2_CB-Film-GMS(1) 12/7/2017 1:19:26PM Page 3 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-24-13RD2 Project: Granite Point TVD Reference: GP 24-13RD2 @ 129.00usft Site: Granite Point Platform r MD Reference: - GP 24-13RD2 @ 129.00usft Well: GP-24-13RD2 < North Reference: la, True Wellbore: GP 24-13RD2 Survey Calculation Method: :-. Minimum Curvature I. Design: GP 24-13RD2 Database: ; E Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,223.00 14.50 158.00 5,057.29 4,928.29 -952.04 662.23 2,543,573.58 264,049.26 1.43 1,060.91 2_CB-Film-GMS(1) 5,323.00 14.50 156.00 5,154.10 5,025.10 -975.09 672.01 2,543,550.34 264,058.57 0.50 1,085.40 2_CB-Film-GMS(1) 5,423.00 15.00 160.00 5,250.81 5,121.81 -998.68 681.53 2,543,526.55 264,067.60 1.13 1,110.38 2_CB-Film-GMS(1) 5,523.00 15.50 164.00 5,347.29 5,218.29 -1,023.69 689.64 2,543,501.39 264,075.20 1.16 1,136.47 2_CB-Film-GMS(1) 5,623.00 16.00 165.00 5,443.54 5,314.54 -1,049.85 696.89 2,543,475.09 264,081.92 0.57 1,163.53 2_CB-Film-GMS(1) 5,723.00 16.00 166.00 5,539.66 5,410.66 -1,076.53 703.79 2,543,448.27 264,088.28 0.28 1,191.04 2_CB-Film-GMS(1) 5,823.00 15.50 170.00 5,635.91 5,506.91 -1,103.06 709.44 2,543,421.63 264,093.39 1.20 1,218.17 2_CB-Film-GMS(1) 5,923.00 15.50 167.00 5,732.28 5,603.28 -1,129.24 714.77 2,543,395.35 264,098.19 0.80 1,244.88 2_CB-Film-GMS(1) 6,023.00 15.25 171.00 5,828.70 5,699.70 -1,155.25 719.83 2,543,369.25 264,102.72 1.09 1,271.38 2_CB-Film-GMS(1) 6,123.00 14.75 170.00 5,925.29 5,796.29 -1,180.78 724.10 2,543,343.64 264,106.47 0.56 1,297.25 2_CB-Film-GMS(1) 6,223.00 13.50 169.00 6,022.27 5,893.27 -1,204.78 728.54 2,543,319.56 264,110.42 1.27 1,321.65 2_C8-Film-GMS(1) 6,323.00 12.50 174.00 6,119.71 5,990.71 -1,227.00 731.90 2,543,297.27 264,113.32 1.50 1,344.11 2_CB-Film-GMS(1) 6,423.00 9.50 185.00 6,217.87 6,088.87 -1,245.99 732.31 2,543,278.28 264,113.35 3.65 1,362.83 2_CB-Film-GMS(1) 6,523.00 9.50 169.00 6,316.52 6,187.52 -1,262.31 733.16 2,543,261.94 264,113.87 2.63 1,379.01 2_CB-Film-GMS(1) 6,623.00 10.50 172.00 6,415.00 6,286.00 -1,279.44 736.01 2,543,244.77 264,116.37 1.13 1,396.37 2_CB-Film-GMS(1) 6,723.00 10.50 180.00 6,513.33 6,384.33 -1,297.57 737.27 2,543,226.61 264,117.27 1.46 1,414.41 2_CB-Film-GMS(1) 6,823.00 8.50 155.00 6,611.99 6,482.99 -1,313.39 740.40 2,543,210.73 264,120.07 4.54 1,430.53 2_CB-Film-GMS(1) 6,923.00 9.50 148.00 6,710.76 6,581.76 -1,327.09 747.90 2,543,196.88 264,127.29 1.48 1,445.41 2_CB-Film-GMS(1) 7,023.00 11.00 152.00 6,809.16 6,680.16 -1,342.51 756.75 2,543,181.28 264,135.82 1.66 1,462.24 2_CB-Film-GMS(1) 7,123.00 15.00 155.00 6,906.58 6,777.58 -1,362.67 766.70 2,543,160.93 264,145.37 4.06 1,483.93 2_CB-Film-GMS(1) 7,223.00 16.25 156.00 7,002.89 6,873.89 -1,387.18 777.86 2,543,136.19 264,156.03 1.28 1,510.12 2_CB-Film-GMS(1) 7,323.00 16.50 161.00 7,098.83 6,969.83 -1,413.39 788.18 2,543,109.78 264,165.80 1.43 1,537.82 2_CB-Film-GMS(1) 7,423.00 17.75 159.00 7,194.40 7,065.40 -1,441.05 798.26 2,543,081.92 264,175.33 1.38 1,566.89 2_CB-Film-GMS(1) 7,523.00 17.50 159.00 7,289.71 7,160.71 -1,469.32 809.11 2,543,053.44 264,185.60 0.25 1,596.71 2_CB-Film-GMS(1) 7,623.00 16.00 162.00 7,385.46 7,256.46 -1,496.47 818.76 2,543,026.11 264,194.70 1.73 1,625.20 2_CB-Film-GMS(1) 7,723.00 16.50 165.00 7,481.47 7,352.47 -1,523.29 826.70 2,542,999.13 264,202.08 0.98 1,653.04 2_CB-Film-GMS(1) 7,823.00 16.00 172.00 7,577.48 7,448.48 -1,550.66 832.29 2,542,971.65 264,207.12 2.02 1,680.98 2_CB-Film-GMS(1) 7,923.00 16.50 169.00 7,673.49 7,544.49 -1,578.25 836.92 2,542,943.98 264,211.19 0.98 1,708.94 2_CB-Film-GMS(1) 8,023.00 16.75 175.00 7,769.32 7,640.32 -1,606.54 840.88 2,542,915.61 264,214.58 1.73 1,737.47 2_C8-Film-GMS(1) 8,123.00 16.75 178.00 7,865.07 7,736.07 -1,635.30 842.64 2,542,886.82 264,215.75 0.86 1,766.04 2_CB-Film-GMS(1) 8,130.00 16.64 178.06 7,871.78 7,742.78 -1,637.31 842.71 2,542,884.81 264,215.78 1.59 1,768.02 2_MWD_InterpAzi+Sag(2) 8,187.35 15.48 188.64 7,926.90 7,797.90 -1,653.09 841.84 2,542,869.06 264,214.59 5.48 1,783.34 2_MWD_InterpAzi+Sag(2) 8,249.61 16.23 200.82 7,986.81 7,857.81 -1,669.44 837.50 2,542,852.80 264,209.91 5.47 1,798.57 2_MWD_Interp Azi+Sag(2) 8,313.74 16.91 212.36 8,048.29 7,919.29 -1,685.70 829.32 2,542,836.71 264,201.41 5.23 1,812.97 2_MWD_InterpAzi+Sag(2) 8,373.44 17.97 222.06 8,105.26 7,976.26 -1,699.87 818.50 2,542,822.75 264,190.30 5.18 1,824.82 2_MWD+AX+Sag(3) 8,434.67 18.95 235.42 8,163.36 8,034.36 -1,712.53 803.98 2,542,810.39 264,175.53 7.08 1,834.48 2_MWD+AX+Sag(3) 8,497.64 20.78 237.06 8,222.59 8,093.59 -1,724.41 786.18 2,542,798.88 264,157.50 3.04 1,842.74 2_MWD+AX+Sag(3) 8,559.82 22.48 237.66 8,280.39 8,151.39 -1,736.77 766.88 2,542,786.92 264,137.95 2.76 1,851.19 2_MWD+AX+Sag(3) 8,620.78 23.56 235.12 8,336.49 8,207.49 -1,749.97 747.04 2,542,774.12 264,117.84 2.41 1,860.36 2_MWD+AX+Sag(3) 8,683.72 24.86 231.42 8,393.90 8,264.90 -1,765.42 726.38 2,542,759.10 264,096.87 3.17 1,871.58 2_MWD+AX+Sag(3) 12/7/2017 1:19:26PM Page 4 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-24-13RD2 "d Project: Granite Point TVD Reference: GP 24-13RD2 @ 129.00usft Site: Granite Point Platform MD Reference: GP 24-13RD2 @ 129.00usft Well: GP-24-13RD2 North Reference: True Wellbore: GP 24-13RD2 Survey Calculation Method: Minimum Curvature Design: GP 24-13RD2 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical' MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section --,-*!":-"-z-.7-,, , (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,743.72 26.70 231.09 8,447.92 8,318.92 -1,781.75 706.03 2,542,743.18 264,076.19 3.08 1,883.73 2_MWD+AX+Sag(3) 8,807.37 28.73 231.35 8,504.27 8,375.27 -1,800.29 682.95 2,542,725.12 264,052.75 3.19 1,897.52 2_MWD+AX+Sag(3) 8,869.07 30.85 228.90 8,557.81 8,428.81 -1,819.95 659.44 2,542,705.94 264,028.85 3.96 1,912.34 2_MWD+AX+Sag(3) 8,931.14 32.94 225.19 8,610.51 8,481.51 -1,842.31 635.47 2,542,684.07 264,004.43 4.62 1,929.72 2_MWD+AX+Sag(3) 8,992.56 34.54 224.35 8,661.59 8,532.59 -1,866.53 611.45 2,542,660.34 263,979.92 2.71 1,948.91 2_MWD+AX+Sag(3) 9,055.69 34.36 225.61 8,713.65 8,584.65 -1,891.79 586.21 2,542,635.60 263,954.17 1.16 1,968.89 2_MWD+AX+Sag(3) 9,118.28 34.94 225.50 8,765.14 8,636.14 -1,916.71 560.81 2,542,611.20 263,928.27 0.93 1,988.50 2_MWD+AX+Sag(3) 9,180.60 34.76 224.28 8,816.28 8,687.28 -1,941.94 535.67 2,542,586.49 263,902.63 1.16 2,008.47 2_MWD+AX+Sag(3) 9,241.15 33.51 224.33 8,866.40 8,737.40 -1,966.25 511.94 2,542,562.66 263,878.41 2.06 2,027.81 2_MWD+AX+Sag(3) 9,305.45 34.78 223.71 8,919.61 8,790.61 -1,992.21 486.87 2,542,537.23 263,852.81 2.05 2,048.50 2_MWD+AX+Sag(3) 9,367.11 34.30 222.51 8,970.40 8,841.40 -2,017.73 462.97 2,542,512.20 263,828.41 1.35 2,069.00 2_MWD+AX+Sag(3) 9,429.05 33.71 223.37 9,021.75 8,892.75 -2,043.09 439.38 2,542,487.32 263,804.30 1.23 2,089.39 2_MWD+AX+Sag(3) 9,489.46 33.78 224.59 9,071.98 8,942.98 -2,067.23 416.08 2,542,463.66 263,780.51 1.13 2,108.64 2_MWD+AX+Sag(3) 9,552.84 33.83 223.85 9,124.65 8,995.65 -2,092.51 391.48 2,542,438.89 263,755.41 0.65 2,128.76 2_MWD+AX+Sag(3) 9,614.39 34.74 219.94 9,175.51 9,046.51 -2,118.31 368.35 2,542,413.56 263,731.76 3.87 2,149.68 2_MWD+AX+Sag(3) 9,677.39 34.43 215.25 9,227.39 9,098.39 -2,146.62 346.54 2,542,385.70 263,709.39 4.25 2,173.31 2_MWD+AX+Sag(3) 9,738.59 34.23 211.33 9,277.93 9,148.93 -2,175.46 327.61 2,542,357.25 263,689.87 3.63 2,198.00 2_MWD+AX+Sag(3) 9,801.39 33.74 207.27 9,330.01 9,201.01 -2,206.05 310.43 2,542,327.02 263,672.07 3.70 2,224.75 2_MWD+AX+Sag(3) 9,857.93 33.94 204.48 9,376.98 9,247.98 -2,234.38 296.69 2,542,298.98 263,657.77 2.77 2,249.94 2_MWD+AX+Sag(3) 9,920.20 34.56 202.11 9,428.45 9,299.45 -2,266.56 282.84 2,542,267.08 263,643.26 2.36 2,278.89 2_MWD+AX+Sag(3) 9,985.81 36.68 199.25 9,481.78 9,352.78 -2,302.31 269.37 2,542,231.62 263,629.07 4.11 2,311.41 2_MWD+AX+Sag(3) 10,045.21 39.27 194.00 9,528.62 9,399.62 -2,337.32 258.97 2,542,196.83 263,617.96 6.97 2,343.79 2_MWD+AX+Sag(3) 10,107.36 40.84 189.11 9,576.20 9,447.20 -2,376.48 250.99 2,542,157.84 263,609.19 5.66 2,380.71 2_MWD+AX+Sag(3) 10,168.40 41.05 186.37 9,622.31 9,493.31 -2,416.11 245.61 2,542,118.33 263,603.00 2.96 2,418.58 2_MWD+AX+Sag(3) 10,230.82 40.89 184.42 9,669.44 9,540.44 -2,456.85 241.76 2,542,077.68 263,598.33 2.06 2,457.84 2_MWD+AX+Sag(3) 10,293.88 42.17 182.39 9,716.65 9,587.65 -2,498.58 239.29 2,542,036.01 263,595.01 2.95 2,498.33 2_MWD+AX+Sag(3) 10,356.16 44.15 180.89 9,762.08 9,633.08 -2,541.16 238.08 2,541,993.46 263,592.93 3.58 2,539.90 2_MWD+AX+Sag(3) 10,414.69 44.94 179.67 9,803.79 9,674.79 -2,582.21 237.88 2,541,952.42 263,591.90 1.99 2,580.16 2_MWD+AX+Sag(3) 10,479.19 46.05 178.55 9,849.01 9,720.01 -2,628.21 238.60 2,541,906.42 263,591.69 2.12 2,625.45 2_MWD+AX+Sag(3) 10,541.30 46.91 177.71 9,891.77 9,762.77 -2,673.22 240.07 2,541,861.39 263,592.25 1.70 2,669.91 2_MWD+AX+Sag(3) 10,604.01 49.30 179.46 9,933.65 9,804.65 -2,719.88 241.21 2,541,814.72 263,592.44 4.34 2,715.93 2_MWD+AX+Sag(3) 10,665.51 52.25 178.46 9,972.54 9,843.54 -2,767.51 242.09 2,541,767.09 263,592.34 4.96 2,762.85 2_MWD+AX+Sag(3) 10,727.62 53.56 177.31 10,010.00 9,881.00 -2,817.01 243.92 2,541,717.56 263,593.17 2.57 2,811.80 2_MWD+AX+Sag(3) 10,785.36 54.02 173.19 10,044.12 9,915.12 -2,863.42 247.78 2,541,671.08 263,596.09 5.81 2,858.09 2_MWD+AX+Sag(3) 10,850.97 53.50 170.11 10,082.91 9,953.91 -2,915.77 255.46 2,541,618.59 263,602.70 3.87 2,910.94 2_MWD+AX+Sag(3) 10,912.48 54.49 170.01 10,119.07 9,990.07 -2,964.78 264.05 2,541,569.42 263,610.29 1.61 2,960.69 2_MWD+AX+Sag(3) 10,973.20 55.69 167.87 10,153.82 10,024.82 -3,013.64 273.60 2,541,520.37 263,618.85 3.50 3,010.48 2_MWD+AX+Sag(3) 11,034.45 56.66 164.52 10,187.92 10,058.92 -3,063.04 285.75 2,541,470.74 263,630.00 4.81 3,061.29 2_MWD+AX+Sag(3) 11,096.79 59.32 162.77 10,220.96 10,091.96 -3,113.75 300.65 2,541,419.74 263,643.86 4.89 3,113.91 2_MWD+AX+Sag(3) 11,118.67 59.95 162.50 10,232.02 10,103.02 -3,131.77 306.28 2,541,401.61 263,649.12 3.07 3,132.67 2_MWD+AX+Sag(3) 12/7/2017 1:19 26PM Page 5 COMPASS 5000.1 Build 810 • • Halliburton I Definitive Survey Report Company: a=HilcorpAlaska,LLC Local Co-ordinate Reference: Well GP-24-13RD2 Project: Granite Point TVD Reference: GP 24-13RD2 @ 129.00usft Site: ";,,,,,t'Granite Point Platform ' MD Reference: ;;;;;',..--1:,: "Y'",14'''., GP 24-13RD2 @ 129.00usft Well: GP-24-13RD2 f'North Reference: :: True Wellbore: GP 24-13RD2 Survey Calculation Method: Minimum Curvature Design: GP 24-13RD2 Database: Sperry EDM-NORTH US+CANADA Survey ", „ E a Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,181.51 61.22 161.39 10,262.89 10,133.89 -3,183.81 323.25 2,541,349.24 263,665.03 2.54 3,186.99 2_MWD+AX+Sag(3) 11,240.58 62.29 161.61 10,290.84 10,161.84 -3,233.16 339.76 2,541,299.57 263,680.53 1.84 3,238.58 2_MWD+AX+Sag(3) 11,302.09 63.80 161.92 10,318.72 10,189.72 -3,285.23 356.91 2,541,247.16 263,696.63 2.50 3,292.97 2_MWD+AX+Sag(3) 11,366.91 65.16 163.12 10,346.65 10,217.65 -3,341.02 374.48 2,541,191.02 263,713.06 2.68 3,351.09 2_MWD+AX+Sag(3) 11,426.15 66.59 163.20 10,370.86 10,241.86 -3,392.77 390.14 2,541,138.97 263,727.66 2.42 3,404.88 2_MWD+AX+Sag(3) 11,489.62 67.87 163.82 10,395.43 10,266.43 -3,448.88 406.75 2,541,082.53 263,743.13 2.21 3,463.13 2_MWD+AX+Sag(3) 11,553.53 67.73 164.41 10,419.57 10,290.57 -3,505.80 422.95 2,541,025.30 263,758.17 0.88 3,522.09 2_MWD+AX+Sag(3) 11,613.94 69.45 165.85 10,441.63 10,312.63 -3,560.15 437.38 2,540,970.67 263,771.49 3.61 3,578.20 2_MWD+AX+Sag(3) 11,673.85 71.29 168.19 10,461.75 10,332.75 -3,615.13 450.04 2,540,915.44 263,783.03 4.79 3,634.59 2_MWD+AX+Sag(3) 11,736.08 72.91 170.37 10,480.88 10,351.88 -3,673.31 461.05 2,540,857.05 263,792.86 4.23 3,693.80 2_MWD+AX+Sag(3) 11,801.39 74.68 172.65 10,499.11 10,370.11 -3,735.33 470.30 2,540,794.86 263,800.85 4.31 3,756.44 2_MWD+AX+Sag(3) 11,865.07 75.24 173.77 10,515.63 10,386.63 -3,796.40 477.57 2,540,733.66 263,806.88 1.91 3,817.77 2_MWD+AX+Sag(3) 11,922.49 74.62 175.18 10,530.56 10,401.56 -3,851.59 482.91 2,540,678.38 263,811.09 2.61 3,872.97 2_MWD+AX+Sag(3) 11,985.98 73.31 176.86 10,548.10 10,419.10 -3,912.45 487.15 2,540,617.44 263,814.09 3.27 3,933.52 2_MWD+AX+Sag(3) 12,049.87 73.50 180.00 10,566.35 10,437.35 -3,973.65 488.83 2,540,556.22 263,814.53 4.72 3,993.92 2_MWD+AX+Sag(3) 12,112.83 75.87 182.56 10,582.98 10,453.98 -4,034.35 487.46 2,540,495.57 263,811.93 5.44 4,053.24 2_MWD+AX+Sag(3) 12,171.50 78.10 185.34 10,596.20 10,467.20 -4,091.37 483.52 2,540,438.64 263,806.83 5.98 4,108.46 2_MWD+AX+Sag(3) 12,236.69 77.79 187.75 10,609.82 10,480.82 -4,154.70 476.25 2,540,375.48 263,798.28 3.65 4,169.24 2_MWD+AX+Sag(3) 12,299.46 78.41 190.13 10,622.76 10,493.76 -4,215.37 466.71 2,540,315.02 263,787.50 3.84 4,226.97 2_MWD+AX+Sag(3) 12,357.90 79.67 192.93 10,633.87 10,504.87 -4,271.58 455.24 2,540,259.05 263,774.90 5.17 4,279.96 2_MWD+AX+Sag(3) 12,390.80 79.86 194.06 10,639.72 10,510.72 -4,303.06 447.68 2,540,227.73 263,766.70 3.43 4,309.42 2_MWD+AX+Sag(3) 12,448.72 81.35 195.73 10,649.18 10,520.18 -4,358.28 433.00 2,540,172.83 263,750.89 3.84 4,360.82 2_MWD+AX+Sag(3) 12,508.69 82.59 190.91 10,657.56 10,528.56 -4,416.04 419.32 2,540,115.35 263,736.05 8.22 4,414.92 2_MWD+AX+Sag(3) 12,572.72 82.65 188.94 10,665.78 10,536.78 -4,478.59 408.38 2,540,053.04 263,723.84 3.05 4,474.23 2_MWD+AX+Sag(3) 12,635.36 81.97 186.32 10,674.17 10,545.17 -4,540.11 400.14 2,539,991.70 263,714.35 4.28 4,533.05 2_MWD+AX+Sag(3) 12,697.49 82.22 183.57 10,682.71 10,553.71 -4,601.42 394.83 2,539,930.52 263,707.80 4.40 4,592.21 2_MWD+AX+Sag(3) 12,756.41 83.47 182.21 10,690.05 10,561.05 -4,659.80 391.89 2,539,872.21 263,703.67 3.12 4,648.96 2_MWD+AX+Sag(3) 12,820.11 82.84 179.27 10,697.65 10,568.65 -4,723.03 391.07 2,539,809.01 263,701.57 4.69 4,710.88 2_MWD+AX+Sag(3) 12,886.30 81.02 177.11 10,706.94 10,577.94 -4,788.53 393.13 2,539,743.49 263,702.31 4.24 4,775.56 2_MWD+AX+Sag(3) 12,945.87 79.06 174.23 10,717.24 10,588.24 -4,847.02 397.56 2,539,684.92 263,705.54 5.79 4,833.83 2_MWD+AX+Sag(3) 13,008.71 80.98 175.17 10,728.13 10,599.13 -4,908.64 403.27 2,539,623.19 263,710.00 3.39 4,895.41 2_MWD+AX+Sag(3) 13,069.89 83.74 176.67 10,736.27 10,607.27 -4,969.12 407.59 2,539,562.65 263,713.08 5.12 4,955.59 2_MWD+AX+Sag(3) 13,130.01 86.58 178.57 10,741.34 10,612.34 -5,028.97 410.07 2,539,502.77 263,714.35 5.68 5,014.81 2_MWD+AX+Sag(3) 13,190.87 89.43 179.05 10,743.46 10,614.46 -5,089.77 411.33 2,539,441.95 263,714.38 4.75 5,074.74 2_MWD+AX+Sag(3) 13,255.56 92.20 179.29 10,742.54 10,613.54 -5,154.44 412.27 2,539,377.28 263,714.00 4.30 5,138.40 2_MWD+AX+Sag(3) 13,319.19 95.48 179.96 10,738.28 10,609.28 -5,217.92 412.69 2,539,313.81 263,713.13 5.26 5,200.79 2_MWD+AX+Sag(3) 13,383.83 98.21 179.92 10,730.57 10,601.57 -5,282.09 412.75 2,539,249.65 263,711.89 4.22 5,263.80 2_MWD+AX+Sag(3) 13,445.94 100.41 179.48 10,720.53 10,591.53 -5,343.38 413.07 2,539,188.37 263,710.97 3.61 5,324.02 2_MWD+AX+Sag(3) 13,461.18 100.32 179.23 10,717.78 10,588.78 -5,358.37 413.24 2,539,173.38 263,710.83 1.72 5,338.77 2_MWD+AX+Sag(3) 13,493.00 100.32 179.23 10,712.08 10,583.08 -5,389.67 413.66 2,539,142.08 263,710.62 0.00 5,369.58 PROJECTED to TD 12/7/2017 1:19:26PM Page 6 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-24-13RD2 Project: Granite Point ND Reference: GP 24-13RD2 @ 129.00usft Site: Granite Point Platform MD Reference: GP 24-13RD2 @ 129.00usft Well: GP-24-13RD2 North Reference: True Wellbore: GP 24-13RD2 ' Survey Calculation Method: Minimum Curvature 1 Design: GP 24-13RD2 Database: Sperry EDM-NORTH US+CANADA mitchell.laird@halliburton.com tgne°°'"""°""""` Michael Calkins ,z ,��. 12/7/2017 Checked By: zov.,z.o7,ozasa-o9'o0' Approved By: p,,,��,,,a„ Date: 12/7/2017 1:19:26PM Page 7 COMPASS 5000.1 Build 81D Hilcorp Energy Company • CASING&CEMENTING REPORT Lease&Well No. GPF GP 24-13RD2 Date Run 8-Dec-17 County State Alaska Supv. Brumley/Dorr CASING RECORD Liner V TD 13,493.00 Shoe Depth: 10,892.70 PBTD: No.Jts.Delivered No.Jts.Run 126 No.Jts.Returned Ftg.Delivered Ftg.Run 5,071.87 Ftg.Returned Length Measurements W/0 Threads Ftg.Cut Jt. Ftg.Balance ' RKB 52.65 RKB to BHF 59.65 RKB to CHF RKB to THF ��JL Casing(Or Liner)Detail Setting Depth Jts. Component Size Wt. Grade THD Make Length Bottom Top Reamer Shoe 7 3/4 DWC Davis Lynch 2.03 10,892.70 10,890.67 2 Liner 7 26.0 L-80 DWC VAM 81.99 10,890.67 10,808.68 Flaot Collar 7 5/8 DWC Davis Lynch 1.67 10,808.68 10,807.01 1 Liner 7 26.0 L-80 DWC VAM 41.00 10,807.01 10,766.01 Landing Collar 7 5/8 DWC Baker 3.79 10,766.01 10,762.22 123 Liner 7 26.0 L-80 DWC VAM 4,906.61 10,762.22 5,855.61 Liner Hanger 9 5/8 DWC Baker 9.45 5,855.61 5,846.16 ZXP Packer 9 5/8 DWC Baker 25.33 5,846.16 5,820.83 Seal Assembly 7 DWC Baker 2.00 5,820.83 5,818.83 Csg Wt.On Hook: Type Float Collar: Davis Lynch No.Hrs to Run: 41 Csg Wt.On Slips: Type of Shoe: Davis Lynch Casing Crew: Weatherford Rotate Csg Yes X No Recip Csg Yes X No Ft.Min. 9.6 PPG Fluid Description: Environmul OBM Liner hanger Info(Make/Model): Baker Flex Lock Liner top Packer?: X Yes No Liner hanger test pressure: Floats Held Yes No Centralizer Placement: 1 spiral glide centralizer per jt from jt#5 to#100. CEMENTING REPORT Shoe @ 10504 FC @ Top of Liner 5821 Preflush(Spacer) Type: Mud Push Density(ppg) 12 Volume pumped(BBLs) 20 Lead Slurry Type: Easy Blok Sacks: 241 Yield: 1.36 Density(ppg) 15.3 Volume pumped(BBLs) 56.5 Mixing/Pumping Rate(bpm): 5 Tail Slurry Le Type: Sacks: Yield: F Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): N Post Flush(Spacer) 1— re Type: Density(ppg) Rate(bpm): Volume: LL Displacement: Type: Environmul OBM Density(ppg) 9.6 Rate(bpm): 5 Volume(actual/calculated): 134.5/136.5 FCP(psi): 600 Pump used for disp: Rig Bump Plug? Yes X No Bump press Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: 0 Cement In Place At: 11:15 Date: 12/11/2017 Estimated TOC: 8,930 Method Used To Determine TOC: CBL Post Job Calculations: Calculated Cmt Vol @ 0%excess: 55.5 Total Volume cmt Pumped: 58.6 Cmt returned to surface: 0 Calculated cement left in wellbore: 56.5 OH volume Calculated: 55.5 OH volume actual: Actual%Washout: www.wellez.net WellEz Information Management LLC ver_102716bf Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. GPF GP 24-13RD2 Date Run 14-Dec-17 County State Alaska Supv. R Brumley/R Pederson CASING RECORD Liner#2 ♦I TD 13,493.00 Shoe Depth: 13,023.00 PBTD: 12,893.53 No.Jts.Delivered 68 No.Jts.Run 56 No.Jts.Returned 12 Ftg.Delivered Ftg.Run Ftg.Returned Length Measurements W/O Threads Ftg.Cut Jt. Ftg.Balance RKB 52.65 RKB to BHF 59.65 RKB to CHF RKB to THF Casing(Or Liner)Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top Reamer Shoe 5 3/4 DWC Weatherford 2.23 13,023.00 13,020.77 Liner 5 15.0 L-80 DWC TKC Convertible 83.08 13,020.77 12,937.69 Float Collar 5 1/2 DWC Weatherford 1.33 12,937.69 12,936.36 Liner 5 15.0 L-80 DWC TKC Convertible 41.78 12,936.36 12,894.58 Landing Collar 5 1/2 BTC Baker 1.05 12,894.58 12,893.53 Liner 5 15.0 L-80 BTC TKC Convertible 2,409.62 12,893.53 10,483.91 LTP 6 5/8 BTC Baker 34.90 10,483.91 10,449.01 Csg Wt.On Hook: 164,000 Type Float Collar: Model#402E No.Hrs to Run: 20.5 Csg Wt.On Slips: Type of Shoe: Weatherford Reamer Casing Crew: Weatherford Rotate Csg X Yes No Recip Csg X Yes No 12 Ft.Min. 9.6 PPG Fluid Description: Enviromul OBM Liner hanger Info(Make/Model): 5"x 7"Baker Flex Lock Liner Hanger Liner top Packer?: X Yes _No Liner hanger test pressure: Floats Held X Yes_ No Centralizer Placement: No centralizers CEMENTING REPORT Shoe @ 13023 FC @ 12,889.00 Top of Liner 10449 Preflush(Spacer) Type: Mud Push II Density(ppg) 12 Volume pumped(BBLs) 19.3 Lead Slurry Type: Class"G"Easy Blok Sacks: 392 Yield: 1.36 Density(ppg) 15.3 Volume pumped(BBLs) 95 Mixing/Pumping Rate(bpm): 5 Tail Slurry w Type: Sacks: Yield: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): f- Post Flush(Spacer) co Type: Density(ppg) Rate(bpm): Volume: LT Displacement: Type: Enviromul OBM Density(ppg) 9.6 Rate(bpm): 5.5 Volume(actual/calculated): 183/186 FCP(psi): 900 Pump used for disp: Rig Bump Plug? X Yes No Bump press 1442 Casing Rotated? X Yes No Reciprocated? X Yes No %Returns during job 99 Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: 0 Cement In Place At: 20:16 Date: 12/15/2017 Estimated TOC: 11,065 Method Used To Determine TOC: CBL Post Job Calculations: Calculated Cmt Vol @ 0%excess: 98 Total Volume cmt Pumped: 95 Cmt returned to surface: 0 Calculated cement left in wellbore: 92.5 OH volume Calculated: 98 OH volume actual: 98 Actual%Washout: www.wellez.net WellEz Information Management LLC ver_102716bf • • 2171 3 Debra Oudean Hilcorp Alaska, LLC 9 7 I3 .11 GeoTech II 3800 Centerpoint Drive, Suite 100 RECEIVED Anchorage,Tele: 777-833703 Atamka.LTA. Fax: 907 777-8510 JAN 18 2018 E-mail: doudean@hilcorp.com DATA LOGGED AO/2011 M K.BENDER DATE 01/17/2018 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 DATA TRANSMITTAL GP 11-24RD(217-143) Prints: GR/CBL CD: CBL Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: //// Date: • • 21 7143 Debra Oudean Hilcorp Alaska, LLC L 8 9 4 5 GeoTech II 3800 Centerpoint Drive, Suite 100 RECEIVEDAnchorage, AK 99503 2 8 9 4 6 Tele: 907 777-8337 F(Jrnrp Ui,ka.t.t.c Fax: 907 777-8510 DATA LOGO-D JAN 16 20t8 E-mail: doudean@hilcorp.com t iL5�2o vi K. BENDE', DATE 01/16/2018 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 DATA TRANSMITTAL GP 24-13RD2 217-143 PRINTS ROP DGR ADR CTN ALD ABG MD ALD DGR ADR CTN ABG TVD Final Well Data _Log Viewers 1/9/2018 4:08 PM File folder CGM 1/9/2018 4:08 PM File folder Definitive Survey 1/11/2018 9:06 AM File folder EMF 1/9/2018 4:07 PM File folder LAS 1/9/2018 4:08 PM File folder PDF 1/11/2018 9:06 AM File folder TIFF 1/11/2018 9:06 AM File folder PRINTS; Formation Log MD / TVD LWD Combo Log MD / TVD Gas Ratio Log MD / TVD Drilling Dynamics Log MD / TVD Final Well Report CD: Final Mudlog Data Daily Reports 12/20/20171:05 PM File folder DML Data 12/20/20171:05 PM File folder Final Well Report 12/20/2017 1:05 PM File folder LAS Data 12/20/2017 12:57... File folder Log PDFs 12/20/2017 12:59... File folder Log TIFFs 12/20/201711 PM File folder Sample Photography 12/20/20171:05 PM File folder Show Reports 12/20/20171:05 PM File folder Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Receive B�A:� 6.z..eat Date: 0 i II Debra Oudean Hilcorp Alaska, LLC GeoTech II 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 HiInirp,ihawka,T.TL Fax: 907 777-8510 E-mail: doudean@hilcorp.com Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 (./7Received By: 1;4,2 t.,7 Date: • IT- 143 DebraDebra Oudean Hilcorp Alaska, LLC GeoTech II 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 Hilrnrp:tl:eAa.i,t.t: Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 01/15/2018 To: Alaska Oil & Gas Conservation Commission Meredith Guhl, Petroleum Geology Assistant 333 W. 7th Ave. Ste#100 RECEIVED 1..•® Anchorage, AK 99501 DATA TRANSMITTAL JAN 16 2018 GP 24-13RD2 (217-143) AOGCC Transmitted herewith are cuttings WELL BOX # SAMPLE INTERVAL GP 24-13RD2 1 OF 3 8130'-9870' GP 24-13RD2 2 OF 3 9870'-12030' GP 24-13RD2 3 OF 3 10230'-13493' 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 Rece ved By• Date: '(� —Q C • tioF 7w, �w\��j��s THE STATE Alaska Oil and Gas A ofL ®® SKA Conservation Commission its 7:- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 'r) Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt. St. 24-13RD2 Permit to Drill Number: 217-143 Sundry Number: 317-589 Dear Mr. Myers: 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, Hollis S. French Chair DATED this 1 S day of December, 2017. RBD't1iS IA- GEC 1 5 2017 RECEIVED DEC 132017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AOC 't, APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing p Change Approved Program Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing r l Other: 0 2.Operator Name: 4.Current Well Class: '5. i ,lit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q' 217-143 ' 3.Address: Stratigraphic 0 Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 50-733-20080-02 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 76.35'7 Granite Pt St 24-13RD2 Will planned perforations require a spacing exception? Yes 2I No 0 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL 018761 Granite Point Field/Middle Kenai Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,493' 10,712' 13,493' 10,712' 2838 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 592' 18" 592' 591' NA NA Surface 3960' 13-3/8" 3960' 3841' NA NA Intermediate Production 9260' 9-5/8" 9260' 8962' 6870psi 4750pSi Liner 5072' 7" 10,893' 10,108' 7240psi 5410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,500'-10,504' 9,863'-9,866' N/A N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD(ft)and TVD(ft): N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑✓ ' Service 0 14. Estimated Date for 15.Well Status after proposed work: 12/10/2017 Commencing Operations: OIL ❑r • WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: 12/10/2017 GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: Guy Schwartz 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. Authorized Name: Monty M Myers Contact Name: Monty M Myers Authorized Title: Drilling Engineer Contact Email: mmyers .hilcorp.com Contact Phone: 907.538.1168 Authorized Signature: Date: 12.11.2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a represe�£atiae may witness Sundry Number: - .317 _. 5iq Plug Integrity 0 t BOP Test RV Mechanical Integrity Test ❑ Location Clearance 0 7f Other: 35co /0s.. gee %e5 f �, C re- 44.4-,...t RE 3 L k- L �, . 5 20;7 Post Initial Injection MIT Req'd? Yes ❑ No 6,-,,,,f k/ ai(7,4)Spacing Exception Required? Yes 1=1No Subsequent Form Required: I Q — 0 7 ( I C( �J APPROVED BY Approved by: COMMIS/g�/�p�J�N�^yg\ GH ALSION Date: 1Z- �� 6C\4\ I� /oz//41)I� yL/�7�, �+ • • I /Z/y-/� Submit Form and ) 1F Forh 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate <^ • • 11 GP 24-13RD2 Our iob is to set hands up for success with pre planning and sound equipment. 7"Liner Top = 5820.8' 7"Shoe = 10,892.7' Plan Forward: 1. R/U Pollard a. Bridge plug 10,550 b. -5' perfs -10,500' c. Cement retainer H0,475 2. R/D Pollard 3. M/U cement stinger assembly & RIH to retainer a. Establish parameters prior to sting in 4. Sting into retainer & establish circulation a. Might need to space out for cementing 5. Circ & cond mud for cement job 6. Pump cement as per SLB (est. TOC -200' above TOW) 7. POOH & L/D stinger assembly 8. M/U Baker dog sub BHA& RIH to TOL 9. Set packer as per Baker rep & test same 10.POOH & L/D dog sub BHA 11.M/U 6 1/8" clean out BHA 12.RIH, drill out shoe track & clean out to 13,000' a. Need to P/U more DP 13.Run 5" liner as per tally �;' • i Granite Point Unit II Wellbore Sketch (Current) GP 24-13RD2 PTD: 217-143 API: 50-733-20080-02-00 lid—.p Alaska,LLC R 1 ' 0, 7"Liner Hanger @ 5,821'MD t ' 9-5/8" TOW—8,130'MD , BOW-8,147'MD .., r,+ r ;; Cmt Retainer—10,475'MD j3EIVEC ,4:4/i ::_,. Perfs 10,500'—10,504'MD ISWAill Bridge Plug—10,550'MD rk Landing Collar—10,759'MD 7"Shoe @ 10,893'MD 8-1/2" Hole TD=13,493'/TVD=10,712' Updated by OD 12-13-17 • • Granite Point Unit Wellbore Sketch ( Proposed) GP 24-13RD2 PTD: 217-143 API: 50-733-20080-02-00 Hilcarp Alaska,LLC 7"Liner Hanger @ 5,821'MD a 9-5/8" • TOW—8,130'MD BOW-8,147'MD r. CV 5"LTP @ 10,400'MD Perfs 10,500'—10,504'MD F/7"Squeeze Job p�r k 7"268,L-80 DWC/C 10,893'MD M , :ire is n3•� a it 11: 5"188,L-80 BTC^'13,010'MD 8-1/2" Hole TD=13,493'/TVD=10,712' Updated by CJD 12-13-17 GWraell:niteGranite Point PlatformPtSt2 Last ComplerFut : 413RD2 PROPOSED PTD: 217-14 API: 50-733-20080-02 Hilcorn Alaska,LLC RKB to Tubing Head 38' Casing Detail: i SIZE WT GRADE CONN ID TOP BTM. +4 x Lias v 26" Conductor 26 ", 18" 70.59 B Ventura Surf 592' 18 A: 1 13-3/8" 61.0 J-55 Butt.LT&C 12.515 Surf 3,960' 9-5/8" 40&43.5 N-80&S-95 Butt.LT&C 8.755 Surf 8,130' TOW DV Collar ' 0 # E l; c (TOW) ) (V 2198 Vc.r 7" 26 L-80 DWC/C 6.184" Surf ±5,821' it 7" 26 L-80 DWC/C 6.184" 5,821' 10,893' 13-3/8" -� ry BTC(KC Casing Leak / ,-(� 5"15 L-80 convertible) 4.408" ±10,400' ±13,010' 1550 c✓/ Tubing Detail: li 2 L. 2-7/8" 6.5 L-80 8rnd EUE 2.441" Surf ±10,380' I 8 ® (,.I(" '1^1 `� U ' 2-3/8" 4.7 L-80 8rnd EUE 1.995" ±10,380' ±11,450' Tr1 JEWELRY DETAIL No Depth Depth ID OD Item (MD) (ND) 38' 38' Tubing Hanger 1 1 ±350' ±350' 2.313" 4.91" SSSV roc@ 7,970' ±2,546' ±2,500' 2.441" 4.75" GLM#1 ,,II ±4,544' ±4,400' 2.441" 4.75" GLM#2 to ±6,045' ±5,850' 2.441" 4.75" GLM#3 ±7,116' ±6,900' 2.441" 4.75" GLM#4 roc@ ", 2 ±7,899' ±7,650' 2.441" 4.75" GLM#5 x,xxx` ±8,527' ±8,250' 2.441" 4.75" GLM#6 9-5/8^ `' e it ±9,100' ±8,750' 2.441" 4.75" GLM#7 ±9,705' ±9,250' 2.441" 4.75" GLM#7 ±10,340' ±9,750' 2.441" 4.75" GLM#9 s ,.tor. 3 ±10,380' ±9,779' 1.995" 3.700" 2-7/8"x 2-3/8"Crossover to 4 ±11,360' ±10,344' 1.995" 3.330" GLM#10 n 5 ±11,400' ±10,360' 1.925" Packer a 6 ±11,440' ±10,376' 1.875" 2.730" X Nipple 0. 7 ±11,450' ±10,380' WLEG as i, 3 2 SqueezePerfs PERFORATION DETAIL I 10,500`10,504 * ,, ik Top Btm Top Btm TOC @x,xxx' 7" a 4 Zone (MD) (MD) (TVD) (TVD) FT SPF Date Status Comment ;. C-7 ±11,550' ±12,810' ±10,418' ±10,696' ±1,260' 6 Future 1.1.1P.= 5 f 6 1. 7 C7 Sand ,r 5 i i rpt . y PBTD:±12,860' TD:13,493' Max Hole Angle"83.47'at 12,756'MD Updated By:DEM 12/12/171 )(\ (Dqk,(39-1 it 1I 1110 7 // ....... ill 5-a 21 11 IP:tt,' ,,,A414 7 'tatt6 t / ?,`8 ., - Si 0)1 )-° ._ , , :&7,, •,.-,7-, . q ' 1 ot,,, \,,,, ,A -- , i ( i . /44 i r , ,, ,. Re-tes,t,..,..„,, lb , Ptr'r 0 i 0 (-00 I ,: I , 1 / L I _____ L e'' •--N CA,'s-,,4) ‘0 I I eN 4f- 1 12, 7 _ e . t, ,..„...7 ,1 c) ,1,,,.e — \ • , 1 . i . \ . .1 q 7i Ho(c. — 13 qq3 • 1 pr r2:1: 21 7- 1113, G P 2‘11 1 3 kl?-2- 5 0 - / 33- zoo /) -07._ pco ?o 5e ok , I i nr5v 1 1 111i1 1 FEEVg ,....-- 1 . e .." ..t.: ..--".- . If /177, - E-- r 5 e . . , \ ' ,1 \ ! 7" 24 4:fr L80 )106lic ..-%.- 10 8 3 / 1 ) , ' \ e" ‘)<,.' !' • . , -,.., . , '< .\ i ,-, ' —. .... . * 5 " /B-4* L 90 1 "T-C- / 3 eDI 0 .1 0 eP L ,-> , /- / / :5 71 m Plan View-IPllan: Lookahead PlanlI (RIG�GGP-24-13RD2,!GP 24-13RD2) in ICJ tC I2 O °o°a°o ❑ l6� XS oz 1r ill Q q ,ir a ii ----f- - ' 1 ; -T 1 '- 11�� ■ I •13H 50 ------ i .. • ■� _ IiIIror® ■ ■r ■� � rrII1r ■ . Ell I ME Iiii r t,, wii 1 t:50 _ a`�5nom iin '. -r�rrrI .iaII elm rrIIl -lito IN= i errr9 ■fir T1I______IIIIIIM ll ■I e ■NM r mmo I . IONNMI IIIII ■r�II 1111 ■ z III= MIMI El I. rr �� al r iir IIr _: I_______ I z-. _ r1 i .4.: LIMIIIIIII Ca` 59if MMIIIIIIMEIVIIIIIIEII 1 NNW 111111111jhkgrill I lin, III illi111 r ■ --- �rrrrrlIM IF i -1390 -11.^5 -9:' : : - -- -.:5 0 :.:5 :_ - : ___ 11S 1350 1575 1800 Z7..3 '^50 :475 Cary Taylor—(C) Well Design Tech 2 Schwartz, Guy L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Monday, December 04, 2017 10:58 AM To: Schwartz, Guy L(DOA) Subject: PTD#217-143: Projected GP 24-13RD2 landing Guy, With our new surveys that are coming in, it looks like we will miss our 500' radius circle on GP 24-13RD2 I'll call you to discuss Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell:907.538.1168 From:Cary Taylor-(C) Sent: Monday, December 04, 2017 10:35 AM To:Corey Ramstad<cramstad@hilcorp.com>; Monty Myers<mmyers@hilcorp.com> Subject:Projected GP 24-13RD2 landing Corey, It does appear that we will land this outside our permitted 500' radius BHL target by about 100'. Let me know if there is anything I can do to help with sundry. 1 OF T •! •• I//7:.s THE STATE Alaska Oil and Gas of L /\ sKik Conservation Commission 333 West Seventh Avenue F GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASY' Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt. St. 24-13RD2 Permit to Drill Number: 217-143 Sundry Number: 317-533 Dear Mr. Golis: 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. Cathy P. Foerster Commissioner DATED this day of December, 2017. RBDMS U UEC 1 1 2017 • • • RECEIVED VoU I. 3 2017 STATE OF ALASKA OW !11ALASKA OIL AND GAS CONSERVATION COMMISSION OV► APPLICATION FOR SUNDRY APPROVALS C "? 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown El Suspend ❑ Perforate 0. Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. G/L Completion 0 7' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 . 217-143 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20080-02-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 76.35 ' Will planned perforations require a spacing exception? Yes 0 ✓ No ❑ Granite Pt St 24-13RD2 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018761 Granite Point Field/Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Totl9 Q�eptth MMD( Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): ± ±12,398(proposed) ±13,400(proposed) ±12,314(proposed) 2,082 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 592' 18" 592' 591' Surface 3,960' 13-3/8" 3,960' 3,842' 3,090 psi 1,540 psi Intermediate Production 8,130' 9-5/8" 8,130' 7,872' 5,750 psi 3,090 psi Liner ±5,548(proposed) 7" ±13,501 (proposed) ±12,398(proposed) 7,240 psi 5,410 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A M/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 12/11/2017 Commencing Operations: OIL 0 + 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. Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe@hilcorp.com Q Contact Phone: (907)283-1329 Authorized Signature: �C �L1ly Date: "' t3't7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. " -S33 Plug Integrity ❑ BOP Test U �+Mechl Integrity Test Cl Location Clearance Other: 3500p5.. t.'1 /4,jr RSDMMIS L C DEC 1 1 2017 r Post Initial Injection MIT Req'd? Yes ❑ No ❑ �/ 6.4_,..„.„-( , l) IAi C 7 - J Spacing Exception Required? Yes ❑ No Eel Subsequent Form Required: ((� / 0 7- /, ,vi l / APPROVED BY U Approved by' COMMISSIONER T E O MISSION Date: )'Z—I? ? . 9� ,ig -t ./� ORIGIN /2-//17 Submit Form and .,gym 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate } • S • Well Work Prognosis Date: 11/01/2017 Hilcorp Alaska,LLC Well Name: GRANITE PT ST#24-13rd2 API Number: 50-733-20080-02 (GP 24-13rd2) Current Status: New Sidetrack of SI Leg: Leg#3 Injector Estimated Start Date: December 11, 2017 Rig: Kuukpik 5 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 217-143 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Monty Myers (907)777-8431 (0) (907) 538-1168 (M) Current Bottom Hole Pressure: 3,100 psi @ 10,178'TVD 0.305 lbs/ft(5.86 ppg)based on offset producers Maximum Expected BHP: 3,100 psi @ 10,178'TVD 0.305 lbs/ft(5.86 ppg)based on offset producers Maximum Potential Surface Pressure:2,082 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary GP 24-13rd2 is a C-7 only producer that will be completed with Gas Lift. This new well was side tracked from the current GP 24-13rd a shut-in injector.This workover will run completion and perforate the new well. Last Casing Test: Casing and liner tested to 2,000 psi under PTD 217-143 Procedure: 1. ***Take over operations from the Drilling Sidetrack Program*** 2. Test BOP's every 14 days continued from last test date from PTD 217-143.Test to 250psi low/3,500psi high/ 2,500 psi annular.(Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 3. Completion fluid will be diesel. BOP's will be closed as needed to circulate the well. 4. Rig up E-Line and run gamma/ccl/cbl. POOH. ./ 5. 5. PU and RIH with TCP guns,Correlate on depth and perforate. 6. Circulate bottoms up and assure well is static, release underbalance packer,circulate again and ensure well i static. POOH PU and RIH with Gas Lift completion. 8. Set Packer/Pressure test completion: • Pressure up and set packer • Test tubing against plug in X nipple to 2500#and chart for 30 minutes. • Test IA to 2.000psi and chart for 30 minutes(This will pressure up tubing also). • Pull prong and plug in X-Nipple. 9. Set BPV. NU tree,test same. 10. Turn over to production. 11. Schedule SVS testing with AOGCC as per regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Proposed 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form Granite Point Platform , 13 e Well: Granite Pt St 24-13RD2 • Last Completed: Future PROPOSED PTD:217-143 API: 50-733-20080-02 Hilcorp Alaska,LL( RKB to Tubing Head 38' Casing Detail: SIZE WT GRADE CONN ID TOP BTM. 26" Conductor 26 18" 70.59 B Ventura - Surf 592' 1 13-3/8" 61.0 J-55 Butt.LT&C 12.515 Surf 3,960' 9-5/8" 40&43.5 N-80&5-95 Butt.LT&C 8.755 Surf 8,130'(TOW) 7" 26 L-80 DWC/C 6.184" ±7,900' ±13,010' 18" A d Tubing Detail: 2-7/8" 6.5 L-80 8rnd EUE 2.441" Surf ±11,450' 13-3/8" ..4 2 CD JEWELRY DETAIL No Depth Depth ID OD Item (MD) (TVD) 38' 38' Tubing Hanger 1 ±350' ±350' 2.313" 4.91" SSSV ±2,546' ±2,500' 2.441" 4.75" GLM#1 ±4,544' ±4,400' 2.441" 4.75" GLM#2 ±6,045' ±5,850' 2.441" 4.75" GLM#3 $ TOC@ ±7,116' ±6,900' 2.441" 4.75" GLM#4 7,970' . ±7,899' ±7,650' 2.441" 4.75" GLM#5 2 ±8,527' ±8,250' 2.441" 4.75" GLM#6 ±9,100' ±8,750' 2.441" 4.75" GLM#7 0 ±9,705' ±9,250' 2.441" 4.75" GLM#7 / 11, ±10,340' ±9,750' 2.441" 4.75" GLM#9 9.5/8•. 360' ±10,344' 2.441" 4.75" GLM#10 ,1,400' ±10,360' 3.000" 5.875" Packer—7"x 3-1/2"DLH Retrievable 26-32# 0 ±11,440' ±10,376' 2.313" 3.210" X Nipple ±11,450' ±10,380' 2.430" 3.700" WLEG CD CD PERFORATION DETAIL p Btm Top Btm MD) (MD) (TVD) (TVD) FT SPF Date Status Comment D Zone ( C-7 ±11,550' ±12,810' ±10,418' ±10,696' ±1,260' 6 Future 3 L X {4 L +5 7 Sand /`e PBTD:±12,860' TD:13,493' Max Hole Angle"83.47°at 12,756'MD Updated By:DEM 12/05/17 H . • Granite Point Platform Well: Granite Pt St 24-13RD2 . ui Last Completed: Future PROPOSED PTD:217-xxx API: 50-733-20080-XX Hilcorp Alaska,LLC RKB to Tubing Head 38' Casing Detail: SIZE WT GRADE CONN ID TOP BTM. 25j 26" Conductor 18" 70.59 B Ventura Surf 592' 13 3/8" 61.0 J 55 Butt.LT&C 12.515 Surf 3,960' 9-5/8" 40&43.5 N-80&S-95 Butt.LT&C 8.755 Surf ±8,153'(KOP) 7" 29 L-80 DWC/C 6.184" ±7,953' ±13,501' 18" Tubing Detail: 2-7/8" 6.5 L-80 8rnd EUE 2.441" Surf ±10,460' 13-3/8" WI "9 0 rrr JEWELRY DETAIL tlO t 0I No Depth(MD) (ND) ID Item 1 ±7,953' 6.059" SDD Baker Liner Hanger V. 2 ±8,153' ±7,894' - KOP 3 ±7,953'- 13,501' ±10,915' 6.276" 7" 26#L-80 DWC/C Fj 1. " [ FUTURE INJECTOR—Plan packer accordingly L la 9-5/8" 2 3 SI . fe f sK 4 :" ' CEMENT DETAIL TOC Depth TOC Depth No p p Volume Item (MD) (ND) ie 4 ±9,000' ±8,618' 130 bbls 15.3 ppg Class G cement w/Y2 bbl cemnet LCM 71.: »:t ' ,. ,84.- PBTD:13,400' TD:±13,501' MAX HOLE ANGLE_±75° .H . Granite Point Platform Well: Granite Pt St 24-13RD2 Last Completed: Future PROPOSED PTD:217-143 API: 50-733-20080-02 Hilcorp Alaska,LLC RKB to Tubing Head 38' Casing Detail: SIZE WT GRADE CONN ID TOP BTM. 26" Conductor 18" 70.59 B Ventura Surf 592' 1 13-3/8" 61.0 Butt.LT&C 12.515 Surf 3,960' 9-5/8" 40&43.5 N-80-1:-&58505-95 Butt.LT&C 8.755 Surf 8,130'(TOW) 7" 26 DWC/C 6.184" ±7,953' ±13,501' is , i1,, Tubing Detail: 2-7/8" 6.5 L-80 8rnd EUE 2.441" Surf ±10,940' 133/8 __ / 2 A JEWELRY DETAIL No Depth ID OD Item (MD38'AA�� Tubing Hanger 1 _ 0' it)± Q 13" 4.875" SSSV ±2,54 ±2,500' 4.500" GLM#1 ±4,440' ,300' 2. 00" GLM#2 i ±5,890' ±5, 2.441' r110" GLM#3 TOC @ A, ±6,912' ±6,700' .441" 4.500" GLM#4 7,970 2 ±7,638' ±7,400' 274N, 4.500" GLM#5 ±8,265' ±8,000' 2.441" "'�4, 110" GLM#6 ±8,849' ±8,500' 2.441" 4.500" GLM#7 ±9,488' ±9,000' 2.44 ' 4.500" GLM#7 �7_,...„ ±10,126' ±9,500' 2.,,1" 4.500" GLM#9 4�f ' ±10,860' ±10,054' .441" 4.500" GLM#10 g_g/8" i , 3 ±10,900' ±10,081' 3.000" 5.880" Packer—7"x 3-1/2' DLH Retrievable 26-32# 4 ±10,930' ±10,1'a' 2.313" 3.210" X Nipple 5 ±10,940' ±11 06' 2.430" 3.700" WLEG TOC @ x,xxx' '1, , z PERFORATION DETAIL Zone Top Btm Top Btm FT Date Status Comment .,� 4, (MD) (MD) (TVD) (TVD) C-7 ±11,059' ±13,359' ±10,178' ±10,878' ±2,300' Future ., w 3 S; .. 5 __ C7 Sand C SUP 7" illpasuggk PBTD:±13,400' TD:±13,501' .‘"*."1°4.4...„,..................,........basst.....04,4temillr MAX HOLE ANGLE=±75° Updated By:DEM 11/01/17 i • Granite Point GPP 24-13RD2-proposed 11/13/2017 Hiker?Ala.k.,LU.t: Granite Point Platform Tubing hanger,WG-TC-1A- GPP 24-13RD EN-CCL,11 X 3%EUE lift and 18 X 133/8 X 95/8 X 7 X27/8 susp,w/3TypeH BPV profile,2-''A cont SCSSV port, 6'/."extended neck BHTA,Bowen,3 1/8 5M FE X 3"Bowen HAMM 11111 Valve,Swab,CIW-FLS, Itlitit!!1: 4 C•' 3 1/8 5M FE,HWO,EE trim . vr�i rib. Valve,SSV,Wing,WKM-M, 31/85M,w/15"VWoper it i i OO r I. i :,,,,, / N _ • Valve,Master,CIW-FLS, +^^ 31/8 5M FE,HWO,EE trim 03,/,;VI It Valve,Master,CIW-FL, NM.. 3 1/8 5M FE,HWO,EE trim U 7t. (i It? "l.it 11- Adapter,Wood group- t ___----_-.__ t EN-6.25",11 10M FE x ��'y //.- 3 1/8 SM stdd top,w/2- 1/2"npt control line exits Tubing head,WG-TCM-BG, I®1 1 1I 13 5/8 5M API hub bottom X 11 10M top,w/ 2-1 13/16 10M SSO II MM SII ,.. 0 • • 0 fn1 ip Unihead,OCT type 2,13 5/8 5M API i Upper bowl section bad hub top X 13 3/8 BTC casing bottom, iJ w/2-2"LPO on lower section,2-2 1/16 SM SSO on upper section,IP L. internal lockpin assy . J ■ i ! } ' i A Starting head,OCT, l_ !,!aI-i••; 21 1/4 2M Hub x 24'/.1M Hub w/2-2"LPO, 2111 prepped f/18"EN hanger �� CO illM� err/ t s-i.a Conductor housing,OCT, Q , 0 24Y..1MHub X 24"Buttweld II ' ' II Ii II 18" 13 3/8" 9 5/8" 2 7/8" • ! Granite Point Platform 2017 BOP Stack(Kuukpik) 04/24/2017 Nilrorp AIuik•,TJA: Rig Floor 111 III 16" Pipe Ii■III'III'IIP • III Iiigill.ill Ili-ill !II Iii 3.74' Shaffer 13 5/8 5M Ili`Ill'tii Ill amm SIafer SL e 2 7/8-5.5 Variables 2.83' iE 135/85M •-�'=I Blind 2 1/16 5M manual= HCP valve 2 1116 5M manual and HCR valve ]] til _ 1.76 i11: 7 4 - i III Illi ti iii ,Ell��:;�ll? IL' Sha 411 135 85M 'Mr.." 144 _ 27/8-5.5 Variables 1 UU UU U1 Drill deck 13.70' Riser 13 5/8 5M FE X 13 5/8 5M API hub s • Choke Manifold Valves 2 To Shaker 3" Panic To Gasbuster L 3 1/8"_ L 2 1/16 ~O O 2 1/16" i8 )i frill iy I N 21 -E) 21/1 + 21/16" R 3 1/8' o� © ---4,,.... + ♦ N L _i_ =,pr = =T, 4111 2 1/16" 2 1/16" Manual Choke \, Automatic Choke 2 1/16" Inlet Pressure Sensor 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES BLUE = 2 1/16" 5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold 1 ka 1 . ,� 4� is. \\. 4 ,W-. .'4,--: - ..:*!",", ..,-„g=7,.. ' ', , 'a- am *10 C 2 r a 11, #9 Ay ,,,. t.........,,a. , `._ 2 fiti ...„134;11, 2 ::1- #1 #2 C:-1 Ph ..-- 4.se Kuukpik Drilling Rig 5 Choke Manifold • • E bQ CI G i'pi loi G of 1 i d'«i d'4)i.2 Na' 0• cil N Oi 0al a' 0ilV!lOIVip.° v!0!0l O r I I I 1 r T� .I 14I it I I _ ;:1I I;�I ji WI WI .� O q) OI I4,1 to 7,1;it O •O Q - Ial.di a.il I 4-0 LL O E '/ g W ;! i !71!W .21 d a i a1 O a w Vl l lglw QIo°10o. Q. IX— i •••1"..i oa.Qv I 21 eaI-I • , a - lol I wlr1°.I CI 2I �• c � ISI yl .I ofco I V dl pc!I N-1 UI 1co NI loloi I If LO I Da o• i—o•D4 � .+1 I I I i i Nr M N y I I I l y I I I N N N & • �!�! !iii 8 n tee!ri! I I I . Ill No : N: O "' a U o N — e w � ` ` ..-i rn T 0 .01 I.oI cI ISI.oI X191 O ° .1 WI NI.ali NI NI Ml NI (11 c 1 1 1 1 1 1 1 1 1 VA . O I q11412,111I 0.1:=1;. .1 1 O g N I._ i31015151(341661.41 WI } a O 1 0!p!u11:nI pJ pJinl oil el CI 1011' Y :.01010 01010101 w.O.U. N .0 CD �I�ihINl Ihih. lUldl O1,--1-,-.1,..,1_,1-......1-..-.1,_,Iwa -- O co O.- Nwl ..-,le.ele'+IMlrelevlMle�.l I ct [XI 1.4 al I I I I I I I I I O �� 0 �� 0.ol.*IcIleolvlv+lholNIcol ?.�1~I~I~I~I~I~I~I~I z ~_ O C4 O 'o Tr CD LE' Op .- gN 2 pM o L rL r L ID N iY ..fA O �g o, U gd' v CD Co L 0 Da Da d I I I I . l I ms' 3 0'0' 0. 0' 0' 0. 0 A X NI NI WI WI WI WI WI NI 241 t?' 81.61.6161818181.61.6! l 1 1 I j 1 I 1 1 N'W.W.W. N'W. N' W'W' a!w! ! !w!w!w!`!`waNN, -lel' oi"� "I� al "S ` a N 0,0.0.o.SI,alol0,0, 21vvj.vv,vv1,in,ijlin,1Oj11hl 01l'el.01;01;01 016161;01 ti..r..r•w•..1•.�....•.-I..e. e•elydevlevlcol e•dnlell rel (-) y I I I l l l l l l = r,I ry l('l a l yl l.o l e.l 001 by a % I I I i I I 1 1 I - 9 :.-0 Cr) `.00 .--1 G ..-1 N N H . a o U • • E ct tab ct o aril al c1 O wilt ai .— W, N. L. a g al. N. Y. 01 2'I 81 81 � I I I al I i I NI I I ql I 1 I 4..' N1 1;>1%I •.i di i d, o a ts cn II i.a•ia. �iii I D D +. a1I 11.71_1 al 4,1 1 C a UI 1—.17s1 s1 a acz.col d ✓ �0! wi 10Ir ✓+l !M1 •, Iel,j1 _I o, I c it I yI,I yl °I I cc;cn v1 I NI �1 UI�I i c SI I la)p'I I I i J 1111 1 { 1 NN ANY acu �o�.,�r1�a +�a�v+� • N Ei o ^4ININIrII a r11e�UN1 I I I 1% I I I VI N N `' ♦N d U a c 1.01111111 el tri 10-411171 rl 1 $ N • NdNdNV6161 vcI 1 I 1 I 61 I C J •N 21.9.121.9.1.9.1.21.21.21.21 R 3 - a. U101U101viv,Uivivj 0 $ LL v O i dl arl ..1 dl dl at dl 1 O •N L i01+,l0101.010I0i01di N 1yl4N. 0.. e. cfNlyiol a' a' a',..s. RS Iooloo101010o100101 olUl ,.1._c 1 .r,In,se,..„.101010101010101011-1 vion ,r, . I,eI.o1. . 1.o1,e1_ I=1 0I cz▪ i v 0) CO 6— N i"'...1.e�i'e l"I en i i i i C4 C4 b4 b4 I • I I i I I I i .',N, N,a e, i_1 1 U I'sg O V6—AL �Io1..11Nieylylwl.olr-laol O O U edI_i~I~1~I~1~1•~I~1~I CY) O I><1 ' 1 1 1 1 1 1 I I 1 N Nr cts SC M o L O� L r L �`•' a a) a, I. 41, a. a. Q N—g ZM d e U m 6— O U 0 CQ a I I 1 I aI aI (�� (0 7 X I° o a• a• ar a• aI 1 I 1 I 1 �� r ,,, arlarlarl0.' 61adwl „{ N1 ° 01,0!01,01,0!0!01,C1,0! a• I I 1 1 I I I I I N, d, N, 4, N,N.,:, N., ; NI Nl N1�NI NI N1N1N1N1, 01UIL)IC91i91i91L11t91VI GI a.! O.1 co, a4 OJ 04 � 0,1 i al olololgloiololol •; 0.0.0.0.0.0.0 0 0 i wiwlwiwiwlwlwiwiwl Olblbiblbl,ol,ol,°I bl In ~1~1i�l~1�"1�"1rz!i'�I .r,.•1..•1,—,a,ra.ra,ti.a. NIell ell NINIell Iell NINI bbQ U_ y I III 1 I I I I • • P4 C cts 6 .rI NI NI•al antra!r-l aol al O 1 1 1 1 1 1 1 1 1 bA CL i na • Cr) c g ^▪s-' N N a Q•, U • • E G I I I I o I I I 0,ylmilli• MI• yl �1 .. a7°. 81SioiAla ui0°1 1 I I WI I I I O 0 III. I I I I a,11 ' I I a1;.1 oI a,1 I L EI 1.1.1! will i ;� O Q -O coail. Ia1a1 a,1 0i i oa O ,1-. + o f !M Ix I a, •�•94.ad fr7� 0- w VIUI i wl a 10.01°'101 N r 7.,1, •I oto' y1..! I d qI Iwl-1 iI 01 I •••••1 I�I rl �I°ol i dl MINI UI ` I I co of III I I 1 m 4 m 2 '.' '+I I lei 0 1 1 ., I I I I d I I I +° oIo1.•.leiIi ..,I'l.ni N N N Y B .. N'N'N'0 N•N'N' N t1 I I 1 1Z 0 I 1 1 ' I I I I! tit IT: 7 m Qw o w G N '� U , ` 0 LO _ 9 fy .r N 17r- D4 `' kb— J II L __. I 2S q �I I I of l of I of I u a) d a .0 .1 WI NI dp�1 „1$1 N1 y1 c U, 0 -I°I°I'ip1-1=1 °Iol J a) UIUIUIUI IUIUIUI 1 c v) O J I•q1.ti yl yi Iv wl yl dl I O LL Y •N IUIV11IUIU101�I1 •� L L f'. 17,1707„0 ITnl 41NI.IYI U �C Alooloo.c o 6.00.6 a1V1 Ct wlo1g1o1o1oioiolai,,i Q, I.I.Iy'041. I. oniv1 CA Q n I.e'e•A=?I0I.�Ie•O= i Sl' wl '� 0) Co N .�iI NIMI•,.II NI N. ••••1 I .•--• ^^‹� hh^^ hh<I� I I I I I 1 I I I I ~I I I 1 1 1 I I I I Cpp ,gl,c'l,1l Nl�l ,Vl„�„I�I�I�i o B I 11 I 1 I 1 1 I 1 O l>" 0 It C 3 N d w 7. o 0 c.9 li'4 40 4 Na g co; 1C) o o! o�LI Q!a�p!a!d�dI - A m G!WI W O I! Ogi,j°I oI —_4_ sa 6101 I Io0 I MVI F. i i i i 1 i i 1 i `w�w•w•w•w• w�w•w•w• VI�113iCitliclicllill(li Q 0.4 a!o~0.0.0.C: d .1.1.1.1.1.1.1.11I o,o•o•o• o•o•o .1.1.1.1.1.1.1.1 I 0•IVD•1.0••X1�1,1s1,o•1.0• 1 t, ^'0^'0^'1'-0-l-"1-1-1-1 r1I N!N!N! -!N!N!N!N! ,,/ U IIIIIIIII I: c I1 I 1 1 1 I I 1 1 1 CV) N Li -'INimiviv'I'*INioi0ii a_ Iiiiiiiii r• e) s II d a •r-1 w 4 :1-1 o u • • Kuukpik 5 BOP Test Procedure iliteorp Alaska,LLC Attachment#1 Attachment #1 Hilcorp Alaska LLC. Rolling BOP Test Procedure: Kuukpik 5 — Oil/Gas Producers, Water/Gas Injectors Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile & lift threads were deemed good, but still unable to get good tests 1) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Guy Schwartz (AOGCC-guy.schwartz@alaska.gov ),Jim Regg (AOGCC-jim.regg@alaska.gov ) and Michael Quick (AOGCC—Michael.quick@alaska.gov) via email explaining the wellhead situation prior to performing the rolling test. If on Federal land contact BLM representative Amanda Eagle (aeagle@blm.com) and Mutasim Elganzoory (melganzoory@blm.com). AOGCC and BLM may elect to send an inspector to witness.As outlined and approved in the sundry, proceed as follows: 2) With stack out of the test path, test choke manifold per standard procedure 3) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) Kill and choke line valve will also be tested during this time. 4) During these tests the test chart needs to be set to 60 min instead of 12 hours so chart shows a better graph. Need to station hands in cellar going over all connections on the BOPS looking for the slightest leak. Also need a man looking down the hole to confirm that the BOPS are not leaking. Test# 1=Annular, HCR Choke, and HCR Kill. Test#2=Upper Pipe Rams, HCR Choke, and HCR Kill. Test#3=Upper Pipe Rams, Manual Choke, and Manual Kill. Test#4=Lower Pipe Rams. 5) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. 6) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) 7) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 8) Pull hanger to surface. (Making tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid and sweep off any oil cap that may be present. 9) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE as per Kuukpik's standard test procedure. Or POOH laying down all the tubing and use the normal test plug to finish the tests that were not completed as per regulatory approval. • • Kuukpik 5 BOP Test Procedure HiieorpAlaska.,,1,c Attachment#1 If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree and test. May have to tap out if scaled up or paraffined up if well is not dead may have to be done w/ pressure lubricator (diesel or acid could help) 2) If unsuccessful, or BPV profile is eroded and well is dead. Best practice is to have two barriers a. Fluid column b. Set wire line plug or tag fluid level with slick line to establish static fluid level or shoot fluid level with an echo meter gun. 3) Shoot off tubing very shallow ( 300-500' most likely just under SSSV if applicable) 4) Spear hanger w/ upside down cup provided by fishing company 5) Proceed to get best test we can achieve against cup and confirm no visual leaks on all flanges of BOPE 6) Notify Hilcorp Anchorage Operations Engineer and AOGCC of situation 7) Pull hanger and cut off stub 8) P/U test plug and set same. 9) Perform complete BOPE test as per Kuukpik's standard procedure 0 . ,. _ . . , . . /� C2 7 a o T co c 2E CDo § / / 2 k� § / « � E ® § � ) f ( 10 01'.-- :-. » LN-- k / / _0 < � t' > _ < O --co R 2 0 Tr E'S I4. C / N CO. - n ■ ■ 0 I- 2 a 2 c 2 ta # a. $ c % �. N /f re @ce 0 � B 4N 0 / C @ 0 § 0 kc a e § ca ' coC k MI R e _ .ccU Q \ -00 0 J f9 0 CD � Eb ° o O k 0 . a L C.) = / 0 a \ / 15 »It? § - c = / . V $ p U) LU cod .t3 ■ D § U)§ Cl) w ■ CU0 p Q. 0. � 0cz ccL. « � > 0 a 2 � � E 2 a Q ■ q R & e \ 0 � 0- u) Q 2 c © 2 0 � w / � Q .. V a E0 > ko o 0_ CO c \ 9 C < a_ i i Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Tuesday, December 05, 2017 12:30 PM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett; Michael Quick; Stan Golis Subject: RE:GP 24-13rd2 PTD217-143 Attachments: ' 10-403 GP 24-13RD2 -2017-11-13 Submitted.pdf;GP 24-13RD2 Proposed 2017-12-05.docx Follow Up Flag: Follow up Flag Status: Flagged With proposed attached this time! From: Dan Marlowe Sent:Tuesday, December 05, 2017 12:18 PM To:Schwartz,Guy(guy.schwartz@alaska.gov)<guy.schwartz@alaska.gov> Cc:Juanita Lovett<jlovett@hilcorp.com>; Michael Quick(mquick@hilcorp.com)<mquick@hilcorp.com>;Stan Golis <sgolis@hilcorp.com> Subject:GP 24-13rd2 PTD217-143 Guy We called TD yesterday on GP 24-13rd2 at 13,493. Attached is the revised proposed schematic with final perf selections, please note that we encountered the aquifer earlier than expected so won't be running casing all the way to TD. We are currently at the window testing BOP test,then will finish POOH lay down the drilling BHA and RIH for a cleanout prior to running casing. We anticipate swapping to our completion sundry(attached)on December 12th when we will be ready to run the cased hole logs and pick up TCP guns As always let me know if you have any questions Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Email DMarlowe(c�hilcorp.com Hilcorp A Company Built on Energy 1 C.17.1, P¢ z f>T6 ` (71430 Regg, James B (DOA) From: Rick Brumley - (C) <rbrumley@hilcorp.com> —, 14'/4/7 Sent: Wednesday, December 6, 2017 9:51 AM To: Regg,James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe (DOA) Cc: Monty Myers; Michael Quick;Adam Dorr- (C); Marvin Rogers - (C) Subject: Kuukpik 5 12-6-17 Attachments: Kuukpik 5 12-6-17.xlsx; Kuukpik 5 12-6-17 Chart.JPG; Kuukpik 5 12-6-17 Test Sheet.pdf Attached are the BOP test form, test chart and Hilcorp BOP test sheet. Rick Brumley Hilcorp DSM Granite Point Platform 776-6658 Office 232-5709 Cell • 1 • 0 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report *AII BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regqaalaska.gov:AOGCC.Inspectors analaska.gov; phoebe.brooksna.alaska.gov Contractor: Kuukpik Rig No.: 5 - DATE: 12/6/17 Rig Rep.: L Wares/J Twigg Rig Phone: 907-776-6914 Operator: Hilcorp AK, LLC Op. Phone: 907-776-6658 Rep.: R Brumley/A Dorr E-Mail rbrumley@hilcorp.com Well Name: GP 24-13RD2 - PTD# 2171430 " Sundry# Operation: Drilling: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly: X Test Pressure(psi): Rams: 250/3500 -- Annular: 250/2500 Valves: 250/3500 - MASP: 2838 - MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P - Well Sign P - Upper Kelly 1 P • Housekeeping P • Rig P - Lower Kelly 1 P 1 PTD On Location P Hazard Sec. P - Ball Type 1 P Standing Order Posted P Misc. NA Inside BOP 1 P • FSV Misc 0 NA • BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P . P Annular Preventer 1 13 5/8"Annular . P - Pit Level Indicators P - P #1 Rams 1 2 7/8"x 5"VBR P - Flow Indicator P - P #2 Rams 1 13 5/8"Blind ' P - Meth Gas Detector P - P #3 Rams 1 7" - P ' H2S Gas Detector P - P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 3 1/16" . P . Inside Reel valves 0 NA HCR Valves 1 3 1/16" . P . Kill Line Valves 3 2 1/16" - P . Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 3000 - P CHOKE MANIFOLD: Pressure After Closure(psi) 1600 - P Quantity Test Result 200 psi Attained(sec) 24 - P No.Valves 16 P - Full Pressure Attained(sec) 116 - P Manual Chokes 1 P - Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P - Nitgn. Bottles#&psi(Avg.): 4 @ 2500 - P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 10.0 Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Tested with 4 1/2", 2 7/8"and 7"test joint at 250 low and 3500 high for 5 minutes each. 250/2500 on annular. Rig Electrician tested gas detection equipment. Function tested flow alarm and PVT's. AOGCC Inspection 24 hr Notice Yes - Date/Time 12/3/17 06:27 .--- Waived By Jim Regg `-e Test Start Date/Time: 12/5/2017 17:00:00 PM (date) (time) . Witness Test Finish Date/Time: 12/6/2017 3:00 Form 10-424(Revised 03/2017) Kuukpik 5 12-6-17 • • / ,.'"' 0 ; J -- , -;'----- 4.\%*‘' N . 1 02 1 0 1 / -.N. A6‘. f , - w' / # ' ' 4irmi �4-41„,4744111 \ ,' ' �V y. .- \ - ii ir.,, , % . ,0, si, - _0.1 ir 141,, % A 0\ / , /I "A ' ... 0000001 '' ' j ' 0,40vev#,0 .11......., OA. t...7).4. \" \ , /tat*/ � 9: #IIj..gs♦ au l i , i 1111,111* f,, ��j ��, I..0.i111g`wl* ►�• � a 4 , , inpum 1 1 IL t1 II Him Fie fle4 _. ►� lifta ;-;.-iiii Ni 1�11 n:-11- , , , 1_, IN a u� IV ariat147 ill NI Op T .s....,-, Y-r,°° ** ./1,1 iii ily i I I 1 \\\1 0Wit�� sitikrurs S► ,,� . by ibb 4 ! . , �� - I /lb ilb 4 .�,�.,..iii �I,�4,.... -A,i,�ij l /liphi, " ,1111 \ �� .a4q i r .• t V �� ri; , i 0 r HILCORP BOP TEST SHEET -� DATE: 6-Dec-17 RIG CONTRACTOR: Kuukpik RIG# 5 TIME: WELL NAME: GP-24-13RD TYPE OF OPERATION - (DRILLING /WORKOVER/OTHER): Drilling HILCORP REP: Brumley RIG SUPERVISOR: Jeff Twigg SUPERINTENDENT: Scott Heim TESTING COMPANY: Kuukpik DP SIZES: 4.5 BOP SIZE& RATING: 13 5/8 5K Minutes Held Pass/ Test# e.i.s-'`T' 'sfi Aomponents Tested (Low/High) Low PSI High PSI Fail 1 A1irl}, /,OA2-r, )C// D Er cviffs•7 v-7,s'-I,/.c 1b C gSD gS- P 2 7--r'!2. i /T)r4,z r, I2 EI bilYie4 ,,n(/- )', /11, /S-)/6 5` 95`t,) ar°° 1 Li T?IR- , Ti v.) , Tis, bc. i#kc It l MAW J 2OP < -3S' P C?nn:v' --- ' ,ID, lea S- TPQ } T14 i I'r.,<as)c jt li CrnU- 2.)ell 1: S' ac 3S`L,v P (;p Ta ti-44.) , 'rte s bc: k /(, Colt,- 1,Cl, I Z_ 4— Zs-t) g. P Z5b 34-Do P < -rtP2 1'-i\/..)i -7-,,A, ox k,!f, ',vs,.t ( a S G2SO 3S"e.o a=' ct 131")0S 1 ,,,A s 1 ras kc 11 7 Gm v - I 1c4, iZ S"' S`v Z c) P 10 l l7. Choke PS-t" iso° P 11 ilAn Cd,,ice.. I c > ISyr t -Vr 776-$7- J - t Z Pr1.,N ,2'n4S/t7g Mc?$'e- i r-tr.,(+Pe l e,II 'S Z .0 Z S` ty 1> /3 L,P2 )--Nstor C"it r svSt kill 'J Z,s-r7 35`4)0 p /'-I AWN t . s r `,",r ssat edi S P Is_ ..++:4 i r*+.s's M1/ t. Accumulator Test Accumulator Manifold Annular Preventer Type Closing Time Initial Pressure -' ,,r14,20 IS60 )009 Shaffer 13 5/8" Final Pressure Re-charge Time Zuo 145,' 2.4 v,,,C,_ 1 IN e, 2S00 s Hilcorp Representative Signature: Rig Supervisor Signature: Contract Testing Representative Signature: • EXPLANTATION OF TESTS ON NEXT PAGE. ATTACH BOP ANMANIFOLD SCHEMATIC. I - ..,-11112,- HLLCORP BOP TEST NOTES 0 1,0,,,.? tip r 0ss,� Awriz V of T4� . a �w\��\��,s� THE STATE Alaska Oil and Gas ti '►1 � of® LAsKA Conservati®n Commissi®n trit =_= 333 West Seventh Avenue iiiiGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O .. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Paul Mazzolini Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 24-13RD2 Hilcorp Alaska, LLC Permit to Drill Number: 217-143 (revised) Surface Location: 2392' FNL, 1376' FWL, SEC. 13,T1ON, R12W, SM, AK Bottomhole Location: 2508' FNL, 1784' FWL, SEC. 24, T1ON, R12W, SM,AK Dear Mr. Mazzolini: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05,Title 20,Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, al / Cathy l. Foerster Commissioner DATED thisday of December, 2017. d K.14/A./'4'v STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMMVION PERMIT TO DRILL REVISED 20 AAC 25.005 1 a.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ 1 c.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑✓ Service- Winj ❑ Single Zone ❑., Coalbed Gas ❑ Gas Hydrates ❑ Redrill 0 Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑✓ Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 Granite Pt St 24-13RD2 3.Address: 6. Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 MD: 13,500' TVD: 10,713' Granite Point Field 4a. Location of Well(Governmental Section): 7.Property Designation: Middle Kenai Oil Pool Surface: 2392'FAL, 1376'Ffty ,L,Sec 13,T1ON, R12W,SM,AK ADL 018761 Top of Productive Horizon: 8.DNR Approval Number: 13.Approximate Spud Date: 125'FNL, 1645'FWL,Sec 24,T1ON,R12W,SM,AK N/A 11/8/2017(Actual Spud Date) Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2508'FNL, 1784'FWL,Sec 24,T1ON,R12W,SM,AK 5089 6,926'to nearest unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL(ft): 115' 15. Distance to Nearest Well Open Surface: x-263406 y- 2544538 Zone-4 GL/BF Elevation above MSL(ft): 0 to Same Pool: 50'from 11-24RD 16.Deviated wells: Kickoff depth: 8,140 feet 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 100 degrees Downhole: 5348 Surface: 2838 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) 8-1/2" 7" 26# L-80 DWC/C 5,548' 7,953' 7,702' 13,500' 10,713' 545 sx 15.3 ppg Class G 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): 10,640' 10,287' 8,781'TOC Plug 8,781' 8,503' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 592' 18" 650 sx 592' 591' Surface 3960' 13-3/8" 1850 sx 3960' 3841' Intermediate Production 9260' 9-5/8" 703 sx 9260' 8962' Liner 1586' 7" 400 sx 10640' 10287' Perforation Depth MD(ft): 9,505'-10,480' Perforation Depth TVD(ft): 9,196'-10,132' Hydraulic Fracture planned? Yes No 0 20. Attachments: Property Plat ❑ BOP Sketch — Drilling Program — Time v.Depth Plot Shallow Hazard Analysis— Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Monty Myers Authorized Name:Paul Mazzolini Contact Email: mmyerSt_C71 hiICOrp.COm Authorized Title: Drilling Manager Contact Phone: 777-8431 Authorized Signature: 7 /// Date: /2/n4.- r Commission Use Only Permit to Drill, API Number: Permit Approval I See cover letter for other Number: ". ii/3 50- 7-��'" . 00,S0 — 6,,/--a1 Date: i 1 MCI l`I requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane, as hydrates,or gas contained in shales: Other: Samples req'd: Yes ❑ No"VI Mud log req'd:Yes❑ No El H2S measures: Yes [ o❑ Directional svy req'd:Yes ENo❑ Spacing exception req'd: Yes I� No❑ Inclination-only svy req'd:Yes❑ No[r Post initial injection MIT req'd:Yes❑ No❑ Go ?(I .3s s c .D ij/c/j?-- agy ,I — APPROVED BY Approved by: O 't"" C//O��MMISSION/E'ER A THEACOMMISSION Date:/Z' �' / 7 D I 1 Z mSyb in Form and Form 10=40��vised 5/2917�� This��s v lid/Or 24 mont s rTL�`t a ei4", a Ill•�er 20 AAC 05(g) Attachm4ntyF in Duplicate . 1111 Hilcorp Alaska, LLC P.O. Box 244027 Monty Myers Anchorage, AK 99524-4027 Drilling Engineer Tel 907 777 8431 Email mmyers@hilcorp.com Hilcorp Energy Company 12/5/2017 RECEIVED DEC 0 5 2017 Commissioner AV�CC Alaska Oil & Gas Conservation Commission VV 333 W. 7th Avenue Anchorage, Alaska 99501 Re: GP 24-13RD2 Revised Dear Commissioner, Enclosed for your review is the revised application for permit to drill GP 24-13RD2. Due to directional drilling challenges we were unable to stay within our original permitted drilling radius. We have attached a new directional plan for your review. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 0 • \ GP-11_-_,13 BHLGP-31-13 BHL / • GRANITE_PT-1 •• • \ k ~BHL • 1\ \`\ Legend • \ \ ,GP-11-13RD N \\ \ -��HL GP 24-13RD2_SHL Other Surface Hole Location \\�� \� \ \/ \\ GP 24 13RD2TPH • Other Bottom Hole Location `_ GP-31-14RD1 1 \ \ (N '- GP-31-4vD7-.BHI L \\ \\ \\ I + GP 24-13RD2_BHL - Well Paths �,,,,,, BHL • \ t I • GP-22-Y3/BHL ——— -G7'r' 1;.,-:-`'l`\'..— GP24-13RD2 SHL ——— -- d/ GP-32-1 BHL //-- //S°p �\ en.• �� / / / `• � `• MONO1 n7 /'/' i' \ o ONO1 7 �, -'411-50A, GP-k3-13 V \ \ \ 41n \ \ 7156A, L/ I \ ac— `•\• �i� / /G9 0�HL I \ GP-33\3 BHC • •�'a / / /4 I \ • \ •__\ / / ii / I \ / ♦ \� GP-22-13RD3 / /i /� / I \ `\ \s,, B1 BHL / / /�/ • / 1 \ \� `�\\a / // // / I 1 •• • • \GP-22-13RD3 • / /// i/�I \\ -\ '.IRB2 BHL / ,' / 1 p ANF -- POINT . GP-44-14�S1�L- / / --. �� •�—% / I I •''!I " 'S \ 'S / / P-55 BHL/ I I `• GP 22-1'RD3 // ' / I II �' \`GiP-32-13RDPB �FI`•L \ /` /// // I ADL018761 `,�HL / / I SOIONO14 'I / /i // / I SGP-24-13 BHL / 1 / I I GP-24-13RD e� 0 9 3 /// // /// i I BHL / / iii / / / i o / •GP-11-24 BHL /,., 1 . / / / ` GP-�1-24PBr 1 e Z:"---t GP24-13RD2 TP11 / / I A GP-11-24RD / / / / k / I lo`. BHL / / I 10 / / / / I /� 0 `• " / // I 0 \ • / // I / 0 N / d / o `N / / 0 I // 0 N /' /° I / ° ./,, I/ o° If /I o `° o ONO1SJ ''S\ GP-11-24RD t t1ONO1TO SO1ONO1SW8 o ° ,/ / 0 /,l N B BHL ya q(el I 0 o GP-1224 BHL 1 ° • o I 00 1 g I 1 0 1 1 GP24-13RD2 BHL I I I 1 I I 0 500 1,000 1,500 II Granite Point Unit Feet N GP 24-13RD2 wp 18 Alaska State Plane Zone 4,NAD27 Hilcorp Alaska,LLC Map Date: 12/5/2017 • • Hilcorp Alaska, LLC Granite Point Granite Point Platform RIG: GP-24-13RD2 GP 24-13RD2 Plan: GP 24-13RD2 WP18 Standard Proposal Report 4 05 December, 2017 W HALLIBURTON Sperry Drilling Services • • il� HALLIBURTON WELL DETAILS:RIG:GP-24-13802 Water nim 7s.00 West(-)/East(+)(900 usft/in) Sperry,y D.;;;;,g +Nis -IE/-W Nom > Img Latitude Longitude 900 1800 2700 0.00 0.00 2544538.84 263406.53 60°57 29.201N 151°14 52.249W p0�pi I i 1 1 I i I , I Project: Granite Point REFERENCE INFORMATIONSite: Granite Point PlatfoL - Well: RIG: GP-24-13RD2rm Co-ordinate(N/E)Reference:Well RIG:GP-24-13RD2,True North C., - Wellbore: GP 24-13RD2 Vertical(TVD)Reference:GP 24-13RD2 @ 129.00usft O Measured Depth Reference:GP 24-13RD2 @ 129.00ustt 5p0 --9 p 0 Plan: GP 24-13RD2 WP18 Calculation Method:Minimum Curvature 55p0 GP-24-130D2 WPI5 Cool7 6el50 GP-24-13RD2 WPI5 Cl_8 - GP-24-13RD2 WP15 Coal,9-. 15°13 - GP-24-13RD2 WP15 Coal_10 :000 GP-24-13RD2 WP15 Caa111i' 8500 --1:00 GP-24-13RD2 WPI5 Coal 12 ,• 11O, LEGEND GP-24-13RD2 WP15 Coal 13- so' 9250 - -ARIG:GP-24-13RD2,GP-24-13,GP-24-13 VO GP-24 13RD2 WP Cuol 14 r 9�S0 �i -ly-__ $ RIG:GP-24-13RD2,GP-24-13RD,GP-24-13RD VO GP-24-I3RD2 WPI5 9750 d Cool_15 ,p' GP-24-13 - $ RIG:GP-24-13RD2,GP 24-13RD2,GP 24-13RD2 VO 0000 GP-24-13RD --2 00 2 -9 GP 24-13RD2 WP18s GP-24-13RD2 WP15 Coal_16\ I ,p250 GP 24-13RD2 WP15 C7 Sand Top i 24-13RD2 WP16 Nov20 CT Lookahead Tgt - +. 1' CO GP-24-13RD2 WP15 Coal9 85� -3x110 0 8500 ii 10500- N GP-24-13RD2 WP15 Coal_10 900 - _GP-24-13RD2 WP15 Coal 11\ .-. 8925-1 - GP-24-13RD2 P15 Coal_12 . 2,6C2132,6C213I W --4'00 uFri GP-24-13RD2 WP15 Coal_13 "r' 9350- - .. X00 n GP-24-13RD2\5P15 Coal_14 IS' p `j ie..'.1 o0 9775 1 ^a5 GP 24 13RD2 wp08 BHL _GP-24-13RD2 WP15 Coal_i r_____- . ^oo9 10713-,{0712 I,_--" --5400 10200— GP-24-13 ` 0500 ^ ^oo GP 24-13RD2 �‘GP 24-13RD2 F - - GP-24-13R•,-T6690 o - - h o 13493 - 10625— GP-24-13RD2 WP15 Coal_16/ M „ GP 24-13RD2 WP18 GP 24-13RD2 WP15 C7 Sand Top,f -- 24-13RD2 WP18 Nov20 CT Lookahead Tgt GP 24-13RM 1nIP1A t...I iliiiiliiiiliiiiliiiiliiiilirirliiiiliiiiliiiiliii ',Milli 1275 1700 2125 2550 2975 3400 3825 4250 4675 5100 8525 Vertical Section at 175.62°(850 usft/in) GP 24-13RD2 wp08 BHL • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well RIG:GP-24-13RD2 Company: Hilcorp Alaska,LLC TVD Reference: „,•, GP 24-13RD2 @ 129.00usft „:. ,, ,,,,,...,.. Project: Granite Point MD Reference: ' '7,7,•.-'.:„.:, -:.•-..,- GP 24-13RD2 @ 129.00usft Site: , •,, --,:„Granite Point Platform North Reference: ',i?.„, True Well: '21#54;;,• ., RIG:GP-24-13RD2 Survey Calculation Method: -:;i7-'Z:14 Minimum Curvature ..--,.=,--, •, -••• • '..-.ic,!i.: ,,,= Wellbore:itJ;i1 GP 24-13RD2 Design: GP 24-13RD2 WP18 -,•':.`43AztklitiS-1,A,41.4,36f42 ;:t.01- -,'.-. - ',A410.174MVOinVZAtifiraWan.„,StliM,,,,,,.27:'I'llii'f'.1''',tte,•41'?'i'l',•,1:tif-';'.'''''',..-iti.li,i5,3: :. >. -, .. ,.4, .,..., . tDmogor•bp,,,,,,,,s, Project Granite Point 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 Siteili.::.0,--f'-:,7i1",--.:. Granite Point Platform Site Position: Northing: 2,544,544.00 usft Latitude: 60°5729.251 N From: Map Easting: 263,401.00 usft Longitude: 151°19'52.363 W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.16° RIG:GP-24-13RD2,Leg3 SIot6 .uar.r,,tSg.g.....,. .".r....=. Well Position +N/-S 0.00 usft Northing: 2,544,538.84 usft Latitude: 60°57 29.201 N I +E/-W 0.00 usft Easting: 263,406.53 usft Longitude: 15V 19'52.249 W Position Uncertainty 0.00 usft Wellhead Elevation: 129.00 usft Water Depth: 75.00 usft Wellborel:-.::•7::•::: GP 24-13RD2 Magnetics Model Name Sample Date l' 4'-'7::?i1 :. ' '- P!.,'-'4tAi-i.!- Field Strength '11.:fet=•::::*lif: .*•(=,',0--,zies... -4-7.-..-- +7,1:',,r7i17+,-,, -- . 7 , .-7-,•.,...:1,-;--1",,L,Pt:o ' ',.-4:;,;;;. ,;77,..-2'7.)•':,i;::7=7.: ::(eUte,.::','.:=.7:+::-ii,x-1,1,•=..'=,,,--;••,:.7,-,•--:•.,rt,•,,,,, ;7,,,, _ -,-1(:`,'•'1,,t BGGM2017 10/2/2017 16.05 73.84 55,439 -....z..: y,..-,-...--„,,,.......,,,,,...,..,... Design -4,441,-,P GP 24-13RD2 WP18 Audit Notes: Version: Phase: PROTOTYPE Tie On Depth: 13,255.56 Vertical Section: ;7-' ..,.47,iklii`o.1, Depth From(TVDdliAlii:i.10:1 '.: Direction :-e1.1.??-;. :F3.%713: i:1•X•iiiiii-ii-4 7A-4,:qt 0.-irv,,:..:,-,,-----,rt.;Iiiv-yfra,1•-t-,,,,„Tot , () e4-....A-40-,-fti...,,,e---4: ',':-kt-',' ,..,-.41.-1 it-, 0.00 0.00 0.00 175.62 Plan Sections - 0--, , - ' -. /,- ,--- , -2--,-,-- ---.. -,-,...".,0:1,,v,;„ . -,4-,,,,,A,-i:•,+'• --,-'-'-','''',', 7 7 '' •P"' ''''''''''7"''=ii-'7,•::C'"7 ''''''-'131r"'-'''--w't'"c7 Measured Vertical TVD liti dilr •,,A-.!•ige '4,-- Dogleg Li, Build *.',,,,,: Turn , Depth Inclination Azimuth Depth System +NI-S +E/-W Rate Rate Rate Tool Face (usft) () (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) () 13,255.56 92.20 179.29 10,742.54 10,613.54 -5,154.44 412.27 0.00 0.00 0.00 0.00 13,451.36 100.00 180.00 10,721.75 10,592.75 -5,348.97 413.48 400 3.98 0.36 5.14 13,500.00 100.00 180.00 10,713.30 10,584.30 -5,396.88 413.48 0.00 0.00 0.00 0.00 12/5/2017 1:04:42PM Page 2 COMPASS 5000.1 Build 81D 0 • Halliburton I-IALLIBURTO.J Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well RIG:GP-24-13RD2 Company: Hilcorp Alaska,LLC TVD Reference: GP 24-13RD2 @ 129.00usft Project: Granite Point MD Reference: GP 24-13RD2 @ 129.00usft Site: 'Granite Point Platform North Reference: True Well ,RIG:GP-24-13RD2 Survey Calculation Method: Minimum Curvature Wellbore-. GP 24-13RD2 : `A Design. GP 24-13RD2 WP18 " e » it . - .:,, maJ Planned Survey Measured ` .. .„-w -. . 'f Vertical '' ` Max; Map Depth Inclination Azimuth Depth TVDss �'• Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft fisit (usft) t (usft) -129.00 0.00 0.00 0.00 0.00 -129.00 0.00 0.00 2,544,538.84 263,406.53 0.00 0.00 123.00 0.75 118.00 123.00 -6.00 -0.38 0.71 2,544,538.45 263,407.23 0.61 0.43 223.00 1.00 195.00 222.99 93.99 -1.53 1.06 2,544,537.29 263,407.56 1.11 1.60 323.00 2.25 247.00 322.95 193.95 -3.14 -0.97 2,544,535.72 263,405.49 1.81 3.05 423.00 4.00 186.00 422.82 293.82 -7.38 -3.14 2,544,531.53 263,403.24 3.51 7.11 523.00 5.50 184.00 522.47 393.47 -15.62 -3.84 2,544,523.30 263,402.37 1.51 15.29 616.00 5.96 177.45 615.01 486.01 -24.90 -3.94 2,544,514.03 263,402.09 0.86 24.52 18" 623.00 6.00 177.00 621.97 492.97 -25.63 -3.90 2,544,513.30 263,402.11 0.86 25.25 723.00 5.00 183.00 721.51 592.51 -35.20 -3.86 2,544,503.73 263,401.96 1.15 34.80 823.00 5.00 188.00 821.13 692.13 -43.86 -4.69 2,544,495.08 263,400.95 0.44 43.38 923.00 3.50 190.00 920.85 791.85 -51.19 -5.83 2,544,487.79 263,399.66 1.51 50.59 1,023.00 4.00 187.00 1,020.64 891.64 -57.65 -6.78 2,544,481.34 263,398.58 0.54 56.97 1,123.00 6.00 151.00 1,120.28 991.28 -65.69 -4.67 2,544,473.26 263,400.52 3.63 65.14 1,223.00 7.25 150.00 1,219.61 1,090.61 -75.73 1.02 2,544,463.11 263,406.01 1.26 75.58 1,323.00 8.25 158.00 1,318.70 1,189.70 -87.84 6.86 2,544,450.88 263,411.60 1.47 88.11 1,423.00 8.75 163.00 1,417.60 1,288.60 -101.77 11.77 2,544,436.86 263,416.23 0.89 102.37 1,523.00 10.25 158.00 1,516.23 1,387.23 -117.29 17.33 2,544,421.22 263,421.47 1.71 118.27 1,623.00 11.25 131.00 1,614.53 1,485.53 -131.95 28.03 2,544,406.35 263,431.87 5.09 133.71 1,723.00 11.75 133.00 1,712.52 1,583.52 -145.30 42.84 2,544,392.71 263,446.40 0.64 148.14 1,823.00 13.00 131.00 1,810.20 1,681.20 -159.62 58.77 2,544,378.07 263,462.05 1.32 163.64 1,923.00 14.25 136.00 1,907.39 1,778.39 -175.85 75.81 2,544,361.49 263,478.75 1.72 181.13 2,023.00 15.00 136.00 2,004.15 1,875.15 -194.02 93.35 2,544,342.98 263,495.92 0.75 200.58 2,123.00 15.75 140.00 2,100.57 1,971.57 -213.72 111.07 2,544,322.91 263,513.23 1.30 221.58 2,223.00 17.50 136.00 2,196.39 2,067.39 -234.94 130.24 2,544,301.31 263,531.96 2.09 244.20 2,323.00 19.00 140.00 2,291.36 2,162.36 -258.22 151.15 2,544,277.61 263,552.39 1.95 269.02 2,423.00 20.50 141.00 2,385.47 2,256.47 -284.30 172.63 2,544,251.10 263,573.34 1.54 296.66 2,523.00 21.00 141.00 2,478.99 2,349.99 -311.84 194.93 2,544,223.12 263,595.07 0.50 325.82 2,623.00 21.25 144.00 2,572.27 2,443.27 -340.42 216.86 2,544,194.09 263,616.42 1.11 356.00 2,723.00 21.00 142.00 2,665.55 2,536.55 -369.21 238.54 2,544,164.88 263,637.51 0.76 386.35 2,823.00 21.50 141.00 2,758.75 2,629.75 -397.57 261.11 2,544,136.07 263,659.49 0.62 416.35 2,923.00 19.50 141.00 2,852.41 2,723.41 -424.78 283.14 2,544,108.41 263,680.97 2.00 445.17 3,023.00 18.75 142.00 2,946.89 2,817.89 -450.42 303.54 2,544,082.37 263,700.85 0.82 472.29 3,123.00 17.25 140.00 3,042.00 2,913.00 -474.44 322.97 2,544,057.95 263,719.78 1.62 497.73 3,223.00 17.25 142.00 3,137.50 3,008.50 -497.49 341.63 2,544,034.54 263,737.97 0.59 522.13 3,323.00 16.50 145.00 3,233.20 3,104.20 -520.80 358.90 2,544,010.87 263,754.77 1.15 546.70 3,423.00 15.50 145.00 3,329.32 3,200.32 -543.38 374.71 2,543,987.98 263,770.11 1.00 570.42 3,523.00 15.00 140.00 3,425.80 3,296.80 -564.24 390.70 2,543,966.80 263,785.67 1.41 592.44 3,623.00 16.25 143.00 3,522.11 3,393.11 -585.33 407.43 2,543,945.38 263,801.98 1.49 614.74 3,723.00 18.25 140.00 3,617.61 3,488.61 -608.50 425.92 2,543,921.84 263,819.99 2.19 639.26 3,823.00 19.50 143.00 3,712.23 3,583.23 -633.83 446.03 2,543,896.11 263,839.58 1.58 666.05 3,923.00 18.50 142.00 3,806.78 3,677.78 -659.66 465.85 2,543,869.88 263,858.86 1.05 693.32 3,984.00 18.19 140.79 3,864.68 3,735.68 -674.66 477.82 2,543,854.63 263,870.53 0.80 709.19 13 3l8" 4,023.00 18.00 140.00 3,901.75 3,772.75 -684.00 485.55 2,543,845.15 263,878.06 0.80 719.09 12/5/2017 1:04:42PM Page 3 COMPASS 5000.1 Build 81D • • Halliburton -IALLIBURTO J Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: "'' Well RIG:GP-24-13RD2 Company: Hilcorp Alaska,LLC TVD Reference: GP 24-13RD2 @ 129.00usft Project: Granite Point MD Reference: GP 24-13RD2 @ 129.00usft Site: Granite Point Platform North Reference: True Well: I RIG:GP-24-13RD2 Survey Calculation Method: Minimum Curvature Wellbore 1 GP 24 13RD2 Design: GP 24 13RD2 WP18 e :--x?ms... .:... ...:.. c..w.,.r 5... . r......47444444 ;;14 . +E.'i` . aaa u: a a tk.4. .= _.«::a. I Planned Survey �� Measured -4#''''''':11P,44 ;;1,-.,.,,- Vertical f4? r '"1"0€ P-`' 'V ap 11., Map Depth Inclination Azimuth Depth TVDss +NIS `'',+Ef-W Northing �k' Easting t DL' (usft) usft ". (usft) usft (') (`) ( ) usft (usft) (usft) ( ) 3,867:ff6 4,123.00 18.00 141.00 3,996.86 3,867.86 -707.84 505.20 2,543,820.91 263,897.23 0.31 744.37 4,223.00 17.50 144.00 4,092.10 3,963.10 -732.01 523.76 2,543,796.37 263,915.29 1.04 769.89 4,323.00 16.75 145.00 4,187.66 4,058.66 -755.98 540.86 2,543,772.06 263,931.91 0.81 795.09 4,423.00 16.00 140.00 4,283.61 4,154.61 -778.34 557.99 2,543,749.35 263,948.57 1.60 818.70 4,523.00 16.50 143.00 4,379.62 4,250.62 -800.24 575.40 2,543,727.10 263,965.53 0.98 841.86 4,623.00 15.00 147.00 4,475.86 4,346.86 -822.44 590.99 2,543,704.60 263,980.67 1.85 865.18 4,723.00 15.00 147.00 4,572.46 4,443.46 -844.15 605.09 2,543,682.61 263,994.32 0.00 887.90 4,823.00 14.00 152.00 4,669.27 4,540.27 -865.68 617.82 2,543,660.82 264,006.61 1.60 910.35 4,923.00 14.50 153.00 4,766.20 4,637.20 -887.52 629.18 2,543,638.76 264,017.53 0.56 932.99 5,023.00 13.75 150.00 4,863.17 4,734.17 -908.96 640.80 2,543,617.08 264,028.71 1.05 955.26 5,123.00 13.75 153.00 4,960.31 4,831.31 -929.84 652.14 2,543,595.97 264,039.62 0.71 976.95 5,223.00 14.50 158.00 5,057.29 4,928.29 -952.04 662.23 2,543,573.58 264,049.26 1.43 999.85 5,323.00 14.50 156.00 5,154.10 5,025.10 -975.09 672.01 2,543,550.34 264,058.57 0.50 1,023.57 5,423.00 15.00 160.00 5,250.81 5,121.81 -998.68 681.53 2,543,526.55 264,067.60 1.13 1,047.83 5,523.00 15.50 164.00 5,347.29 5,218.29 -1,023.69 689.64 2,543,501.39 264,075.20 1.16 1,073.38 5,623.00 16.00 165.00 5,443.54 5,314.54 -1,049.85 696.89 2,543,475.09 264,081.92 0.57 1,100.02 5,723.00 16.00 166.00 5,539.66 5,410.66 -1,076.53 703.79 2,543,448.27 264,088.28 0.28 1,127.15 5,823.00 15.50 170.00 5,635.91 5,506.91 -1,103.06 709.44 2,543,421.63 264,093.39 1.20 1,154.04 5,923.00 15.50 167.00 5,732.28 5,603.28 -1,129.24 714.77 2,543,395.35 264,098.19 0.80 1,180.55 6,023.00 15.25 171.00 5,828.70 5,699.70 -1,155.25 719.83 2,543,369.25 264,102.72 1.09 1,206.87 6,123.00 14.75 170.00 5,925.29 5,796.29 -1,180.78 724.10 2,543,343.64 264,106.47 0.56 1,232.64 6,223.00 13.50 169.00 6,022.27 5,893.27 -1,204.78 728.54 2,543,319.56 264,110.42 1.27 1,256.91 6,323.00 12.50 174.00 6,119.71 5,990.71 -1,227.00 731.90 2,543,297.27 264,113.32 1.50 1,279.32 6,423.00 9.50 185.00 6,217.87 6,088.87 -1,245.99 732.31 2,543,278.28 264,113.35 3.65 1,298.29 6,523.00 9.50 169.00 6,316.52 6,187.52 -1,262.31 733.16 2,543,261.94 264,113.87 2.63 1,314.63 6,623.00 10.50 172.00 6,415.00 6,286.00 -1,279.44 736.01 2,543,244.77 264,116.37 1.13 1,331.92 6,723.00 10.50 180.00 6,513.33 6,384.33 -1,297.57 737.27 2,543,226.61 264,117.27 1.46 1,350.10 6,823.00 8.50 155.00 6,611.99 6,482.99 -1,313.39 740.40 2,543,210.73 264,120.07 4.54 1,366.11 6,923.00 9.50 148.00 6,710.76 6,581.76 -1,327.09 747.90 2,543,196.88 264,127.29 1.48 1,380.34 7,023.00 11.00 152.00 6,809.16 6,680.16 -1,342.51 756.75 2,543,181.28 264,135.82 1.66 1,396.40 7,123.00 15.00 155.00 6,906.58 6,777.58 -1,362.67 766.70 2,543,160.93 264,145.37 4.06 1,417.26 7,223.00 16.25 156.00 7,002.89 6,873.89 -1,387.18 777.86 2,543,136.19 264,156.03 1.28 1,442.55 7,323.00 16.50 161.00 7,098.83 6,969.83 -1,413.39 788.18 2,543,109.78 264,165.80 1.43 1,469.47 7,423.00 17.75 159.00 7,194.40 7,065.40 -1,441.05 798.26 2,543,081.92 264,175.33 1.38 1,497.82 7,523.00 17.50 159.00 7,289.71 7,160.71 -1,469.32 809.11 2,543,053.44 264,185.60 0.25 1,526.84 7,623.00 16.00 162.00 7,385.46 7,256.46 -1,496.47 818.76 2,543,026.11 264,194.70 1.73 1,554.64 7,723.00 16.50 165.00 7,481.47 7,352.47 -1,523.29 826.70 2,542,999.13 264,202.08 0.98 1,581.99 7,823.00 16.00 172.00 7,577.48 7,448.48 -1,550.66 832.29 2,542,971.65 264,207.12 2.02 1,609.71 7,923.00 16.50 169.00 7,673.49 7,544.49 -1,578.25 836.92 2,542,943.98 264,211.19 0.98 1,637.57 8,023.00 16.75 175.00 7,769.32 7,640.32 -1,606.54 840.88 2,542,915.61 264,214.58 1.73 1,666.08 8,123.00 16.75 178.00 7,865.07 7,736.07 -1,635.30 842.64 2,542,886.82 264,215.75 0.86 1,694.89 8,130.00 16.64 178.06 7,871.78 7,742.78 -1,637.31 842.71 2,542,884.81 264,215.78 1.59 1,696.90 8,187.35 15.48 188.64 7,926.90 7,797.90 -1,653.09 841.84 2,542,869.06 264,214.59 5.48 1,712.57 8,249.61 16.23 200.82 7,986.81 7,857.81 -1,669.44 837.50 2,542,852.80 264,209.91 5.47 1,728.54 8,313.74 16.91 212.36 8,048.29 7,919.29 -1,685.70 829.32 2,542,836.71 264,201.41 5.23 1,744.12 12/5/2017 1:04:42PM Page 4 COMPASS 5000.1 Build 81D • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well RIG:GP-24-13RD2 . Company: , Hilcorp Alaska,LLC TVD Reference: ,,, ,,., GP 24-13RD2 @ 129.00usft Project: "Granite Point MD Reference: ,,. _ a' GP 24-13RD2 @ 129.00usft Site: Granite Point Platform North Reference: True Well: . RIG:GP-24-13RD2 Survey Calculation Method: Minimum Curvature Wellborec GP 24-13RD2 " { Design: - GP 24-13RD2 WP18 x � Planned Survey Measured ., ,, c.Vertical ;" Map ::__ Map :�'' Depth Inclination Azimuth Depth TVDss +NIS +E/-W =Northing Easting DLS iv,VertSection v (usft) (°) (usft) (usft) (usft) 7,976.26 I 8,373.44 17.97 222.06 8,105.26 7,976.26 -1,699.87 818.50 2,542,822.75 264,190.30 5.18 1,757.43 8,434.67 18.95 235.42 8,163.36 8,034.36 -1,712.53 803.98 2,542,810.39 264,175.53 7.08 1,768.95 8,497.64 20.78 237.06 8,222.59 8,093.59 -1,724.41 786.18 2,542,798.88 264,157.50 3.04 1,779.43 8,559.82 22.48 237.66 8,280.39 8,151.39 -1,736.77 766.88 2,542,786.92 264,137.95 2.76 1,790.28 8,620.78 23.56 235.12 8,336.49 8,207.49 -1,749.97 747.04 2,542,774.12 264,117.84 2.41 1,801.93 8,683.72 24.86 231.42 8,393.90 8,264.90 -1,765.42 726.38 2,542,759.10 264,096.87 3.17 1,815.75 8,743.72 26.70 231.09 8,447.92 8,318.92 -1,781.75 706.03 2,542,743.18 264,076.19 3.08 1,830.48 8,807.37 28.73 231.35 8,504.27 8,375.27 -1,800.29 682.95 2,542,725.12 264,052.75 3.19 1,847.20 8,869.07 30.85 228.90 8,557.81 8,428.81 -1,819.95 659.44 2,542,705.94 264,028.85 3.96 1,865.01 8,931.14 32.94 225.19 8,610.51 8,481.51 -1,842.31 635.47 2,542,684.07 264,004.43 4.62 1,885.47 8,992.56 34.54 224.35 8,661.59 8,532.59 -1,866.53 611.45 2,542,660.34 263,979.92 2.71 1,907.79 9,055.69 34.36 225.61 8,713.65 8,584.65 -1,891.79 586.21 2,542,635.60 263,954.17 1.16 1,931.05 9,118.28 34.94 225.50 8,765.14 8,636.14 -1,916.71 560.81 2,542,611.20 263,928.27 0.93 1,953.95 9,180.60 34.76 224.28 8,816.28 8,687.28 -1,941.94 535.67 2,542,586.49 263,902.63 1.16 1,977.19 9,241.15 33.51 224.33 8,866.40 8,737.40 -1,966.25 511.94 2,542,562.66 263,878.41 2.06 1,999.62 9,305.45 34.78 223.71 8,919.61 8,790.61 -1,992.21 486.87 2,542,537.23 263,852.81 2.05 2,023.58 9,367.11 34.30 222.51 8,970.40 8,841.40 -2,017.73 462.97 2,542,512.20 263,828.41 1.35 2,047.20 9,429.05 33.71 223.37 9,021.75 8,892.75 -2,043.09 439.38 2,542,487.32 263,804.30 1.23 2,070.68 9,489.46 33.78 224.59 9,071.98 8,942.98 -2,067.23 416.08 2,542,463.66 263,780.51 1.13 2,092.98 9,552.84 33.83 223.85 9,124.65 8,995.65 -2,092.51 391.48 2,542,438.89 263,755.41 0.65 2,116.30 9,614.39 34.74 219.94 9,175.51 9,046.51 -2,118.31 368.35 2,542,413.56 263,731.76 3.87 2,140.26 9,677.39 34.43 215.25 9,227.39 9,098.39 -2,146.62 346.54 2,542,385.70 263,709.39 4.25 2,166.82 9,738.59 34.23 211.33 9,277.93 9,148.93 -2,175.46 327.61 2,542,357.25 263,689.87 3.63 2,194.13 9,801.39 33.74 207.27 9,330.01 9,201.01 -2,206.05 310.43 2,542,327.02 263,672.07 3.70 2,223.32 9,857.93 33.94 204.48 9,376.98 9,247.98 -2,234.38 296.69 2,542,298.98 263,657.77 2.77 2,250.51 9,920.20 34.56 202.11 9,428.45 9,299.45 -2,266.56 282.84 2,542,267.08 263,643.26 2.36 2,281.55 9,985.81 36.68 199.25 9,481.78 9,352.78 -2,302.31 269.37 2,542,231.62 263,629.07 4.11 2,316.16 10,045.21 39.27 194.00 9,528.62 9,399.62 -2,337.32 258.97 2,542,196.83 263,617.96 6.97 2,350.27 10,107.36 40.84 189.11 9,576.20 9,447.20 -2,376.48 250.99 2,542,157.84 263,609.19 5.66 2,388.71 10,168.40 41.05 186.37 9,622.31 9,493.31 -2,416.11 245.61 2,542,118.33 263,603.00 2.96 2,427.81 10,230.82 40.89 184.42 9,669.44 9,540.44 -2,456.85 241.76 2,542,077.68 263,598.33 2.06 2,468.14 10,293.88 42.17 182.39 9,716.65 9,587.65 -2,498.58 239.29 2,542,036.01 263,595.01 2.95 2,509.56 10,356.16 44.15 180.89 9,762.08 9,633.08 -2,541.16 238.08 2,541,993.46 263,592.93 3.58 2,551.92 10,414.69 44.94 179.67 9,803.79 9,674.79 -2,582.21 237.88 2,541,952.42 263,591.90 1.99 2,592.84 10,479.19 46.05 178.55 9,849.01 9,720.01 -2,628.21 238.60 2,541,906.42 263,591.69 2.12 2,638.75 10,541.30 46.91 177.71 9,891.77 9,762.77 -2,673.22 240.07 2,541,861.39 263,592.25 1.70 2,683.75 10,604.01 49.30 179.46 9,933.65 9,804.65 -2,719.88 241.21 2,541,814.72 263,592.44 4.34 2,730.36 10,665.51 52.25 178.46 9,972.54 9,843.54 -2,767.51 242.09 2,541,767.09 263,592.34 4.96 2,777.91 10,727.62 53.56 177.31 10,010.00 9,881.00 -2,817.01 243.92 2,541,717.56 263,593.17 2.57 2,827.41 10,785.36 54.02 173.19 10,044.12 9,915.12 -2,863.42 247.78 2,541,671.08 263,596.09 5.81 2,873.98 10,850.97 53.50 170.11 10,082.91 9,953.91 -2,915.77 255.46 2,541,618.59 263,602.70 3.87 2,926.76 10,912.48 54.49 170.01 10,119.07 9,990.07 -2,964.78 264.05 2,541,569.42 263,610.29 1.61 2,976.29 10,973.20 55.69 167.87 10,153.82 10,024.82 -3,013.64 273.60 2,541,520.37 263,618.85 3.50 3,025.74 11,034.45 56.66 164.52 10,187.92 10,058.92 -3,063.04 285.75 2,541,470.74 263,630.00 4.81 3,075.92 11,096.79 59.32 162.77 10,220.96 10,091.96 -3,113.75 300.65 2,541,419.74 263,643.86 4.89 3,127.62 12/5/2017 1:04:42PM Page 5 COMPASS 5000.1 Build 81D • Halliburton 1-IALLI B U RTO N Standard Proposal Report Database: , Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well RIG:GP-24-13RD2 Company: , Hilcorp Alaska,LLC TVD Reference: GP 24-13RD2 @ 129.00usft Project: Granite Point MD Reference: At GP 24-13RD2 @ 129.00usft Site: Granite Point Platform North Reference: True Well: ; • • Halliburton -IALLIBURTON Standard Proposal Report Database: '. Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well RIG:GP-24-13RD2 Company: Hilcorp Alaska,LLC TVD Reference: GP 24-13RD2 @ 129.00usft Project: Granite Point MD Reference: GP 24-13RD2 @ 129.00usft Site: Granite Point Platform North Reference: True Well: RIG:GP-24-13RD2 Survey Calculation Method: Minimum Curvature Wellbore GP 24-13RD2 Design: �,. GP 24-13RD2 WP18 i' • Targets ' � 1 t'f at � ,' Target Name . 4. s �,,, -hit/miss target;„ e ® e o; e' 1' NorthingEasting -Shape .,,,,,,„41,..: Kt= us (usft) i (usf) GP-24-13RD2 WP15 Coal_10 0.00 0.00 8,532.00 -1,849.46 696.74 2,542,675.68 264,065.53 -plan misses target center by 46.96usft at 8841.86usft MD(8534.34 TVD,-1811.00 N,669.89 E) -Circle(radius 19.00) GP-24-13RD2 WP15 Coal_12 0.00 0.00 9,074.00 -2,037.57 386.57 2,542,493.92 263,751.62 -plan misses target center by 41.87usft at 9490.75usft MD(9073.06 TVD,-2067.75 N,415.57 E) -Circle(radius 18.00) GP 24-13RD2 wp08 BHL 0.00 0.00 10,914.93 -5,488.36 992.46 2,539,031.65 264,287.27 -plan misses target center by 619.87usft at 13500.00usft MD(10713.30 TVD,-5396.88 N,413.48 E) -Circle(radius 500.00) GP-24-13RD2 WP15 Coal_7 0.00 0.00 7,930.00 -1,655.19 842.47 2,542,866.94 264,215.18 -plan misses target center by 1.44usft at 8190.84usft MD(7930.26 TVD,-1654.01 N,841.69 E) -Circle(radius 14.00) GP-24-13RD2 WP15 Coal_13 0.00 0.00 9,350.00 -2,185.78 275.16 2,542,348.00 263,637.22 -plan misses target center by 42.62usft at 9816.41 usft MD(9342.50 TVD,-2213.50 N,306.65 E) -Circle(radius 17.00) GP-24-13RD2 WP15 Coal_16 0.00 0.00 10,082.00 -2,880.08 256.36 2,541,654.25 263,604.33 -plan misses target center by 21.14usft at 10822.06usft MD(10065.76 TVD,-2892.80 N,251.73 E) -Circle(radius 33.00) GP 24-13RD2 WP15 C7 Sand Top 0.00 0.00 10,129.00 -2,948.92 277.44 2,541,585.00 263,624.00 -plan misses target center by 22.45usft at 10907.55usft MD(10116.20 TVD,-2960.83 N,263.35 E) -Circle(radius 100.00) GP-24-13RD2 WP15 Coal_14 0.00 0.00 9,676.00 -2,430.01 207.10 2,542,105.21 263,564.22 -plan misses target center by 43.00usft at 10220.39usft MD(9661.56 TVD,-2450.04 N,242.31 E) -Circle(radius 10.00) GP-24-13RD2 WP15 Coal_8 0.00 0.00 8,019.00 -1,683.71 839.36 2,542,838.49 264,211.49 -plan misses target center by 7.98usft at 8283.86usft MD(8019.68 TVD,-1678.25 N,833.58 E) -Circle(radius 10.00) GP-24-13RD2 WP15 Coal_15 0.00 0.00 9,987.00 -2,754.49 226.21 2,541,780.42 263,576.74 -plan misses target center by 25.06usft at 10664.35usft MD(9971.83 TVD,-2766.59 N,242.06 E) -Circle(radius 45.00) 24-13RD2 WP16 Nov20 CT Lookahead Tgt 0.00 0.00 10,402.89 -3,464.56 423.84 2,541,066.51 263,759.89 -plan misses target center by 12.09usft at 11510.73usft MD(10403.39 TVD,-3467.67 N,412.17 E) -Circle(radius 50.00) GP-24-13RD2 WP15 Coal_9 0.00 0.00 8,456.00 -1,824.74 732.81 2,542,699.66 264,102.09 -plan misses target center by 50.31 usft at 8753.68usft MD(8456.81 TVD,-1784.58 N,702.52 E) -Circle(radius 17.00) GP-24-13RD2 WP15 Coal_11 0.00 0.00 8,835.00 -1,948.37 519.00 2,542,580.41 263,885.82 -plan misses target center by 7.96usft at 9205.21 usft MD(8836.56 TVD,-1951.92 N,525.94 E) -Circle(radius 11.00) Measured Vertical �t -1. Casing Hole , Depth Depth4. a Diameter Diameter l €'r-. K, (USN (usft) game : . O O 13,500.00 10,713.30 8 1/2"x 7" 7 8-1/2 12/5/2017 1:04:42PM Page 7 COMPASS 5000.1 Build 81D • • Halliburton HALLIBURTON Standard Proposal Report ! Sperry EDM-NORTH US+CANADA Well RIG:GP-24-13RD2 -. zP,,. Hilcorp Alaska,LLC , GP 24 13RD2 @ 129.00usft € }n Granite Point a GP 24-13RD2 @ 129.00usft ; Granite Point Platform True RIG:GP-24-13RD2 Mi •ia e ,,,,,, ,,,z.,,,Minimum Curvature '' GP 24 13RD2 " ,,an, ! ® GP 24 13RD2 WP18 7a a men ' » 1:. 13,255.56 10,742.54 -5,154.44 412.27 End Drilling Surveys-Begin Lookahead WP 12/5/2017 1:04:42PM Page 8 COMPASS 5000.1 Build 81D • S TRANSMITTAL LETTER CHECKLIST WELL NAME: � ,� � -- /64'6k. PTD: / 7 -N3 Development Service _Exploratory Stratigraphic Test Non-Conventional FIELD: 61kM,,JIVE_ PO POOL: 6i i k •d)-1" ñ944 / 4 1,i) Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 2/2015 • .110 ❑❑ N O• O O 0 Oa) N •O . r. a, o m ° — °. C. ' C 'O. S W c o co c ` - - . �; . , p, , , a) a), o, a) 3 as o a .° O , , , a ' 1W w `m. 3 c, m. ° o a , 1 co v o 3. o, a� , , , o. to .N E O o. , a m; , a�. o. N. , , , , v Q , •a) 0) ' ao). Z' - c, .". , E a , 00i w 2 aa) c s �, o O. o ' E Q 0 03 o. o. , co, a) c. ca �, a �. — �' , a, , 0 >. , a' Y. �, � t, o $. c p, a. U) a} j o_ C7 . a 0. N. o. . , . , , o E E c E 3. v N J. 00. �� G) �� L.., �� , CC, N, �� o' W� 4 W� N� <`•�� U� y, , 0 . E cp O. ° 'U, E' o, �) , o, b Q 0. O ori O c a; a� m. , oi; . •c, I'', w Q, o. a -.a' o. y. o m. m. 'N. �. 3. y, H. v, @ I- CL �, . Z. , C. U. . -p N, c. C, '6-' N. , O. °. y. G c. a) .a •y. °. Q, y. �. , N' , ) O W 20 . W. , a, '°' , N. O �O-.r a _ p. O, C. (0. O. 'y. En. co a U. 2, �. t, °. a) F- ' N' Y. ' 3 M. , 3, p a6. e .7 3. �. yo = v. o' L' : a o o, ) a). 0. u.i or @. N. >, 3. p. a) t) > M. o. _•. E v, y. Y, aa)) Z N 3, J. �. �. �. o �. (a s. c, p, Q. �. �, �. ln. �. Q. <D, U. e, N a, Z ao e, D. _ _ >. 4 p. o. O E 0 c N • p. _ �, 'S, 4 ma, , a3C ' 1 N N e a. NNN omN. m. . p. N ' ° O h-, H. . 00, Xa �m � Ow N. , w ., Y ., OW0 a a) aO, �, d �. 3q ,- a °. 2, , aj, N EMc 0 5-, H. , d, 4, 0) y , 0, i, , . 0 N. �. a) (a E. = II. E. e o y. o , E. c0 0 0 J _.1 C'' Q' (/ CO. a. 'E. �. -. �. c. , , . c_. V. t, m y. --, x' f co' o' c td • g a . >. aa) O 0• d'. , a, a. a a, O, y, as . °' . F. p. N, ro. °, Q. _. °, N• N' X' . yy U Q C9 C9 C7 C7 v) Q U N w U r m M Z 5. Y. 2 U VT 2 1 W ❑ aXi W a E a (q a Q Q V)), (al, aN., V 0, o, 'Gni, aU), N• o. o. N>. Q; Q; QQ, Q; QQN',, N', N N, N Q' N' NaN, N, N,, N), Q; O,, N), Q; Q; Q a Zz, >'. >-. >-, >-, Z. z, >-, >, r, ZZ }. Z. Z. Z, Z, ZZ. Z. }, >-, }. }, r, Z }. }. }, >', >-, >', Z. Z, >-, Z, Z. Z. N- > CO CV O .` CO U W. p, , G — E. o. �. U . o O, a. .o N t, T O �. c N. x O co o O ' y. N. J O, 0, C' 0 2. o O D, o, 2, 0. E. �. e' Q Q �. y, y. o o �. a a), INt\, N. . 47. Y E 3 o c LL , Ut Q �. °. "�ko p w. N. _ �O Lu Q' O. . r), a , , O, ht 22c. , a) , O) TN �. N. ,o 03, nIi' i . °) . ,a) v .o . jo?, 47, Oes', 4=, ! , y I-- U), 0„' CLoa) ca ° oc O N N N a . . W = . . . �. '` >, , , o , ,EEv5. @ ° c cW' . . -. a N. t a �' 1- cmrn c O Z Q'' d _ 'po, ° . 7 ,' v 0 •, C> ) oycN E •, ac, am. r. .s-.), 0, o-2@ co, a a, I) . -O. °. N, � aM, NN, N, y. , o - H •'mco 3 a u °Y � e O aoya . ' ' ' o' w • o o. Q ° C' , ' , . av .o. >. E =. uo. `ta . , a, z,.. 0, . �, � o oc, a °, v >. Nv2 . Eo °' y. Ooc, v . o; Ni' 'C' E' �, ° E' oo C. v, a N,• pcp a m c � m . ° �. �. o °. o' x, m ° m s o m ' cn7' c ,oui o' a$ gU m a a' v' ° °' ai m , °' °' a c' d a aaai - 'oa) `- e' -o m' Eo O . Nt. a , OaamNay. N. a . , a0oOc001 (, a' OOS 'c, U. z �, yp, y, ct •° QN' Um. O, E , O, O. 3. • a ,N. .N. 0. .lcC. mm , y, (0y , , pNo, O , . C . . -O, y, "O. a 0 o 6-, aE, a a e. p. O. a). 3. E. .° 'c ° o � c t p, 3a � 0. 3 0' oa. y, >, ' a), a. 32) "••••.,,_\• _• a v U c m' va) w 7), '° ' OY 3e U c cE ' N _' U ca, ity NIX C aa _ d �, 0 N NO L. C c UN' •7 'OO. N O O, 8, b. c a) c O a) J O a'' w7 a' 0. N c . ` `, N N E. @ O pU. , • N. = a) U .. , =, c. ,, y' U. c. aU ., - c ' 0 0 0 a, m o ooUaUN v ". ao o; 3 am m � vi, a E 3. �. c ° eo, a o, °J p . S -2, 0 0o .>' m e, • a 9-, Tv °' U' >' >' o 3 Uo 2,, YNUaNn, al y �o ari Zay4 .0. — — �' aa Em; 3 o; c; H1-- 0, G _ a, a 0 a E 10 , o, c, Nam aN 2; 2' 2 v 0 v = OO -c •°' N a� m a) a) oOt- ,°O ZaJD � OoaaUaaUuUUUUQQwommUs (42a q m (1) U cs)� W °' N. 0 '- N M V U) (O CO O) O e- N M V (() (O N. CO o) O N M V' U) U) M O O) � ='.i EO _� •- N M Q co co N. O °) N N N N N N N N N N M M M M M M M M M M _ V;.. U ^ ` .75 co �' o C _ ( r 0 co RI \1 '"' ON 2 0 COre O as res O0 u) N E J- N N a) >. C7oQ C c O ala as w < 0 as OF T • �� )�j/ 4,9P* ,s THE STATE 6 Alaska Oil and Gas •��,r— pfALASKA Conservation Commissi®n ,>E2 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O `T' Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Paul Mazzolini - Drilling Manager Hilcorp Alaska, LLC • 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 24-13RD2 Hilcorp Alaska, LLC Permit to Drill Number: 217-143 Surface Location: 2392' FNL, 1376' FWL, SEC. 13, T1ON, R12W, SM, AK Bottomhole Location: 2599' FNL, 2363' FWL, SEC. 24, T1ON, R12W, SM, AK Dear Mr. Mazzolini: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20,Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05,Title 20,Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair DATED this e)day of November, 2017. E D • STATE OF ALASKA • ti EC EIV ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 0 3 2017 PERMIT TO DRILL 20 AAC 25.005 AOrj 1 a.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp 1:11 c.Specify T wgiPoposed for: Drill 0 Lateral 0 Stratigraphic Test 0 Development-Oil 0 Service- Winj 0 Single Zone 0' Coalbed Gas 0 Gas Hydrates 0 Redrill 0 \ Reentry 0 Exploratory-Oil 0 Development-Gas 0 Service-Supply 0 Multiple Zone 0 Geothermal 0 Shale Gas 0 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC. Bond No. 022035244 Granite Pt St 24-13RD2 ' 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 MD: 13,501' ' TVD: 10,915' " Granite Point Field ' 4a. Location of Well.(Governmeey,n�tSection): 7.Property Designation: Middle Kenai Oil Pool . Surface: 2392'F$1_, 1376'F0.,Sec 13,T1ON,R12W,SM,AK ADL 018761 Top of Productive Horizon:riF14)4. 8.DNR Approval Number: 13.Approximate Spud Date: --S-6-.V FF-566Lf'5L, 1092eAFvvu,oec 13,T1ON,R12W,SM,AK N/A 10/25/2017 Total Depth: 00/ 9.Acres in Property: 14.Distance to Nearest Property: 2599'FNL,2363'FWL,Sec 24,T1 ON,R12W,SM,AK �'"' 5089 • 5,098'to nearest unit boundary I 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 0..41 'V t' 15.Distance to Nearest Well Open Surface: x-263406 y- 2544538 Zone-4 I GL/BF Elevation above MSL(ft): 0 1?pto Same Pool: 2,700'from GP 44-14 16.Deviated wells: Kickoff depth: 8,153 feet , 17.Maximum Potential Pressures in psig(see 20 .0.35)40-. i� Maximum Hole Angle: 75 degrees - Downhole: 5348 • Surface: 2838 ` C'ti' 18.Casing Program: Specifications Top - Setting Depth - Bottom ement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8-1/2" 7" 26# L-80 DWC/C 5,548' 7,953' 7,702' 13,501' 10,915' 545 sx 15.3 ppg Class G 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): 10,640' 10,287' 8,781'TOC Plug 8,781' 8,503' N/A •Casing Length Size Cement Volume MD TVD Conductor/Structural 592' 18" 650 sx 592' 591' Surface 3960' 13-3/8" 1850 sx 3960' 3841' Intermediate Production 9260' 9-5/8" 703 sx 9260' 8962' Liner 1586' 7" 400 sx 10640' 10287' Perforation Depth MD(ft): 9,505'-10,480' Perforation Depth TVD(ft): 9,196'-10,132' Hydraulic Fracture planned? Yes 0 No ❑., 20. Attachments: Property Plat ❑ BOP Sketch 7 Drilling Program 7 Time v.Depth Plot 7 Shallow Hazard Analysis— Diverter Sketch _ Seabed Report _ Drilling Fluid Program 7 20 AAC 25.050 requirements.i 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Monty Myers Authorized Name:Paul Mazzolini Contact Email: mmyers C(/�.hiIcorD.com Authorized Title:Drilling Manager Contact Phone: 777-8431 Authorized Signature: C PIN Clyre Date: )O/o3 /Zo f'7 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: 4/7.7- 1 l' 3 50- .733— c OO$a-Oa. -pp Date: 11 I 0(vi 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: @�I/{ Other: E" .� 4 C� 5 f— Samples req'd: Yes E Nog. Mud log req'd:Yes❑ No[+I ,JtC S i HZS measures: Yes �( No9, Directional svy req'd:Yes Er No RA /i; 5 f ck 'f' ' Spacing exception req'd: Yes Li No Inclination-only svy req'd:Yes❑ No a2 U A"1-AC2—<-: C,-kcczV(/� -) Post initial injection MIT req'd:Yes❑ No❑ ' r) 7" 1,,,,,a, . .,..0.,,,...1: ly, Co -7.‘, .1s- ieL ' t MI?' AidAh C APPROVED BY Approved by:J �� CO INMISSION Date: �,I � 11-4 PFJ i)4/ /7-717 Submit Form and Aft Forth 1 o Rei i 7/ This p rmit is valid for 24 months om t e da e o approval per 20 AAC 25.005(g) Attachments in Duplicate l c' Hilcorp Alaska, LLC P.O. Box 244027 Monty Myers Anchorage,AK 99524-40 7 Drilling Engineer Tel 907 777 8431 Email mmyers@hilcorp.co Hilc. Emmy 10/3/2017 Commissioner RECEIVED Alaska Oil &Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 OCT 0 3 2017 Re: GP 24-13RD2 ! OGCC Dear Commissioner, Enclosed for your review is an application for permit to drill GP 24-13RD2. GP 24-13RD2 is an oil production well planned to be re-drilled in a South-easterly direction from the existing GP 24-13RD utilizing the existing casing program down to 8500' MD/7873'TVD. At 8153' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Tvonek targets. A 5348'x 8-1/2"open hole section is planned. A 7" 26# L-80 DWC/C prod liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 2-7/8"gas lift completion. Drilling operations are expected to commence approximately October 25th, 2017. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, (podul niletwELL., FoR,/ Monty Myers Drilling Engineer ORIGINAL Hilcorp Alaska, LLC Page 1 of 1 • Hilcorp Alaska, LLC GP ST 24-13RD2 Drilling Program Granite Point ro •dby: M► Revision 0 October 3, 2017 i i GP ST 24-13RD2 Drilling Procedure Rev 0 IIil(•orp tla.ka.I.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 Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 BOP N/U and Test 11 11.0 Mud Program and Density Selection Criteria 12 12.0 Whipstock Running Procedure 13 13.0 Whipstock Setting Procedure 16 14.0 Drill 8-1/2"Hole Section 19 15.0 Run 7"Production Liner 22 16.0 Cement 7"Production Liner 25 17.0 Wellbore Clean Up& Displacement 29 18.0 Run Completion Assembly 30 19.0 RD 30 20.0 BOP Schematic 31 21.0 Wellhead Schematic 32 22.0 Days vs Depth 33 23.0 Geo-Prog 34 24.0 Anticipated Drilling Hazards 35 25.0 Rig Layout 36 26.0 FIT Procedure 37 27.0 Choke Manifold Schematic 38 28.0 Fluid Flow Diagrams 39 29.0 Casing Design Information 42 30.0 8-1/2"Hole Section MASP 43 31.0 Plot(NAD 27) (Governmental Sections) 44 32.0 Slot Diagram (As Built) (NAD 27) 45 33.0 Directional Program (wp08) 47 • • GP ST 24-13RD2 Drilling Procedure Rev 0 (Iileorp Alaska,LTA: 1.0 Well Summary Well GP ST 24-13RD2 Pad&Old Well Designation Sidetrack of existing well GP ST 24-13RD(PTD#180-116) Planned Completion Type 7"26#L-80 Liner, 2-7/8"Tubing GL Comp Target Reservoir(s) Tyonek Producer C7 Planned Well TD,MD/TVD 13501' MD/ 10915' TVD PBTD, MD/TVD 13400' MD/ 10888' TVD Surface Location(Governmental) 2392' FSL, 1376' FEL, Sec 13, T10N, R12W, SM,AK Surface Location(NAD 27) X=263406.53, Y=2544538.84 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 565'FSL, 1939'FWL, Sec 13, T10N,R12W, SM,AK TPH Location(NAD 27) X=263926.96,Y=2542204.41 TPH Location(NAD 83) BHL(Governmental) 2599'FNL, 2363'FWL, Sec 24, T10N,R12W, SM,AK BHL(NAD 27) X=264287.27,Y=2539031.65 BHL(NAD 83) AFE Number 1711829D AFE Drilling Days AFE Drilling Amount $4.68 MM Work String 4-1/2" 16.6# S-135 CDS-40(From Saxon) RKB—AMSL 115' MSL to ML 75' BOP Equipment 13-5/8"5M Hydril"GK"Annular BOP 13-5/8" 5M Cameron Type U Double Ram 13-5/8" 5M Cameron Type U Single Ram Page 2 Revision 0 October,2017 DrillingGPST Procedure Rev 0 Ililcorp Alaska,LLC 2.0 Management of Change Information co Hilcarp Alaska, LLC HilEacryy Com pany Changes to Approved Permit to Drill Date: October 5, 2017 Subject: Changes to Approved Permit to Drill for GP 24-13RD2 File#: GP 24-13RD2 Drilling Program Any modifications to GP 24-13RD2 Drilling Program will be documented and approved below. Changes to an approved APD will be communicated and approved by the AOGCC prior to continuing forward with work. Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Monty l\.1 Myers 10.5.2017 Drilling Engineer Date Page 3 Revision 0 October, 2017 S GP ST 24-13RD2 Drilling Procedure Rev 0 Ililcorp Alaska,LIA: 3.0 Tubular Program Hole Section OD (in) Wt(#/ft) Coupl OD It, Drift(in) Grade Conn Top Bottom 8-1/2" 7" 26 7.875" 6.276 6.151 L-80) DWC/C 7,953' 13,501' 4.0 Drill Pipe Information Hole OD (in) ID (in) TJ ID TJ OD Grad onn Burst Collapse Tension S- ;. (in) (in) (#/ft) (psi) (psi) (k-lbs), 8-1/2" 4-1/2" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 October, 2017 • • GP ST 24-13RD2 Drilling Procedure Rev 0 1111,orp:Uaska.1,1.1: 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. i. Report covers operations from 6am to 6am ii. Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the le of the data entry area—this will not save the data entered, and will navigate to another data ent tab. iii. Ensure time entry adds up to 24 hours total. iv. Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates v. Submit a short operations update each work day to pma77oliniC hilcorp.com, mmyers@hilcorp.com and cdinger@hilcorp.com 5.3 5am Weekend Update vi. Submit a short operations update each weekend and holiday to whoever is assigned weekend o vacation duty. Details will be sent before each weekend or holiday. vii. Copy pmazzolini@hilcorp.com, and mmyers@hilcorp.com 5.4 EHS Incident Reporting viii. 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 fi! re it out!!!! a. Leonard Dickerson: 0: (907) 777-8317 C: (907)252-7855 b. Mark Tornai: 0: (907)283-1372 C: (907) 748-3299 c. Thad Eby: 0: (907) 777-8317 C: (907)602-5178 2. Spills: a. Keegan Fleming: 0:907-777-8347 C:907-350-9439 ix. Notify Drlg Manager 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 x. Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally xi. Send final"As-Run"Casing tally to mmyers@hilcorp.com and cdinger@hilcorp.com 5.6 Casing and Cmt report xii. Send casing and cement report for each string of casing to mmyers@hilcorp.com and cdingera,hilcorp.com Page 5 Revision 0 October, 2017 int • • GP ST 24-13RD2 Drilling Procedure Rev 0 hue :11a.ka.1.1.1: 6.0 Planned Wellbore Schematic Granite Point Platform 14 Well: Granite Pt St 24-13RD2 Last Completed:Future PROPOSED PTD:217-xxx Iliir-orp lln,ka.1.1.I API: 50-733-20080-XX Po(B to Tubing Head 38 Casing Detail: SIZE WT GRADE CONN ID TOP BTM. :ri [ 26" Conductor 18" 70.59 B Ventura Surf 592' 13-3/8" 61.0 1-55 Butt.LT&C 12.515 Surf 3,960' 9-5/8" 40&43.5 N-80&S-95 Butt.LT&C 8.755 Surf ±8,153'(KOP) 1-80 DWC/C 6.184" ±7,953' ±13,501' A I. Tubing Detail: 1-80 Send EUE 2.441" Surf ±10,450' JEWELRY DETAIL No Depth(MD) Det ID Item 1 ±7,953' 6.059" SDD Baker Liner Hanger 2 ±8,153' ±7,894' KOP 3 ±7,953'-13,501' ±10,915' 6.276" 7"26# 30 DWC/C FUTURE INJECTOR—Plan packer accordingly .: .,' e(7 . ry // ' .TSG J } 5,/4 x. C At: CEMENT DETAIL TOC Depth TOC Depth No (MD) (TVD) Volume Item #; 4 ±9,000' ±8,618' 130 bbls 15.3 ppg Class G cement w/'/:bbl cemnet LCM 4 .4. : I- .17. " s. wk . . 5'/, 7' - P8TD:13,400'TD:±13501' MAX HOLE A NGLE•±75' Page 6 Revision 0 October, 2017 • • GP ST 24-13RD2 Drilling Procedure Rev 0 Ililcorp Alaska,LI.I: 7.0 Drilling Summary GP 24-13RD2 is an oil production well planned to be re-drilled in a South-easterly direction from the exist ng GP 24-13RD utilizing the existing casing program down to 8500' MD/7873' TVD. At 8153' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Tyo ek targets. A 5348' x 8-1/2"open hole section is planned. A 7"26#L-80 DWC/C prod liner will be run,cemented, and perforated based on data obtained while dril g the interval. The well will be completed with a 2-7/8"gas lift completion. Drilling operations are expected to commence approximately October 25th,2017. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Fi-1d G&I facility for disposal/beneficial reuse depending on test results. A separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack and for running the completion assembly General sequence of operations pertaining to this approved drilling procedure: 1. Skid rig to GP 24-13RD 2. RU,NU BOPE and test 3. DP should be stood back in derrick 4. Pull kill string n, 4. 5. PU whipstock, and mills and TIH to CIBP 6. Orient whipstock and set at 65 deg left of highside. 7. Swap well to 9.0 ppg oil based drilling mud 8. Mill 8-1/2"window and 20' of new formation at 8153'. 9. Perform FIT to 12.5 ppg EMW 10. Drill an additional 30' for a total of 50' 11. POOH and LD mills. PU rotary steerable directional BHA and TIH to window. 12. Drill 8-1/2" production hole from 8203' to 13501' MD, performing short trips as needed 13. Perform short trip and condition mud. POOH 14. LD Directional Tools. RIH w/7" liner. Set liner and cement. Circ wellbore clean. 15. POOH, laying down DP and liner running tools, 16. PU 7" casing scraper assembly and TIH to landing colfar. 17. Circ casing clean. POOH laying down DP. 18. Run 2-7/8" completion. (Covered under separate sundry) 19. Land hanger and test. 20.ND BOPE,NU tree and test void Page 7 Revision 0 October,2017 • • GP ST 24-13RD2 Drilling Procedure Rev 0 Ilileorp:11aska.I.I.1: 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate o contact the Anchorage Drilling Team. • BOPs shall be tested at (2) week intervals during the drilling of GP 24-13RD2. Ensure to provide AOGCC 48 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipme i t 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 wi 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. Variance Requests: o Hilcorp would like to request a variance to regulation 20 AAC 25.035(e)(4)(F)(i) which states - "the outlets must be at least two inches in nominal diameter, except that for rotary drilling rig )41 operations, if the operation has a maximum potential surface pressure of greater than 3,000 psi, hp 0 c' the nominal diameter of the choke outlets must be at least three inches". o The calculated MASP for this wellbore when completely evacuated to gas is 5348 psi. Hoever,�for Cook Inlet Operations, we assume that the well can never flow 100% gas, due to the wawter jrLn the reservoir. We reduce this MASP calculation to 2838 psi which assumes that only 2/3 of the wellbore is evacuated to gas and 1/3 to 9.0 ppg reservoir fluid. It' l 4 Hilcorp would like to request to have 2-1/16" outlets on the choke line and kill line due to this I' assumption 11 / Page 8 Revision 0 October,2017 GP ST 24-13RD2 Drilling Procedure Rev 0 llilcorp Alaska,td.(: Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) • 13-5/8"Shaffer 5M annular • 13-5/8"5M Shaffer SL Double gate Initial Test:250/3500 • Blind ram in bottom cavity (Annular 2500 psi) 8-1/2" • Mud cross • 13-5/8"5M Shaffer SL single gate Subsequent Tests: • 3-1/16"5M Choke Manifold 250/3500 • Standpipe,floor valves,etc (Annular 2500 psi) • Primary closing unit: Control Technology Accumulator, 3000psi, 5 station, 170 gallon reservoir, 4 nitrogen backups and 12 bladder bottles. • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Secondary back-up is an air pump, and tertiary 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). • 48 hours notice prior to spud. • 48 hours notice prior to testing BOPs. • 48 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Additional requirements may be stipulated on APD. Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email: guy.schwartz@alaska.gov Victoria Loepp/Petroleum Engineer/(0): 907-793-1247/Email: victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236(During normal Business Hours) Notification/Emergency Phone: 907-659-2714(Outside normal Business Hours) Page 9 Revision 0 October, 2017 • • HGP ST 24-13RD2 Drilling Procedure Rev 0 Ililcorp Ala,ka,Ilk 9.0 R/U and Preparatory Work 9.1 Separate sundries will be submitted that will include the following: • Pull tubing • P&A lower perfs with a cement plug • Set CIBP 9.2 Mix mud for 8-1/2" hole section. 9.3 Verify 4.5" liners installed in mud pump#1 and 5.5" liners installed in pump#2. • Ellis Williams WH-1000 Pumps are rated at 3500 psi (100%) with 4.5" liners and can deliver � 171 gpm at 86 spm. o5.5" • TSM 1000 Pumps are rated at 3500psi 100/o with liners and can deliver 229 mat 86 P ( ) gp spm. • Ideal pump rate for drilling will be 400 gpm. Both pumps running at 60 spm should achieve this. Pump#1 Ellis Williams WH1000 10" Stroke Pump#2 TSM 1000 9" Stroke 96% Efficiency Max psi 3500 psi 96% Efficiency Max psi 3500 psi Liner Size bbls/stroke Liner Size bbls/stroke 4.5 0.0472 5.5 0.0635 Strokes/minute bpm gpm Strokes/minute bpm gpm 20 0.94 40 20 1.27 53 40 1.89 79 40 2.54 107 60 2.83 119 60 3.81 160 86 4.06 171 86 5.46 229 100 4.72 198 100 6.35 267 120 5.67 238 120 7.62 320 140 6.61 278 150 7.08 297 Page 10 Revision 0 October, 2017 • • GP ST 24-13RD2 Drilling Procedure Rev 0 IIilcorp Alaska,LLC 10.0 BOP N/U and Test 10.1 N/U 13-5/8"3 5/8 x SM BOP as follows (top down): • 13-5/8"x 5M Shaffer annular BOP. • 13-5/8" Shaffer Type "SL" Double ram. (2-7/8"X 5"VBR in top cavity, blind ram in btm cavity) • 13-5/8"mud cross • 13-5/8" Shaffer Type "SL" single ram. (2-7/8"X 5"VBR) • N/U pitcher nipple, install flowline. • Install (2)manual valves 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. 10.2 Run 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 "A" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. Confirm the correct valves are opened!!! • Test VBRs on 4-1/2"test joint. • Ensure gas monitors are calibrated and tested in conjunction w/BOPE. 10.3 R/D BOP test assy. 10.4 Continue mixing mud for 8-1/2"hole section. 10.5 Set wearbushing in wellhead. Ensure ID of wearbushing> 7-5/8". Page 11 Revision 0 October, 2017 • GP ST 24-13RD2 Drilling Procedure Rev 0 Ilikrorp Alaska,i.l.l. 11.0 Mud Program and Density Selection Criteria 11.1 8-1/2" Production hole mud program summary: Primary weighting material to be used for the hole section will be barite to minimize solids. We will have enough barite on location to weight up the active system 1ppg above highest anticipated MW in the event of a well control situation. Canrig PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 80/20 Enviromul MOBM Properties: MD Mud Weight Viscosity PV YP HTHP WPS ES (PPg) 8,153—13,501' 9.0-9.5 50-80 25-35 15-22 <5 250-270K >580 System Formulation: 80/20 Enviromul MOBM Product Concentration LVT 0.662 bbl Water .172 bbl INVERMUL NT 4 ppb EZ MUL NT 4 ppb GELTONE V 6-10 ppb Lime 7 ppb DURATONE HT 2 ppb Calcium Chloride 21 ppb BAROID 41 9.0 ppg(as needed) BARACARB 5 3-5 ppb BARABLOK 2 ppb BAROTROL PLUS 4 ppb 11.2 Program mud weights are generated by reviewing data from producing & shut in offset wells, estimated BHP's from formations capable of producing fluids or gas and formations which co I d require mud weights for hole stabilization. 11.3 A guiding philosophy will be that it is less risky to weight up a lower weight mud than be overbalanced and have the challenge to mitigate lost circulation while drilling ahead. Page 12 Revision 0 October,2017 • • GP ST 24-13RD2 Drilling Procedure Rev 0 Ilileorp:%la..ka.1.1.1: 12.0 Whipstock Running Procedure Section 12.1 through 12.5 is covered under decompletion sundry, drilling proceed to 12.6 12.1 M/U window milling assembly and TIH w/4-1/2"DP out of derrick. • Use an 8-1/2"taper mill and a 8-1/2" string mill above to ensure whipstock assy will pass freely. • Ensure BHA components have been inspected previously. • Caliper and drift all BHA components before running them in the hole. • Drift DP prior to RIH. • Lightly wash and ream any tight spots noted. 12.2 TIH to CIBP (8153' MD). Note that this was a wireline measurement so actual depth tagged may vary slightly. Keep up with the#of joints picked up so we know where we are. 12.3 Pressure test casing to 1500 psi/30 min. Chart record casing test &keep track of the amount 0 f fluid pumped. Stage up to 1500 psi in 500 psi increments. 12.4 CBU& circ at least(1)hi-vis sweep to remove any debris created by the clean out run. Anything left in the wellbore could affect the setting of the Whipstock. 12.5 TOH. 12.6 Make up mills on a joint of HWDP. 12.7 RIH & set in slips. 12.8 Make up float sub, install float. 12.9 Leave assembly hanging in the elevators, and stand back on floor. 12.10 Bring Whipstock to rig floor on the pipe skate. Do not slam into bottom of Whipstock with pip- skate. 12.11 Pick up Whipstock per Baker rep using the Baker Whipstock handling system using air hoist. Allow assy to hang while Baker Rep inspects and removes shear screws as needed and any saf:ty screws. Note: Anchor should be pinned with 6 shear screws initially. Shear screws are rated for 6,630 lbs each. REMOVE 3 screws for a set down shear of 6,630 x 3=19,890 lbs. Note: Attach mills to Whipstock with (1) 35k mill shear bolt. 12.12 If needed, open BOP Blinds. Page 13 Revision 0 October,2017 yf/ S S GP ST 24-13RD2 Drilling Procedure Rev 0 nilcorp Alaska,LLC 12.13 Run the Whipstock in the hole, install safety clamp as per Baker Rep, and install hole cover wrap. 12.14 Release pick up system at this point, Make up mills. 12.15 With the top drive,pick the assembly and position the starting mill to align with the hole in the slide. The Baker Rep will instruct the driller when the slot is lined up,the shear bolt then can .- made up by the Baker Rep. 12.16 The assembly can now be picked up to ensure that the shear bolt is tight. 12.17 Remove the handling system. 12.18 Slowly run in the hole as per Baker Rep. Run extremely slow through the BOP &wear bushinl. 12.19 Run in hole at 1 %2 to 2 minutes per stand. 12.20 Fill every 30 stands or as needed, do not rotate or work the string unnecessarily. 12.21 Call for Baker Rep. 15 — 10 stands before getting to bottom. 12.22 Orient at least 30' —45' above the CIBP. Page 14 Revision 0 October, 2017 0 i H RD2 re DrillingGPST24-13Procedu Rev 0 Ililvorp:11a•ka.HA' c F'.. Window Master G2 Whipstock i� p BAKER d \.u• With Torque Master Bottom Trip p Anchor HUGHES 9.625 53.5#Non Special Drift Casing ,,, Baker Oil Tools • • * Upper Watermelon Mill • OD: 8.500 8.500 —► I `i 11— 6.25 Length: 6.25 )1FlexJoint OD: 6.375 I i Length: 6.375 --► ' ♦-- 9.00 Lower Watermelon Mill OD: 8.375 Length: MN IMndowMill 40.6 MIOD: 8.500 8.250 —* `I 1— 5.66 Length: 1.13 `1 Whipstock • OD: 8.000 8.500 _•. �.. , _ Length: 18.54 fr r 1 1 1.13 Face Angle: 1.9 A I,.�r Face Length: 17.08 I Retrieval BTA OD: 8.357 17.08 Length: 3.41 18.54 1.9 Overall length —o. Length: 44' WELL INFORMATION CUSTOMER • FIELD _ —1- MN 4— 8.000 LEASE Z mom WELL NO. 111SHEAR BOLTII 25.000 3.410 �) 35,000 8.357 —00- li r 4- 45.000 55.000 �11 65,000 75,000 NOTE DIM ENSIGNS AR BASED ON TECHUJIT DATA ACTUAL DIM ENSIONS MAY V-' Page 15 Revision 0 October, 2017 • • GP ST 24-13RD2 Drilling Procedure Rev 0 Ilik orp %la.ka.I.I.I: 13.0 Whipstock Setting Procedure 13.1 With the bottom of the Whipstock 30—45' above the CIBP, measure and record P/U and S/O weights. We will orient Whipstock face using highside MWD. 13.2 Orient Whipstock to desired direction by turning DP in '/4 round increments. P/U and S/O on DP to work all torque out(Being careful not to set BTA). Whipstock Orientation Diagram: 65L HS 85L HS Desired orientation of the Whipstock face is 65 degrees left of high side. Hole Angle at window interval (8153' MD) is 16 deg. The wellbore trajectory is planned to kick off at 178 degrees azimuth. 13.3 Once Whipstock is in desired orientation, slack off and tag CIBP to set Bottom Trip Anchor. - 13.4 Set down 12-15K on anchor to trip, P/U 5-7K maximum overpull to verify anchor is set. he window mill can then be sheared off by slacking off weight on the Whipstock shear bolt. ( 5k • shear value). 13.5 P/U 5-10' above top of Whipstock. 13.6 Displace to 9.0 ppg 80/20 Enviromul MOBM. 13.7 Record P/U, S/O weights, and free rotation. Slack off to top of whipstock and with light weip.ht and low torque. Mill window. Utilize 4 ditch magnets on the surface to catch metal cuttings. 13.8 Install catch trays in shaker underflow chute to help catch iron. 13.9 Keep iron in separate bbls. Record weight of iron recovered on ditch magnets. Page 16 Revision 0 October, 2017 • GP ST 24-13RD2 Drilling Procedure Rev 0 Hilcorp Alaska,LIC 13.10 Estimated metal cuttings volume from cutting window: Wieght of Cuttings For Milled Casing Exit O.D.Of Casing(in) 9.625 I.D.Of Casing(in) 8.535 Whipstock Face Length(Ft) 16.00 Percent of Casing Removed(%)• 38 Milled Area(InAl2) 5.908 Volume of Cuttings(inA3) 1134.272 Density of Casing(1b.CnA3)•• 0.283 Weight of Cutting Generated(lbs) 321.0 •Calculated Average of Casing Removed Based on Drift Mills(38%) ••Density of Steel=.283 13.11 Drill approx. 50' rat hole to accommodate the drilling assembly. Ream window as needed to assure there is little or no drag. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 13.12 Circulate Bottoms Up until MW in= MW out. 13.13 Conduct FIT to 12.5 ppg EMW. • (12.5 —9.0) * 0.052 * 7894' tvd= 1437 psi 13.14 Kick Tolerance f/ • (12.5-9.0) * (7894/10915) =2.5 Note: Offset field test data predicts frac gradients at the window to be between 12 ppg and 15 ppg. A 12.5 ppg FIT results in a 2.5 ppg kick tolerance while drilling the interval with a 9.0 ppg fluid density. 13.15 Slug pipe and POOH. Gauge Mills for wear. 13.16 Should a second run be required pick up the following BHA. Page 17 Revision 0 October, 2017 40 • HGP ST 24-13RD2 Drilling Procedure Rev 0 llilcorp Alaska,I.I.0 Back Up Mills Connection Length O.D. WINDOW MILL 4 1/2 REG-P X MILL 2.25 8.5 NEW LOWER WATERMELON MILL 4 1/2 REG-P X 4 '/2 REG-B 5.5 8.5 FLEX JOINT 4 '/2 REG-P X 4 '/ REG-B 9.0 6.375 STRING MILL 4 '/ REG-P X 4 % REG-B 5.5 8.5 FLOAT SUB 4 %2" IF-B X 4 '/" REG-B 3.0 6.375 30 jts-HWDP 4 %2"XH-B X 4 1/" REG-P 900' 6.5 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY' Page 18 Revision 0 October, 2017 0 GP ST 24-13RD2 Drilling Procedure Rev 0 Irilcorp Alaska,LLC 14.0 Drill 8-1/2" Hole Section 14.1 P/U 8-1/2"rotary steerable directional drilling assy. 14.2 Ensure BHA Components have been inspected previously. 14.3 Drift & caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 14.4 Ensure TF offset is measured accurately and entered correctly into the MWD software. 14.5 Confirm that the bit is dressed with a TFA of 0.51 -0.61 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 350-425gpm. 14.6 Must keep up with 5 deg/100 DLS in the build section of the wellbore. 14.7 Primary bit will be the Halliburton 8-1/2"MM75DC PDC bit. Ensure to have a back up bit available on location. COMPONENT DATA ItDescription Serial Number OD ID Gauge Weight Top Length Cumulative" 0 (in) (In) (in) (Ibpf) Connection (ft) Length (ftp` 1 HDBS-MMD75DC 5.030 2.250 8.500 54.17 P 4-1/T REG 0.95 0.95 2 Geo-Pilot 7600 EDL 175C 25KSf 7.625 1.490 8.250 114.40 B 4-1Jr IF 23.22 24.17 Stabilizer 8.375 Ref Housing Stabilizer 8 250 3 Geo-Pilot 7600 Flex Collar 5.000 1.713 76.00 9.20 33.37 4 6 3/4'Inline Stabilizer(ILS) 6.800 1.920 8.250 113.90 B 4-1'r IF 3.77 37.14 5 6 3'4-DGR Collar(Gamma} t/ 6.750 1.920 97.80 B 4.1'2-IF 4.55 41.70 DGR Insert 41.70 DDS Insert 41.70 6 6 314"EW R-P4 Collar(Resistivity)/ 6.750 2.000 104 30 B 4-12"IF 12.10 53.80 EWR-P4 Insert 53.80 7 6 3'4'PWD(Pressure) 6.750 1.905 96 30 B 4 12"IF 4.44 58.24 8 6 3/4'HCIM Collar(Processor) 6.750 1.920 101.70 8 4-1 2"IF 4.97 63.20 HCIM Insert 63.20 9 6 3.4-AID Collar(Density) 6.750 1.920 8.250 104.30 B 4-1 2'IF 14.54 77.74 Stabilizer 8.250 ALD Insert 77.74 10 6 3'4"CTN Collar(Neutron) 6.750 1.905 102.30 B NC 50 11.84 89.59 CTN Insert 89.59 11 6 34"TM-HOC(Puller) 6.900 3.250 103.60 B 4-1 2"IF 15.50 105 09 12 Non Mag Float Sub 6.750 2.750 101.71 B 4-1'2"IF 3.00 108.09 13 6-34'Non Mag Flex Dnll Collar 6.750 2.813 100 77 B 4-1 2-IF 30.00 138 09 14 6-3'4"Non Mag Flex Drill Collar 6.750 2.813 100.77 B 4-1'2"IF 30.00 168.09 15 6-a 4"Non Nag Flex Drill Collar 6.750 2.813 100.77 30.00 198.09 16 6 Joint 5'HW DP 5.000 3.000 49.30 180.00 378.09 17 6-14'Weatherford Hydraulic Jar 6.250 2.250 91.01 30.00 408.09 18 14 Joints 5'HWDP 5.000 3.000 49.30 420.00 828.09 ; „aCtd: 828.09 Page 19 Revision 0 October, 2017 r • HGP ST 24-13RD2 Drilling Procedure Rev 0 ililcorp Alaska,LL( HALLIBURTON iDrill Bits Specification Sheet (1033603) 6 Sarvlaea $_112"(216 mm) MMD75DC Product Specifications ga /'ta6'» Cutter Type Select Cutter li`s�. 4t IADC Code M422 Www Body Typect Cutt4-1, or Total Cutter Count 65s ►el "�` Cutter Distribution 13mm 16mm t Face 0 46 � d A ( 411111111011111.YGauge 0 12 N . . f ' . Up Drill 7 0 "1irr , Number of Small Nozzles 7 I # IIL� Arr. „r ff 4 �r'. ilk lik , Junk Slot Area (Sq in) 12.75 Ar •I. 'k Normalized Face Volume 41.24% l► .•' ; iet API Connection 4-1/2 REG. PIN 40 Recommended Make-Up 12,461 -17,766 Ft*lbs Torque* #'iiltNominal Dimensions- "" � + 411‘. „ Make-Up Face to Nose 11.42 in-290 mm = • *<. - Gauge Length 3 in-76 mm44 'so #Shank Diameter 6 in -152 mm in r Break Out Plate 181954/44040 • s' ! (Mat.#/Legacy#) " " Approximate Shipping Weight 180 Lbs. -82 Kg. ••• n1140 •••' O. Special Features •46. f•• • EDL Tool Specific Gage aki �•• %! • Carbide Impact Arrestor • Optimized Dual Row-"D" Feature • Combo Cutters on Gage Pads %/ Material# 1033603 Page 20 Revision 0 October, 2017 4 S GP ST 24-13RD2 Drilling Procedure Rev 0 Rilrorp Alaska,LLC. 14.8 TIH to window. Shallow test MWD on trip in. 14.9 TIH through window, ensure Halliburton MWD service rep on rig floor during this operation. • Do not rotate string while bit is across face of Whipstock. 14.10 Drill 8-1/2"hole to 13501' MD using motor assembly. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team,try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • See attached mud program for hole cleaning and LCM strategies. • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain API fluid loss <6. • Take MWD surveys every stand drilled. • Minimize backreaming when working tight hole 14.11 Hilcorp Geologists will follow mud log closely to determine exact TD. 14.12 At TD pump a sweep and a marker to be used as a fluid caliper to determine annulus volume fo r cement calculations. CBU, and pull a wiper trip back to the window. 14.13 TOH with drilling assembly, handle BHA as appropriate. Page 21 Revision 0 October,2017 • • GP ST 24-13RD2 Drilling Procedure Rev 0 llilcorr Alaska,LLC 15.0 Run 7" Production Liner 0 7 " e 15.1 R/U Weatherford 7" casing running equipment. • Ensure 7"DWC/C x 4-1/2" CDS-40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted and tally verified prior to running. • Be sure to count the total# of joints before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 15.2 P/U shoe joint, visually verify no debris inside joint. 15.3 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/shoe bucked on&threadlocked(coupling also thread locked). • (1) Baker locked joint. • (1)Joint with float collar bucked on pin end &threadlocked (coupling also thread locked). • (1) Joint with landing collar bucked up. • No centralizers to be installed on shoe joint, FC joint, and LC joint. • Install centralizers, one per joint to +/- 9,000' TMD, and leave centralizers free floating .o that they can slide up and down the joint. • Ensure proper operation of float shoe &FC. 15.4 Continue running 7"production liner • 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. 7" DWC/C M/U torques Casing OD Minimum Maximum Yield Torque 7" 19,200 ft-lbs 22,100 ft-lbs 25,000 ft-lbs Page 22 Revision 0 October, 2017 I • GP ST 24-13RD2 Drilling Procedure Rev 0 I lileorp. Ia.ka. Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: I DWC/C Casing 7 in 26.00 Ib/ft (0.362 in) L-80 2012 API SPEC 5CT COUPLING O.D. Material L-80 Grade 80,000 Minimum Yield Strength (psi.) 95,000 Minimum Ultimate Strength (psi.) USA Pipe Dimensions VAM USA 7.000 Nominal Pipe Body O.D. (in.) 4424 W. Sam Houston Pkwy. Suite 150 6.276 Nominal Pipe Body I.D. (in.) Houston. 77041 Phone: 713-3-479-3200 0.362 Nominal Wall Thickness (in.) Fax: 713-479-3234 E-mail:VAMUSAsales@vam-usa.com 26.00 Nominal Weight (lbs./ft.) 25.69 Plain End Weight (lbs./ft.) 7.549 Nominal Pipe Body Area (sq. in.) ;3,. Pipe Body Performance Properties 604,000 Minimum Pipe Body Yield Strength (lbs.) 5,410 Minimum Collapse Pressure (psi.) 7,240 Minimum Internal Yield Pressure (psi.) 6,600 Hydrostatic Test Pressure (psi.) Connection Dimensions 7.875 Connection O.D. (in.) 6.276 Connection I.D. (in.) ' 6.151 Connection Drift Diameter (in.) 4.50 Make-up Loss (in.) 7.549 Critical Area (sq. in.) 100.0 Joint Efficiency (%) ;- 1 Connection Performance Properties 604,000 Joint Strength (lbs.) 16,590 Reference String Length (ft) 1.4 Design Factor 641,000 API Joint Strength (lbs.) 302,000 Compression Rating (lbs.) i. 5,410 API Collapse Pressure Rating (psi.) 7,240 API Internal Pressure Resistance (psi.) E„ 26.2 Maximum Uniaxial Bend Rating [degrees/100 ft] Approximated Field End Torque Values x' ► 18,300 Minimum Final Torque (ft.-lbs.) 21,100 Maximum Final Torque (ft.-lbs.) (; ' 23,800 Connection Yield Torque (ft.-lbs.) Page 23 Revision 0 October, 2017 • GP ST 24-13RD2 Drilling Procedure Rev 0 Ililcorp Alaska,LLC 15.7 Ensure to run enough liner to provide for approx 200' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8" connection. 15.8 Before picking up Baker SDD liner hanger/packer assy, count the # of joints on the pipe dec to make sure it coincides with the pipe tally. 15.9 M/U Baker SDD liner top packer. Fill liner tieback sleeve with"Pal mix", ensure mixture is t in enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set u0. 15.10 RIH one stand and circulate a minimum of one liner volume. Note weight of liner. • 15.11 RIH w/liner on DP no faster than 1 min/stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. r 15.12 M/U top drive and fill pipe while lowering string every 10 stands. 15.13 Set slowly in and pull slowly out of slips. - 15.14 Circulate 1-1/2 drill pipe and liner volume at 8-1/2"window prior to going into open hole. Stare pumps up slowly and monitor for losses. Do not exceed 60% of the nominal liner hanger setti g pressure. 15.15 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 0, 20, & 30 rpm. 15.16 Continue to fill the string every 10 joints while running liner in open hole. Do not stop to fill casing. 15.17 P/U the cmt stand and tag bottom with the liner shoe. P/U 2' off bottom. Note slack-off and pick-up weights. Record rotating torque values at 10, 20, & 30 rpm. 15.18 Stage pump rates up slowly to circulating rate without exceeding 60% of the liner hanger setti g pressure. Circ and condition mud with the liner on bottom. Reduce the low end rheology oft - drilling fluid by adding water and thinners. 15.19 Reciprocate &rotate string if hole conditions allow. Circ until hole and mud is in good • condition for cementing. Page 24 Revision 0 October, 2017 • GP ST 24-13RD2 Drilling Procedure Rev 0 Ilikorp Alaska,LLC 16.0 Cement 7" Production Liner • Cement will be mixed using batch mixer to ensure consistent density 16.1 Hold a pre job safety meeting over the upcoming cmt operations. 16.2 Attempt to reciprocate the casing during cmt operations until hole gets sticky. 16.3 Pump 15 bbls 12.5 ppg spacer. 16.4 Test surface cmt lines to 4500 psi. 16.5 Mix and pump 130 bbls of 15.3 ppg class "G" cmt per below recipe with 0.5 lb/bbl loss circulation fiber. Ensure cmt is pumped at designed weight. Job is designed to pump 25% O excess but if fluid caliper dictates otherwise we may increase excess volumes. Cement volume is designed to bring cement up to 9000 in annulus of 7" casing and 8-1/2" open hole. 16.6 Displacement fluid will be drilling mud. Cement Calculations 8-1/2"OH x 7"Liner: (13501' —4501')x 0.02259 x 1.25 = 127 bbls Shoe Track: 80' x 0.03715 = 3 bbls Total Volume(bbls): 127+ 3 = 130 bbls Total Volume(ft3): 130 bbls x 5.615 ft3/bbl= 730 ft3 Total Volume(sx): 730 ft3 / 1.34 ft3/sk= 545 sx Page 25 Revision 0 October, 2017 i • GP ST 24-13RD2 Drilling Procedure Rev 0 Ililcorp Alaska,IAA; Slurry Information: System Easy BLOK Density 15.3 lb/gal Yield 1.34 ft3/sk '✓ Mixed Water 5.879 gal/sk Mixed Fluid 5.879 gal/sk Expected Thickening 70 Bc at 05:00 hr:mn API Fluid Loss <25 mL in 30.0 min at 155degF/ 1000 psi Code Description Concentration G Cement 94 lb/sk D046 Anti Foam 0.2%BWOC Additives D202 Dispersant 1.5%BWOC D400 Gas Control Agent 0.8%BWOC D154 Extender 8.0%BWOC 16.7 Drop DP dart and displace with drilling mud. 16.8 Pump cement at max rate of 8 bbl/min. Reduce pump rate to 3 bpm prior to latching DP dart in o liner wiper plug. Note plug departure from liner hanger running of of and resume pumping at 11 displacement rate. Displacement volume can be re-zeroed at this point 16.9 If elevated displacement pressures are encountered,position liner at setting depth and cease reciprocation. Monitor returns &pressure closely while circulating. Notify Drilling Foreman immediately of any changes. Reduce pump rate as required to avoid packoff. 16.10 Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger(15% above nominal setting pressure. Hold pressure for 3-5 minutes. f 16.11 Slack off total liner weight plus 30k to confirm hanger is set. 7`t'�t�x a3aZ Ybcr 16.12 Do not overdisplace by more than %2 shoe track (—1 bbls). Shoe track volume is 2 bbls. 16.13 Pressure up to 4200 psi to release the running tool (HRD-E) from the liner Page 26 Revision 0 October,2017 . • GP ST 24-13RD2 Drilling Procedure Rev 0 llileorp Alaska,LLC 16.14 Bleed pressure to zero to check float equipment. 16.15 P/U, verify setting tool is released, and expose setting dogs on top of tieback sleeve 16.16 Rotate slowly and slack off 50k downhole to set ZXP. 16.17 Pressure up drill pipe to 500 psi and pick up to remove the RS packoff bushing from the RS profile. Bump up pressure as req'd to maintain 500 psi DP pressure while moving pipe until t e pressure drops rapidly, indicating pack-off is above the sealing area(ensure that 500 psi will b- enough to overcome hydrostatic differential at liner top). 16.18 Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 16.19 Pick up to the high-rate circulation point above the tieback extension,mark the pipe for reciprocation, do not re-tag the liner top, and circulate the well clean. 16.20 Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 16.21 POOH, LDDP. Verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 16.22 If the HRD-E tool still does not release hydraulically, left-hand(counterclockwise)torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 16.23 NOTE: Some hole conditions may require movement of the drillpipe to "work"the torque do to the setting tool. 16.24 After screws have sheared,the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set-down weight to shear second set of shear screws. The top sub will dro i 1-3/4 inches. At this point, the bottom sub no longer supports the collet fingers. Pick straight uo with workstring to release collet from the profile. Page 27 Revision 0 October, 2017 • • GP ST 24-13RD2 Drilling Procedure Rev 0 Itilcorp Alaska,tit: 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&ty•e of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Note: Send Csg& cmt report+ "As-Run"liner tally to mmyers(iiJ,ilcorp.com Page 28 Revision 0 October, 2017 • • GP ST 24-13RD2 Drilling Procedure Rev 0 Ililrorp,11a.ka,IALI: 17.0 Wellbore Clean Up & Displacement 17.1 M/U casing clean out assy complete with casing scraper assys for each size casing in the hole. • 6"bit or mill • Casing scraper&brush for 7" 26#casing • +/- 5428' 4-1/2"DP. • Casing scraper&brush for 7" 26# casing • (2000') 4-1/2"DP • Casing scraper&brush for 7"26# casing • 4-1/2"DP to surface. 17.2 TIH& clean out well to landing collar(+/- 13,381' MD). • Circulate as needed on trip in if string begins to take weight. • Circulate hi-vis sweeps as necessary to carry debris out of wellbore. • Ensure 6"bit is worked down to the landing collar. • Space out the cleanout BHA so that the 6"bit reaches the 7" landing collar when crossover is +/- 30' above the 7" liner top. 17.3 After wellbore has been cleaned out satisfactorily using mud,test casing to 2000 psi/30 min. Ensure to chart record casing test. 17.4 Displace drilling fluid in wellbore with a hi-vis pill followed by filtered inlet water. • Circulate 3 to 4 B/U until clean-up is satisfactory. Do not recirculate fluid, pump and dum;i • After a couple circulations using FIW, short trip the assy to bring the upper 7" scraper assy to surface. • RIH again &tag landing collar w/6"bit. Continue circulation as necessary until fluid cle. s up. Make another short trip if necessary. • Pump a chemical train followed by FIW. Target NTU's are 80-100 17.5 TOH w/clean out assy. LDDP on the trip out. Page 29 Revision 0 October,2017 • • H GP ST 24-13RD2 Drilling Procedure Rev 0 11ilcorp Alaska,LLC 18.0 Run Completion Assembly 18.1 Run 2-7/8"tubing completion assembly as per separate Approved Completion Sundry 19.0 RD 19.1 Install BPV in wellhead. RILDs. 19.2 ND BOPE,NU tree,test void 19.3 Rig Down Page 30 Revision 0 October, 2017 • • GP ST 24-13RD2 Drilling Procedure Rev 0 Ililcorp Alaska,LLE 20.0 BOP Schematic P.Ig poor 16" Pipe 111 al Ill lIIIll • • Ill al al 111 lit Ill Ill Ill 37'` Shaffer al al Illlil al 2.83' 2 7/8-5.5 Variables -� 13 5/8 SM Blind 2 1/16 5M manual valves III 2 1116 5M manual and HCR valve 1.76 It:I►4 �J14 ) ' H • .Ir mi ' Iii Ill 111111 III V =11 111 33'5 8 5M __ - _- 2 7/8.5.5 Variables 1.44' _ Iii III Ill III III Drill deck 13.70' Riser 135/8 SM FE X 13 5/8 SM API hub J � Page 31 Revision 0 October, 2017 • • GP ST 24-13RD2 Drilling Procedure Rev 0 11114 orp;%la'ka.I I F 21.0Wellhead Schematic We ead Sc erratic Granite Point Platform Tubing hanger,WG-TC-IA- GPP 24.1380 EN Cl,11 X315 EUE lift and 18 x 133/8 X 95/8 X 7%31/2 susp,w/3 Type HBPV profile,IS non-cont SCSSV port,6 X"extended neck BHT0.WG-8-11A0, 3 1/1610M FE if ' Jima pA Valve,Swab,STN, 3 1116 10M FE.HWO, -0, "< Valve.Wing,WXM-Ml, BB trim 'c, 31/1610M FE,HWO, ........ III B8 trim 1111 1'tt 40 ,,., . Valve,Upper Master,BTN, ' 4, 40 31/16 10M FE,HWO, ' BB trim :ttoy° viimmiiiv Valve,Master,BTN, o !� 3 1/16 10M FE,HWO,BB ,.�ot-o li trim VO Itl rI/1 Tubing head,WG-TCM-8G, 1i1 I lel 13 5/8 SM APi hub bottom x 11 10M top,w/ 2-1 13/16 10M SSO iiergmill ANI Unihead,OCT type 2,13 5/8 5M ASI 0 . i ..;per bowl section bad hub top x 13 3/8 ETC casing bottom, —� w/2-2"LEO on lower section,2.2 1/16 SM SSO on upper section,IPillill internal lockpin assy a :•/ M., A , „.:11. ,.„ i; r Lab r Starling0 iris 1 head,OCT, M :� �'iiil ' 21 1/4 2M Hubx 24X 1M Hub wJ 2-2"IPO V prepped f/18"EN hanger • r 7 Conductor housing,OCT, , y _ 24X 1M Hub III 24"Buttweld II '' I 1� � II 8. �•13 3/8' —1 9 5/8'• I 3„ Page 32 Revision 0 October,2017 S S GP ST 24-13RD2 Drilling Procedure Rev 0 Ililrorp;Ua-ka.1,1,1: 22.0 Days vs Depth Days Vs Depth o — GP-24-13RD2 2000 4000 • -- 6000 - a v i 3 8000 10000 12000 14000 0 10 20 30 40 50 60 70 80 90 Days Page 33 Revision 0 October, 2017 • • GP ST 24-13RD2 HDrilling Procedure Rev 0 I the orp Alaska.lit: 23.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: GP 24-13RD2 FIELD: Granite Point GP 24-13F SURFACE X: i 263406.53 . 2544538.84 STATE: Alaska SURFACE Y i i BOTTOM HOLE X: _ 264287.27 TVD REF DATUM KB BOTTOM HOLEY: 2539031.65 1TVD REF ELEV 129 COORD REF.SYSTEM NAD27 AK4 True North GROUND ELEV 0.0 i PROPOSED TD: — I jMD WATER DEPTH 75.0 I PROPOSED TD: E TVD , Sidetrack well 24-13RD and drill a–2000' lateral through the Tynonek C7 SAND Objective: Geo Summary/ C7 lateral well through untapped oil wedge on east flank of field. Justification: GP 24-13RD2 TARGETS,ANTICIPATED FORMATION TOPS& GEOHAZARDS .,'TOP NAME z 4 FORMATION MD TVD(FT) Est.Press •, =art MW GRAD KOP 8153 7,893.83 3489 8.5 0.44 Cl [ Sand OIL/WATER 9480 8,995.00 I 4673 10.0 a52 C2 , Sand OIL/WATER 9501 9,011.00 ( 4673 10.0 0.52 C5 Sand OIL/WATER 10246 9,595.00 4806 9.6 0.50 C6 Sand ` OIL/WATER 10513 9,804.00 4907 9.6 0.50 C7 SAND TOP Sand OIL/WATER 11059 10,179.00 5028 9.5 0.49 TD Sand OIL/WATER 13501 10,914.93 5349 9.4 0.49 —1 i . . : .. . , . : . . : : . . .. . . : : : : . . =Primary Objective =Secondary Objective TARGET SIZE 50 FT DATA COLLECTION REQUIREMENTS: Mud Logging: gas monitoring and cuttings description / , M/LWD Data: MWD/GR, resistivity, neu,den,dipole sonic E-Line Log Data: RFT,SWC COMPLETION TYPE 7"casing to TD&perf(1500) ANTICIPATED RATES ARTIFICIAL LIFT EQUIPMENT OD Run Tubing and Gas lift Valves TUBING SIZE € OTHER COMMENTS __.__._......._. .....; Page 34 Revision 0 October, 2017 • GP ST 24-13RD2 Drilling Procedure Rev 0 Ililcorp Alaska,LLC 24.0 Anticipated Drilling Hazards Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material, 500 lbs SteelSeal (Angular, dual-composition carbon-based material), & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/viscofier as necessary. Sweep hole w/20 bbls flowzan as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain programmed mud specs. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. • Minimize swab and surge pressures • Minimize back reaming through coals when possible H2S: H2S is not present in this hole section. No abnormal temperatures or pressures are present in this hole section. Page 35 Revision 0 October, 2017 • • GP ST 24-13RD2 1 Drilling Procedure Rev 0 flilcorp Alaska,LK 25.0 Rig Layout 40 ijd!,,::-....t:2 -:)..,,,5: h.tirl, 0 Y. TY Y2'' rf= -11 '(( j .i:- -MA' & : 'Yi NVTt.144(r,Olt ic..,(- - �raa t , t:} T T I ,' I l 11 � -2r) , � r s .j III . L I— ; ' 1 6. ig / - -,.. -0 h$ / \ IIiiI kik\\� 79 p\4 6 ,I / oi i I, \ X4 \\ 1= ! ,../.4-.1,2-A f 1.4,,e4;;,',3'il:-11 \ ,, •\ A , • .. E \\ SII �u ' II r, =� f u'-0' N Page 36 Revision 0 October, 2017 • • 14GP ST 24-13RD2 Drilling Procedure Rev 0 Ililcorp Alusku,LLC 26.0 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) s. 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 stabiliz-s. 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 'ck 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 flu d; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and press e monitored as with an FIT. Page 37 Revision 0 October,2017 • • GP ST 24-13RD2 Drilling Procedure Rev 0 Ililcorp Alaska,LLC 1 . 27.0 Choke Manifold Schematic Choke Manifold Valves 2" 3" To Shaker 3" Panic To Gasbuster 3 1/8" -.- 0 --..© 2 1/16" ' ( © .� 2 1/16" + 2 1/16" di) 2 1/16" © - "`"'JJJ ifl 3 1/8" I -' Q ----,,,,0 ©f N L004_._,J t /1/16" t 2 1/16" 2 Manual Chokef Automatic Choke 2 1/16" Inlet Pressure Sensor 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED= 3 1/18" 5,000 PSI VALVES AND LINES BLUE=2 1/16"5,000 PSI VALVES Kuukpik Drilling Rig 5 / Choke Manifold Imo` ot; ':))se. .41 :Io -.^- 1111' ---- IP"-r--- —Ai -1 ,.2 .. Ct v Cnoka Manifold Page 38 Revision 0 October,2017 • • HGP ST 24-13RD2 Drilling Procedure Rev 0 IIilrorp Alaska,1.U: 28.0 Fluid Flow Diagrams x- r 5. v V 9 S = 1 1 1 1 1 1 1 1 1 jII 1 Iti Iw1,/1o'IN1a.141�1" j 1 1 1 1 1 1 1 1 1 T A r' 0.0 IH 1NIH1NiNiH IN i0• _ iS i:::iL.,a i:iI„ I '-11,' II Mi./Mill'is isisis 11:1:111:111§1f 1L 0 yLL 0 0 y, LLL yih • Inieini�iElnniniC 1;I^1±I�iw 1�Iz 11 In !FLViinli A n I II i i l a.a.......■.l..l■.l. cnA Qrn :•1 Da Da 0 A 4t.X l r.o, 4) •_ CT w C N • pp (D �p CD �'`�L1 K Na -• •O SA 7 DQ O yy 1 I 1 1 1 1 1 1 1 I• 0 • _ L . ; 5• DI DG Da DG ! 1'/I1t.•It,.14141041ta1 - - N !,•;:!;!:!:!Z!7•1 .!:-1 ;!:! :i,iai 1 iIY1 !`=!..l ! IAIPI v 1..IAI, I I ig Ig 1'SgI'$g k m- X^ !;,',11,111 ) 111 %S8$ x 4 2 13.. it�pt-1-.`1 (D K 1'tF i�'i`i�i�ic in ini N. O r 1 i±IA Ip i--11 4,i-IA 1 O• r = I r 1 AIAAA1A1A1A1A1 z A !r!r!r!r!r!r'Fir!r e. 4 11i 4 Da ni N 4 1 A 1 V w -• i i i �i i i iM d A la l'«it.: ii it:io ho N• III 1 1 1 1 N• NN co A ! ! ! 1 1 1 Ir Da ► 1 1 1 ig' i !s I i i1 rami v A 7 1• Il i• t 1-1�1 ie. a 1 Imo,1P is!�! !p 1v-{ 14 rill IC Im In- X N9 6 W!-1 IAis I 17yg b-•I 1 I�Iw K O C , a= — T 1 Ir !S!;! ! CO Q '0O I ITI- Is 1.1 1 In p Q. i 14 1g i.is i 1:, I I 11IA i 1; • .A E bC'O!S !rlp!r1 C III i. s Lai- E i 41 Jai- 0 Page 39 Revision 0 October, 2017 • 0 H GP ST 24-13RD2 Drilling Procedure Rev 0 Nilcorp Alaska,LLC c c n T. v oT A y �w1 U E .r a _ S W - I t i l l l i ! i p I I 1 1 1 t I 1 1 1 w (7ID r 11/1 11..11.4p..IN!"1111ta114 ! i:.1:..I^1.`.1«4.1..1^,ir1 V1 1Q i°'i'1 i'1 ice'i°21e'ie'ip 1111111111111111 19 112 iv iv iv. iiv, w 1I 1i lc)!o!;:i IE)! In!(2 w it!;! !z:Iw iw tq!q I 11 P'} c 1 1 1 i 1 1 1y • Io IQ 0�'Q�iq 19 19 irfIv N p 1 1 1 1 1 1 1 1 1 1 DQ Don n (710 .a• Cr) 1 cot AA O W• w : x (n v Y i (D COX N. —1X8 E D4 O 1 i l 1..1.! i i i i O pp_ r iai:iia111i1:.11:1.`.io1 co Q ' -.J ('1 i i i I i i i I I .I, ^' 1 I�itoi"i"iwiui"i"i D4 D4 D4 D4 r -' W c i�is 1,i1,-iiaiai.-i-i N cfl — b t.i s is i°i 'i =is iQ iaz 1, i�1 I66! 1 1 lrat Imo . Is 1v, iOt l b.IO tt Iq 4 4 i�i.i_««1=.Ia.iw iN i a) rJ I Is Iw 17;1Z iw Iw 14. q!O • �^ Ci (•n * fn.0.0..n,nlnl•0.n o f ISIS!S!S!SIS!SlSiS M a p R (/ D4 Iv ii el . N• U) ~ 1 1 1 :41 1 ! 1 x I•�11, 11. (1.11.,..10!'0 x N 1 1 1 1 1 1 1 .N• W A t i l t r 1 DQ I I 1 1010! 11 - 17 1• 1 In i;iE 1 is £ �- i• F. 1 1. it i•.e,Ir 1 !• _ I I•.. �1. !C 3 it . 70 ti IW1�11, $,1t.1�1l� 7 7 (✓5. Iyb f�, w 1 IC IX;�, w ► C 73 I�A 1itv11 1w Q O c it5.l•r !t!, ' I (n G. 141;r; 1.11 ! !... I I I it 171 IN "I ( I I 1'1I I IR G 1 in I vi I i i S!s !ob �1q b I ITI sr • 0o :lofa !a leIoidl Page 40 Revision 0 October, 2017 0 • HGP ST 24-13RD2 Drilling Procedure Rev 0 llilcorp Alaska,L1.0 X C n a X' o is _V A iI O U O EW _ I I It 1 1 1 1 t I,o,m14140e4I.6,iyleal.- 1 W rr 1 ; 1 I 1 I i I I T 1 T t . t . t . } Fi ,eaiu,u;. :. eaieaieaiea . I:.1~Irl:i 111:1..: CJIPPpQPpPP 40 44ItII IIIIII 111111111 ol i i iITii.."1/ iCtiC" IA 1A 1;1;17! IA At 17 1 f } } } f f .p islsipipl 1 t 1 ip w —I — ,.....!-,-.-!4! ,— I I-1 w 1 e 1�i!i.3 114 _a v v Mala la is la 1a is la • • X8 Q--4 D4 01. 10, cl 0 n • U' C) _.V toll X o O wo Q F 7C- c m y o0 a • o r W: v NJ .. go E o Da 0 I t 1 ! I I 1 ! ! 1gg j , iZ ia`i`rlia1.ai:iuie,1:141 CO• V I t I I I I I 1 1 I4 ii i i i ii I r..."..1 P.• 1.' 8.4 �•ye•ea•ea•4.4•eaea• N J tD --' i• 1 I 1..I.•,I 1 1...I.,I = 1�n1£Ei lalzi,,,1ob_! •ioi rJ 1!,Teg 11Q I I Igl co _ Ist�b! bb b�!oI7- o tq t�t�14 11.1[-�t-It.i..I NC7 p — 1 tCJ1 1i 1�li IVIVI�1 p41 70 T O 1 i+I"ii.I;t'lziei+i r f 1 i i i i i i i i i .R �Qnnn nn•nn _= SO o!$ e e o o Q 10:a Ii Ii::1i E$t$1$ up n I O I I I I E 1 1 4iiii(---, V-1 4 Da ® N ; 6 ,g cn A iuiwi+: 1.41 lore • a Np N N c co A ill i i i i is DQ 110" D4 1 1 1 13 1 I— i 1 1 i°lo I 1S A cn 1 1 1n i-IsI I7 u i ilii ilti. 1 1«5. a c 1 iri it ie i to 1 t►.tilh. it 1.1 1 1 O Icrit�y� 'aiEiElxi; A —' c 1 I`I- 1r•iVi Irre to Q10 O d. i I le i!I i i?1t I�E•1 is- w .r'r.t t', -r7 I 1 I 1:;q i t. O III I 1� t I, < 1 1 I in! I.L . 0bois is.$ b0.° riTi , I , i . , I vi Page 41 Revision 0 October, 2017 • • HGP ST 24-13RD2 Drilling Procedure Rev 0 Itilcorp Alaska,LLC 29.0 Casing Design Information Calculation &Casing Design Factors , Cook Inlet Offshore DATE:f0i212017 WELL:GP 24-13RD2 FIELD:Granite Point DESIGN BY:Monty M Myers Design Criteria: Hole Size Mud Density: Hole Size 8-112" Mud Density: 9.0 ppg Hole Size Mud Density: Drilling Mode MA SP: 282 psi(See attached!1.+°-..SP determination &calculation) Production Mode MASP: 5348 psi(See attached 1.1ASP determination &calculation) i Collapse Calculation: Section Calculation 1,2 Normal gradient external stress(4.43 psi/ft)and the casing evacuated for the internal stress 1 1 Casing Section Calculation/Specification 1 2 3 4 Casing OD r 0 Top(MD) 7,953 Top(ND) 7,702 i a Bottom(MD) 13,501 Bottom(TVD) 10,915 Length 5,548 s Weight(ppf) 26 d t Grade L-80 + Connection DWC/C d Weight w/o Bouyancy Factor(lbs,) 144x248 : Tension at Top of Section(lbs) 144x248 o Min strength Tension (1000 lbs) 604 I Worst Case Safety Factor(Tension) 4.19 ✓ Collapse Pressure at bottom(Psi) 4,693 Collapse Resistance wio tension(Psi) 5,410 1 e Worst Case Safety Factor(Collapse) 1.15 MASP(psi) 2,838 '•. Minimum Yield(psi) 7240 i a Worst case safety factor(Burst; 2.55/'s Page 42 Revision 0 October, 2017 III • 14GP ST 24-13RD2 Drilling Procedure Rev 0 Ililcorp Alaska,LLC 30.0 8-1/2" Hole Section MASP 11 Maximum Anticipated Surface Pressure Calculation Hilcor 8-1/2"Hole Section t GP 24-13RD2 Cook Inlet,Alaska MD TVD Planned Top: 8153 7894 Planned TD: 13501 10915 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad = KOP 7894 3489 Sand 8.5 0.44 Cl 8995 4673 Sand 10.0 0.52 C2 9011 4673 Sand 10.0 0.52 C5 9595 4806 Sand 9.6 0.50 C6 9804 4907 Sand 9.6 0.50 C7 SAND TOP 10179 5028 Sand 9.5 0.49 TD 10915 5349 Sand 9.4 0.49 Offset Well Mud Densities Well MW range Top(ND) Bottom(ND) Date A-27RD2 9.3-9.5 7,755 9,718 2016 K-24RD3 8.9-9.3 8,768 9,994 2017 A-27RD 9.5-9.7 6,328 9,950 1997 K-06RD2 9.0-9.3 6,352 9,792 2017 I 4 Assumptions: 1. Anticipated fracture gradient at 8153'TMD(7894'ND)=0.7=14.9 ppg EMW 2. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assumes 9.2 ppg reservoir contains 2/3 gas,1/3 water. 1111111111 = I I I I I Fracture Pressure at window considering a full column of gas from window to surface: 7894(ft)x 0.7(psi/ft)= 5526 _ 5526(psi)-[0.1(psi/ft)*7894(ft)]= 4737 psi MASP from pore pressure;normal gradient at TD,(0.49 psi/ft) i j 10915(ft)x 0.49(psi/ft)= 5348 psi 5348(psi)-(0.1(psi/ft)*10915(ft))= 4257 psi MASP from pore pressure;unknown gas sand at TD,at 9.4 ppg(0.49 psi/ft) I 10915(ft)x 0.49(psi/ft)= 5348 psi Downhole 5348(psi)-[(2/3)*0.1(psi/ft)*10915(ft)]+[(1/3)*0.49(psi/ft)*10915(ft)]= 2838 psi Drilling M Summary: 4" C L(; 1. MASP while drilling 8-1/2"hole is governed by pore pressure minus 2/3 of wellbore evacuated to gas(remaining 1/3 remains 9.4 ppg drilling fluid) 1 Page 43 Revision 0 October, 2017 • • HGP ST 24-13RD2 Drilling Procedure Rev 0 Ililcorio kla-ka.LU: 31.0 Plot (NAD 27) (Governmental Sections) ,\ -\ GP-11-13 W0. GRANt1P iT GP-31-13 BItSOP3 / 1.13 BHL \ \ GRAN11_PT-*1 BHL \ 1\ \�ak1L Legend \\\ \ \GP tt tGP-11-13RD Plan GP 24-13RD2_SHL Other Surface Hole Location \ \ 5 ," \ BHL \\ GP-31-14R021 \ \ Plan GP 24-13RD2 TPH • Other Bottom Hole Location 2::C.;„;'-z-----452:44_,.... 41,31-14R01 1 \ 1 - GP-3I 4kko -�L\, t \ I -+1- Plan GP 24-13RD2 BHL Well Paths �% BHL GP31-t4RD1 \\ i �L , \ \ t / 1 • ♦ C -Zit-'3 BMLRC,`p-22-73 Bt11. • \1 < GP 24-I 3RD2 SILL \ \r �/ --- --GP.3223P13 B - :8Ht--- -^. 2 -L ,/ 6 Y' \r�,-.-- -GP32-13 ort,GP-32-t : i /1 \ \, S01ONO1QW /,i 1 ` S01ON012W 13 GP {g&IIL 1 15 ♦, CAa� \5 ',i __ s• \, Bio./err .•ItHL i 1 1 GP-33-1381 -- v '\, /�/�/ ff i I `\ N % -73 BK. •\,.. GP-22-13RD3 // i / I 1 \1 , Q81 BHL i '// // / 1 N \"� \\ GP-22-13RD3 7././ / I I 1 \ , BHL /,/ / 1 I \ `, •,, / I `5 G ITE �. a:. GP 4 / i I It POIN UNITN. i -S58H1i ( I I ,. GP-22-43(103. i 1 N -. ///i ///GP-55 BHIC r I I8 f' 32-13RDPB GP-22-13R03 81-It 8ZHL / / t O • L / ' / �/ T 1 I �GP'2 B %F,-2¢13BHL GP32--t13RDPB S01ON011W / / / 1 10J ,GP 24-13RD2 TPI{ 1': / / 1 1,0 ADL018761 i tl j o J / / of / / ! B , GP-11-tri BHLMgP-11-24 BHL ``/ I o I / �,P-11-24P,)3�GPj71-24P8 I C i / / BHL BHL I 0 I 1 / I o 1 / I of / // I // �'/ I /o / // I / o / a / / / I / o // /i/ I /' o // I/ o oS01ON01QW SOION011W S010N01i2W ' , I o y� t o 0 ' i (xJ �'/ i 0 o X12-24 BHL 0 GP-12-24 8#41. / o 0 10 / 0 / o I I ,-GP 24-I 3RD2 I/IlL 1 / / -a- , II 0 500 1.000 1.500 Granite Point Unit Feet GP 24-13RD2 wp08 Alaska State Plane Zone 4.NAD27 A Hileorp Alaska,LLC. Map Date:10/2/2017 Page 44 Revision 0 October, 2017 9 • GP ST 24-13RD2 Drilling Procedure Rev 0 IIuI(orp Alaska,1.1.1; 32.0 Slot Diagram (As Built) (NAD 27) I 11 72 PROTRACTED SECTION LINE NOT TO SCALE(NTS) 14 13 Li .11 SECTION CORNER (PROTRACTED) N:2546957.328 E:262081.754 z CENTER LEG 2 (n � LAT:60°57 29.91087"N I- LON: 151'19'53.20585"W Z a N:2544611.886 W n E:263360.744 J ASP ZONE 4 NAD 27 U z 2319'FNL In 1326'FWL O I- ' NY NELLS oR z,_r O"' �'V 1326'FNL(NTS)- OBSE.':ED Z CENTER LEG 1 LAT:60'57'29.46354"N LON, 151°19'54.53958"W n Z N 2544567.808 E:263293.981 'J ASP ZONE 4 NAD 27 Z2364'FNL EVYTY -S 9 1260'FWL I- U ,..,, c MMPrY W (/) 3,.11RD2 4'W • 12.21 �'� 1260 `"`("'S) W GRANITE(POINT PLATFORM f- 31.23 01,11--,77,114,40, 32 23 CENTER LEG 3 (..3 E1.N 3J-,4110 1°/� ASBUILT WELL LOCATIONS 213802 LAT:60'57'29.26234"N Q �.r u n 31^, LON: 151'19'52.28588'W CC SECTION 13 T10N R12W f- 44.4 EMPTY 1 I N:2534545.120 -�_ _..................... __.. II-13RD ',.W+�I 11 E:263404.821 �- 1371'Mt(NTS)-. .W,t= ASP ZONE 4 NAD 27 d �J ' . 1.2 2385'FNL 11.24 �.0 a.•eb° 1371'FWL ♦13 W• 321380 12-23110 GR.60 24-13RD EMPTY F41PlY EMPTY MYtV • CENTER LEG 4 '~'� 1305'F1@(NIS) Ft.:atr Lt. / LAT: 60'57'28.81798'N ::,, �.�7 � LON: 151'19'53.62548'W F,.�.TY � 55 N:2544501.349 • •.+ E:263337.774 5J ASP ZONE 4 NAD 27 ,E 2430'FNL �`��`�, [MP, EVYTY 52 ......%.;,O F q EVY;Y 1305'FWL ` ..... ......9 �T NOTES , i* P O. i�'.S,*�aol t/ . NOTES or*i Ili ol'1 ,*aol sow O. 1. BASIS OF HORIZONTAL CONTROL:NAD83 US FEET POSITION(EPOCH / -�- 2010)AND VERTICAL CONTROL(NAVD88)IS AN OPUS SOLUTION FROM NGS STATIONS TBON.TSEA.AND ANC2 TO ESTABLISH POINT#1100 THE 4-"iiik 00 , " (AIN C.BROWN :' a ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE: , % E=1403394.393 IIIMIF ,�` ELEV_=115.958(NAVD88) ��w ,�I`,`\��``*Ai -F� 2.SECTION LINES SHOWN ARE EXTENSIONS OF PROTRACTED VALUES. SCALE 3. COORDINATE CONVERSIONS(NAD83-NAD27)WERE DONE USING c 3p c; `CORPSCON SOFTWARE VERSION 6.0.1 I FEET ' "`.°r HILCORP ALASKA.LLC REVISIONGRANITE POINT PLATFORM WELL SLOTS ' , COOK INLET ALASKA °"'""`Y ICS AS BUILT SURFACE LOCATION NAD 27(FOR INFORMATION ONLY) PROJECT NO tnwe E`4..NEEa :.�.°� EYING..EST:N, No ,.ter PO > NS AS �«•,_ VOICE A< Ss° - MT: 1 Ilileor Alaska,LLC PROTRACTED SEC. 13 T10N R12W ter* P SEWARD MERIDIAN,ALASKA 1 a` 3 Page 45 Revision 0 October, 2017 • • GP ST 24-13RD2 Drilling Procedure Rev 0 Hilcorp Alaska,LLC NAD 27 WELL SLOT NORTHING EASTING LATITUDE(N) LONGITUDE(W) CL LEG 3 2544545.120 263404.821 60°57'29.26234" 151°19'52.28588" 31-13 1 2544550.59 263401.139 60°57'29.31546" 151°19'52.36268" 22-13RD2 2 2544551.711 263405.531 60°57'29.32737" 151°19'52.27421" MUCI-1 3 2544549.723 263409.592 60°57'29.30862" 151°19'52.19116" MUCI-2 4 2544545.606 263411.397 60"57'29.26844" 151°19'52.15293" 32-13RD 5 2544541.274 263410.117 60"57'29.22553" 151°19'52.17707" LEG 3 24-13RD 6 2544538.84 263406.528 60°57'29.20086" 151°19'52.24873" 42-23RD 7 2544539.235 263401.999 60°57'29.20384" 151°19'52.34061" 43063 8 2544542.441 263398.892 60°57'29.23478" 151°19'52.40484" 11-13RD 9 2544546.905 263398.51 60°57'29.27865" 151°19'52.41439" EMPTY 10 2544543.272 263406.149 60°57'29.24441" 151°19'52.25823" GP-50 11 2544545.15 263402.616 60°57'29.26219" 151°19'52.33053" GP-51 12 2544547.233 263405.593 60°57'29.28330" 151°19'52.27110" CL LEG 4 2544501.349 263337.774 60°57'28.81798" 151°19'53.62548" EMPTY 1 2544506.617 263333.993 60°57'28.86909" 151°19'53.70421" EMPTY 2 2544507.720 263338.358 60°57'28.88083" 151°19'53.61627" 54 3 2544505.736 263342.508 60"57'28.86212" 151°19'53.53143" 55 4 2544501.552 263344.322 60°57'28.82129" 151°19'53.49299" 53 5 2544497.344 263342.958 60°57'28.77958" 151°19'53.51888" LEG 4 52 6 2544494.923 263339.453 60"57'28.75505" 151°19'53.58885" EMPTY 7 2544495.296 263334.763 60°57'28.75778" 151°19'53.68396" EMPTY 8 2544498.575 263331.660 60°57'28.78944" 151°19'53.74816" EMPTY 9 2544503.081 263331.389 60°57'28.83376" 151"19'53.75548" EMPTY 10 2544499.473 263338.980 60"57'28.79975" 151°19'53.60030" EMPTY 11 2544501.035 263335.567 60°57'28.81445" 151°19'53.67005' EMPTY 12 2544503.340 263338.779 60"57'28.83779" 151"19'53.60597" vaO.BCT REvu.or ' HILCORP ALASKA. LLC GRANITE POINT PLATFORM WELL SLOTS COOK INLET ALASKA CRAW.BY KB SCALE x4 AS BUILT SURFACE LOCATION PROJECT NO NAD 27(FOR INFORMATION ONLY) c: NEERwG 6r4PFWG:SURVEVP rTESTRUG BOON NO X0.41 P4 SOP 441SOLOOTLI.41,VMS 7KE P107).16.13216 PAX (90 r�2L}32p} U"'°" PROTRACTED SEC. 13 T1 ON R12W SHEET : ■ `° ^ Erw� srwc, r,N, .SCGC°, II ill'lii'll:tla..k.t. I,I.0 { - 3 SEWARD MERIDIAN,ALASKA aJ • GP ST 24-13RD2 Drilling Procedure Rev 0 Hilcorp Ala.ka,1.1.0 33.0 Directional Program (wp08) Page 47 Revision 0 October, 2017 • • Hilcorp Alaska, LLC Granite Point Granite Point Platform Plan: GP-24-13RD2 GP 24-13RD2 Plan: GP 24-13RD2 wp08 Standard Proposal Report 02 October, 2017 HALLIBURTON! Sperry Drilling Services • • HALLIBURTON SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 8153.00 16.30 178.28 7893.83 -1643.83 842.92 0.00 0.00 1767.59 Start Dir 12.3°/100':8153'MD,7893.84'TVD:45°RT-F Sperry Drilling 2 8170.08 17.79 183.34 7910.16 -1648.83 842.84 12.30 45.00 1772.50 End Dir:8170.08'MD,7910.16'TVD 3 8190.08 17.79 183.34 7929.21 -1654.93 842.49 0.00 0.00 1778.44 Start Dir 4°/100':8190.08'MD,7929.21'TVD 4 8757.86 38.44 204.91 8428.45 -1904.85 762.04 4.00 36.30 2010.05 End Dir:8757.83'MD,8428.42'TVD 5 10461.20 38.44 204.91 9762.68 -2885.21 316.01 0.00 0.00 2875.71 Start Dir 5°/100':10461.29'MD,9762.74'TVD • 6 11256.79 62.00 161.81 10282.05 -3446.72 321.71 5.00 -70.54 3448.96 End Dir:11256.8'MD,10282.05'TVD 11-Hil c o r 7 11356.79 62.00 161.81 10329.00 -3530.60 349.27 0.00 0.00 3536.41 GP 24-13RD2 wp08 Tgt1 8 11366.79 82.00 161.81 10333.69 -3538.99 352.02 0.00 0.00 3545.15 Start Dir 5./100':11366.8'MD,10333.69'TVD 9 11626.18 74.97 161.81 10428.62 -3767.76 427.18 5.00 0.00 3783.64 End Dir:11626.18'MD,10428.62'TVD 10 13401.41 74.97 161.81 10889.00 -5396.60 962.32 0.00 0.00 5481.72 GP 24-13RD2 wp08 Tgt2 11 13501.40 74.97 161.81 10914.93 -5488.34 992.46 0.00 0.00 5577.36 GP 24-13RD2 wp08 BHL Total Depth:13501.4'MD,10914.93'TVD I Project: Granite Point WELL DETAILS: Plan:GP-24-13RD2 Site: Granite Point Platform Water Depth: 75.00 Plan: GP-24-13RD2 +N/-S +E/-W Northing Easting Latittude Longituce 0.00 Well: 0.00 2544538.84 263406.53 60°57'29.201 N 15?19'52.249 W Wellbore: GP 24-13RD2 DDI = 6.191 • Design: GP 24-13RD2 wp08 SURVEY PROGRAM Date:2017-10-02T0:00:0 Validated:Yes Version: CASING DETAILS Depth From Depth To Survey/Plan Tool 123.00 8153.00 GP 24-13RD CB-Gyro A1180G0087(GP-24-13) CB-Gyro-MS TVD TVDSS MD Size 8153.00 8420.00 GP 24-13RD2 wp08 MWD_InterpAzi+sag 10914.93 10785.93 13501.40 8 1/2"x 7" 8420.00 13501.40 GP 24-13RD2 wp08 MWD+SC+sag l�®® Start Dir 12.3°/100'18153'MD,7893.84'TVD:45°RT TF - 7500- --End Dir :8170.08'MD,7910.16'TVD _ _ __Start Dir 4°/100':8190.08'MD,7929.21'TVD 0 8250 8500 End Dir :8757.83'MD,8428.42'TVD �p;INIO 6500 80°6 9 M0 g762 18' 500 c - A612 O 1000 1000 u) - 90p0 ou�� cto501100•10 1026205 C� 3369,N0 1500 00 9000 1 10000 Skg' • -'tt 112y6a M0,1\3566 MO 102621\1 2000 2000 y - C5- 6500 EnaO �pK S°110 .• 6• 18 MO, 25p0 0 9750 10000' C6 ^^po0 o�Sta 0„-„011 •\107-Total Depth:13501.4'MD,10914.93'ND - 7 Sand .• ;,N o" - 300® - 10550 -,- $ o 3000-- 0 >10500- GP-24-13 Y0690 Icli h - 660GP-24-13RDGP 24-13RD2 wp08 Tgtledi 0.3 GP 24-13RD2 wp08 13 3/8"--,\g000 l' T GP 24-13RD2 wp08 t2" " 4000- p g c - 4500 11250- GP 24-13RD2 wp08 B aY2"x 7" - (.0 - 50p0 - 0 5000- - o - 55p0 12000- - -60p0 � - L1 I I I I I I f I i i i F111 I I I I I I I I I 1 I 1 1 i I I I I I 1 I I I I r I I o- 6000- 1500 2250113000 3750 4500 5250 6000 6750 7500 8250 o _ 6500 Vertical Section at 169.75° (1500 usft/in) Start Dir 12.3°/100':8153'MD,7893.84'TVD:45°RT TF C 7000 7000- 7600 End Dir :8170.08'MD,7910.16'TVD FORMATION TOP DETAILS m - -- 2 _Start Dir 4°/100':8190.08'MD,7929.21'TVD TVDPath TVDssPath MDPath Formation I- - 6p00"" _ --- ,NO 8995.00 8866.00 9481.15 Cl 8000- ,- p End Dir :8757.83'MD,8428.42'TVP 21 A 9011 00 8882.00 9501 57 C2 - 5 ____- MO'g76 •S OJO O 9595.00 9466.00 10247.14 C5 514.30 C6 _ 8500- -9000 10161 29 1026' 0333.- 10179.00 10050.00 119804.00 9675.00 1060.02 C7 Sand Top • ts•N 9000- 90p0 C 9500000 S�� n o�p0••11256 000113661 ‘,N0•10142' NA662�0 0 0 %o/t .1162 - 1000C5 � 0 0o S - ��a0\t 10000-- C6 ^^O A%, ,o-- o Total Depth:13501.4'MD,10914.93'ND Hilcerp Alaska,LLC 10560 _` ,- o 0 - - Calculation Method: Minimum Curva'ure GP-24-1310690 C7 Sand`Top Error System: ISCWSA ,7-GP 24-13RD2 wp08 Scan Method: Closest Approach 3D 11000- GP-24-13RDGP 24-13RD2 wp08 TOError Surface: Elliptical Conic Warning Method: Error Ratio GP 24-13RD2 wp08 Ty 1/2 x 7 REFERENCE INFORMATION GP 24-13RD2 wp08 BHL Co-ordinate(N/E)Reference:Well Plan:GP-24-13RD2,True North 12000- Vertical(TVD)Reference:GP 24-13RD2 @ 129.0usft Measured Depth Reference: GP 24-13RD2 @ 129.O0usft - Calculation Method: Minimum Curvature I I I I I I I I I I I I I I I 11 I I I 1 I I I 1 I I I I 1 mill T I F I I i 1 i 1 I I l I I I I F 1 I I 1 I I I I I F I I I 1 I I I I I I 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 '4000 Vertical Section at 169.75° (2000 usft/in) • • HALLIBURTON Project: Granite Point WELL DETAILS: Plan:GP-24-13RD2 Site: Granite Point Platform Water Depth: 75.00 Spor-ry Drilling Well: Plan: GP-24-13RD2 +N/-S +E/-W Northing Easting Latittude Longitude Wellbore: GP 24-13RD2 0.00 0.00 2544538.84 263406.53 60°57'29.201 N 151°19'52.249 W Plan: GP 24-13RD2 wp08 REFERENCE INFORMATION u[HiICOr]) Co-ordinate(N/E)Reference:Well Plan:GP-24-13RD2,True Nnrth Vertical(TVD)Reference:GP 24-13RD2(83 129.00usft r/ Measured Depth Reference:GP 24-13RD2(d 129.00usft Calculation Method:Minimum Curvature 900— CASING DETAILS TVD TVDSS MD Size Name 10914.93 10785.93 13501.40 7 8 1/2"x 7" 450— a 18 • :o 5 LS yo -450— ry So40 �'550 13 3/8" ' A'Soo -900— �4 050 50 9500 5159, Start Dir 12.3°/100':815T MD,7893.84TVD:45°RT TP , -1350— - End Dir:8170.08'MD,7910.16'TVD Start Dir 4°/100':8190.08'MD,7929.21TVD-_-, 1500 End Dir:8757.83'MD,8428.42'TVD 8000- 8000 -1800— -_-_ 6'2sp 8500 8s� 9000 e7so -2250— 9°00 cA - 9 lO�S CA'� . 2s0 d dpi O - 9 �p- rn -2700— S6b lJ Start Dir 5°/100':10461.29'MD,9762.74TVD 'S0 0 10000 -3150— End Dir:11256.8'MD,10282.05'TVD X0250 O Ilk _.GP 24-13RD2 wp08 Tgtl coo -3600— ---- Start Dir 50/100':11366.8'MD,10333.69TVD End Dir:11626.18'MD,10428.62'TVD -4050— 0500 -4500— _ -4950— x0-19 OP 24-13RD2 wp08 Tgt2 Total Depth:13501.4'MD,10914.93'TVD -- e1lR1 -.GP 24-13RD2 wp08 BH[. -5400— •h16 4`1\S 8 1!2"x 7" Ge 24-19th'w -5850— -6300— -6750— -2250 -1800 -1350 -900 -450 0 450 900 1350 1800 2250 2700 3150 3600 4050 West(-)/East(+)(900 usft/in) • • Halliburton HALLI B U RTO IV Standard Proposal Report „ �'®. •. Sperry EDM-NORTH US+CANADA tn--4 . `✓ ,''Well Plan:GP-24-13RD2 Hilcorp Alaska,LLCig, 1 e GP 24-13RD2 @ 129.00usft . Granite Point ifatitiO':' ,11141101t4;14-iltil GP 24-13RD2 @ 129.00usft a Granite Point Platform ti True Plan:GP-24-13RD2 Minimum Curvature ell o ' GP 24-13RD2 tj , Design:' GP 24-13RD2 wp08 '. Project Granite Point 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 Granite Point Platform Site Position: Northing: 2,544,544.00 usft Latitude: 60°5T 29.251 N From: Map Easting: 263,401.00 usft Longitude: 151°19'52.363 W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.16° .Well Plan:GP-24-13RD2,Leg3 SIot6 _. Well Position +14/-S 0.00 usft Northing: 2,544,538.84 usft Latitude: 60°57'29.201 N +E/-W 0.00 usft Easting: 263,406.53 usft Longitude: 151°19'52.249 W Position Uncertainty 0.00 usft Wellhead Elevation: 129.00 usft Water Depth: 75.00 usft ' Wellbore GP 24-13RD2 Magnetics Model Name am° ® r ® .# , _ { ''''.:,1-:',4410:3-A44.; . BGGM2017 10/2/2017 16.05 73.84 55,439 Design GP 24-13RD2 wp08 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,153.00 Vertical Section e '.Ariftifiri0PatIC.::::4:( 1'flItrOVitiirilittiAraariAtVa4,::::;tiNt.30-440CiiWireiNgrA:dt 077'''i;Ailt;Fat,f$:,,.4 0.00 0.00 0.00 169.75 Plan Sections Measured ' Vertical TVD a Depth Inclination Azimuth Depth System " +N/-S +E/-W =`:'` - x (usft) (1 (1 (usft) usft (usft) (usft) i� - �i e u. : 1N.. 8,153.00 16.30 178.28 7,893.83 7,764.83 -1,643.83 842.92 0.00 rt 0.00 0.00 F 0.00 m 8,170.08 17.79 183.34 7,910.16 7,781.16 -1,648.83 842.84 12.30 8.70 28.47 45.00 8,190.08 17.79 183.34 7,929.21 7,800.21 -1,654.93 842.49 0.00 0.00 0.00 0.00 8,757.86 38.44 204.91 8,428.45 8,299.45 -1,904.85 762.04 4.00 3.64 3.80 36.30 10,461.20 38.44 204.91 9,762.68 9,633.68 -2,865.21 316.01 0.00 0.00 0.00 0.00 11,256.79 62.00 161.81 10,282.05 10,153.05 -3,446.72 321.71 5.00 2.96 -5.42 -70.54 11,356.79 62.00 161.81 10,329.00 10,200.00 -3,530.60 349.27 0.00 0.00 0.00 0.00 11,366.79 62.00 161.81 10,333.69 10,204.69 -3,538.99 352.02 0.00 0.00 0.00 0.00 11,626.18 74.97 161.81 10,428.62 10,299.62 -3,767.76 427.18 5.00 5.00 0.00 0.00 13,401.41 74.97 161.81 10,889.00 10,760.00 -5,396.60 962.32 0.00 0.00 0.00 0.00 13,501.40 74.97 161.81 10,914.93 10,785.93 -5,488.34 992.46 0.00 0.00 0.00 0.00 10/2/2017 7:05:50PM Page 2 COMPASS 5000.1 Build 81D i 0 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference:j Well Plan:GP-24-13RD2 Company: Hilcorp Alaska,LLC TVD Reference: GP 24-13RD2 @ 129.00usft Project: Granite Point MD Reference: GP 24-13RD2 @ 129.00usft Site: t ,.=� Granite Point Platform North Reference: = True Well: Plan:GP-24-13RD2 Survey Calculation Method: Minimum Curvature Wellbore: 4 GP 24-13RD2 Design: GP 24 13RD2 wp08 Planned Survey Measured Vertical " 4iirMap ' I Map "' Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing`=• Easting s =Yert Section (usft) (°) (°) (usft) usft (usft)It (usft) (usft) (usft) e 0.00 0.00 0.00 0.00 -129.00 0.00 0.00 2,544,538.84 263,406.53 0.00 0.00 123.00 0.75 118.00 123.00 -6.00 -0.38 0.71 2,544,538.45 263,407.23 0.61 0.50 223.00 1.00 195.00 222.99 93.99 -1.53 1.06 2,544,537.29 263,407.56 1.11 1.69 323.00 2.25 247.00 322.95 193.95 -3.14 -0.97 2,544,535.72 263,405.49 1.81 2.92 423.00 4.00 186.00 422.82 293.82 -7.38 -3.14 2,544,531.53 263,403.24 3.51 6.70 523.00 5.50 184.00 522.47 393.47 -15.62 -3.84 2,544,523.30 263,402.37 1.51 14.69 616.00 5.96 177.45 615.01 486.01 -24.90 -3.94 2,544,514.03 263,402.09 0.86 23.80 18" 623.00 6.00 177.00 621.97 492.97 -25.63 -3.90 2,544,513.30 263,402.11 0.86 24.52 723.00 5.00 183.00 721.51 592.51 -35.20 -3.86 2,544,503.73 263,401.96 1.15 33.95 823.00 5.00 188.00 821.13 692.13 -43.86 -4.69 2,544,495.08 263,400.95 0.44 42.33 923.00 3.50 190.00 920.85 791.85 -51.19 -5.83 2,544,487.79 263,399.66 1.51 49.33 1,023.00 4.00 187.00 1,020.64 891.64 -57.65 -6.78 2,544,481.34 263,398.58 0.54 55.53 1,123.00 6.00 151.00 1,120.28 991.28 -65.69 -4.67 2,544,473.26 263,400.52 3.63 63.81 1,223.00 7.25 150.00 1,219.61 1,090.61 -75.73 1.02 2,544,463.11 263,406.01 1.26 74.70 1,323.00 8.25 158.00 1,318.70 1,189.70 -87.84 6.86 2,544,450.88 263,411.60 1.47 87.66 1,423.00 8.75 163.00 1,417.60 1,288.60 -101.77 11.77 2,544,436.86 263,416.23 0.89 102.24 1,523.00 10.25 158.00 1,516.23 1,387.23 -117.29 17.33 2,544,421.22 263,421.47 1.71 118.50 1,623.00 11.25 131.00 1,614.53 1,485.53 -131.95 28.03 2,544,406.35 263,431.87 5.09 134.83 1,723.00 11.75 133.00 1,712.52 1,583.52 -145.30 42.84 2,544,392.71 263,446.40 0.64 150.60 1,823.00 13.00 131.00 1,810.20 1,681.20 -159.62 58.77 2,544,378.07 263,462.05 1.32 167.53 1,923.00 14.25 136.00 1,907.39 1,778.39 -175.85 75.81 2,544,361.49 263,478.75 1.72 186.54 2,023.00 15.00 136.00 2,004.15 1,875.15 -194.02 93.35 2,544,342.98 263,495.92 0.75 207.53 2,123.00 15.75 140.00 2,100.57 1,971.57 -213.72 111.07 2,544,322.91 263,513.23 1.30 230.08 2,223.00 17.50 136.00 2,196.39 2,067.39 -234.94 130.24 2,544,301.31 263,531.96 2.09 254.36 2,323.00 19.00 140.00 2,291.36 2,162.36 -258.22 151.15 2,544,277.61 263,552.39 1.95 281.00 2,423.00 20.50 141.00 2,385.47 2,256.47 -284.30 172.63 2,544,251.10 263,573.34 1.54 310.49 2,523.00 21.00 141.00 2,478.99 2,349.99 -311.84 194.93 2,544,223.12 263,595.07 0.50 341.55 2,623.00 21.25 144.00 2,572.27 2,443.27 -340.42 216.86 2,544,194.09 263,616.42 1.11 373.58 2,723.00 21.00 142.00 2,665.55 2,536.55 -369.21 238.54 2,544,164.88 263,637.51 0.76 405.76 2,823.00 21.50 141.00 2,758.75 2,629.75 -397.57 261.11 2,544,136.07 263,659.49 0.62 437.68 2,923.00 19.50 141.00 2,852.41 2,723.41 -424.78 283.14 2,544,108.41 263,680.97 2.00 468.39 3,023.00 18.75 142.00 2,946.89 2,817.89 -450.42 303.54 2,544,082.37 263,700.85 0.82 497.24 3,123.00 17.25 140.00 3,042.00 2,913.00 -474.44 322.97 2,544,057.95 263,719.78 1.62 524.34 3,223.00 17.25 142.00 3,137.50 3,008.50 -497.49 341.63 2,544,034.54 263,737.97 0.59 550.34 3,323.00 16.50 145.00 3,233.20 3,104.20 -520.80 358.90 2,544,010.87 263,754.77 1.15 576.36 3,423.00 15.50 145.00 3,329.32 3,200.32 -543.38 374.71 2,543,987.98 263,770.11 1.00 601.39 3,523.00 15.00 140.00 3,425.80 3,296.80 -564.24 390.70 2,543,966.80 263,785.67 1.41 624.76 3,623.00 16.25 143.00 3,522.11 3,393.11 -585.33 407.43 2,543,945.38 263,801.98 1.49 648.49 3,723.00 18.25 140.00 3,617.61 3,488.61 -608.50 425.92 2,543,921.84 263,819.99 2.19 674.58 3,823.00 19.50 143.00 3,712.23 3,583.23 -633.83 446.03 2,543,896.11 263,839.58 1.58 703.08 3,923.00 18.50 142.00 3,806.78 3,677.78 -659.66 465.85 2,543,869.88 263,858.86 1.05 732.03 3,984.00 18.19 140.79 3,864.68 3,735.68 -674.66 477.82 2,543,854.63 263,870.53 0.80 748.92 13 3/8" 4,023.00 18 .00 140.00 3,901.75 3,772.75 -684.00 485.55 2,543,845.15 263,878.06 0.80 759.48 10/2/2017 7:05:50PM Page 3 COMPASS 5000.1 Build 810 1110 0 Halliburton IIALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:GP-24-13RD2 Company: .Hilcorp Alaska,LLC TVD Reference GP 24-13RD2 @ 129.00usft Project: Granite Point MD Reference: x GP 24-13RD2 @ 129.00usft Site: Granite Point Platform North Reference: True Well: Plan:GP-24-13RD2 Survey Calculation Method: Minimum Curvature Wellbore: ' `" - GP 24-13RD2 Design: GP 24-13RD2 wp08 :� : Planned Survey Measured Vertical II'' Map" Map Depth Inclination Azimuth Depth TVDss '� +N/-S gip +E/-W Northing . Easting DLS 'Vert Section (usft) (°)4. () (usft) "� "usft (usft) (usft) (usft) ` (usft) 3,867.86 4,123.00 18.00 141.00 3,996.86 3,867.86 -707.84 505.20 2,543,820.91 263,897.23 0.31 786.44 4,223.00 17.50 144.00 4,092.10 3,963.10 -732.01 523.76 2,543,796.37 263,915.29 1.04 813.53 4,323.00 16.75 145.00 4,187.66 4,058.66 -755.98 540.86 2,543,772.06 263,931.91 0.81 840.16 4,423.00 16.00 140.00 4,283.61 4,154.61 -778.34 557.99 2,543,749.35 263,948.57 1.60 865.21 4,523.00 16.50 143.00 4,379.62 4,250.62 -800.24 575.40 2,543,727.10 263,965.53 0.98 889.86 4,623.00 15.00 147.00 4,475.86 4,346.86 -822.44 590.99 2,543,704.60 263,980.67 1.85 914.48 4,723.00 15.00 147.00 4,572.46 4,443.46 -844.15 605.09 2,543,682.61 263,994.32 0.00 938.35 4,823.00 14.00 152.00 4,669.27 4,540.27 -865.68 617.82 2,543,660.82 264,006.61 1.60 961.80 4,923.00 14.50 153.00 4,766.20 4,637.20 -887.52 629.18 2,543,638.76 264,017.53 0.56 985.31 5,023.00 13.75 150.00 4,863.17 4,734.17 -908.96 640.80 2,543,617.08 264,028.71 1.05 1,008.48 5,123.00 13.75 153.00 4,960.31 4,831.31 -929.84 652.14 2,543,595.97 264,039.62 0.71 1,031.05 5,223.00 14.50 158.00 5,057.29 4,928.29 -952.04 662.23 2,543,573.58 264,049.26 1.43 1,054.69 5,323.00 14.50 156.00 5,154.10 5,025.10 -975.09 672.01 2,543,550.34 264,058.57 0.50 1,079.10 5,423.00 15.00 160.00 5,250.81 5,121.81 -998.68 681.53 2,543,526.55 264,067.60 1.13 1,104.02 5,523.00 15.50 164.00 5,347.29 5,218.29 -1,023.69 689.64 2,543,501.39 264,075.20 1.16 1,130.07 5,623.00 16.00 165.00 5,443.54 5,314.54 -1,049.85 696.89 2,543,475.09 264,081.92 0.57 1,157.10 5,723.00 16.00 166.00 5,539.66 5,410.66 -1,076.53 703.79 2,543,448.27 264,088.28 0.28 1,184.59 5,823.00 15.50 170.00 5,635.91 5,506.91 -1,103.06 709.44 2,543,421.63 264,093.39 1.20 1,211.70 5,923.00 15.50 167.00 5,732.28 5,603.28 -1,129.24 714.77 2,543,395.35 264,098.19 0.80 1,238.41 6,023.00 15.25 171.00 5,828.70 5,699.70 -1,155.25 719.83 2,543,369.25 264,102.72 1.09 1,264.91 6,123.00 14.75 170.00 5,925.29 5,796.29 -1,180.78 724.10 2,543,343.64 264,106.47 0.56 1,290.78 6,223.00 13.50 169.00 6,022.27 5,893.27 -1,204.78 728.54 2,543,319.56 264,110.42 1.27 1,315.19 6,323.00 12.50 174.00 6,119.71 5,990.71 -1,227.00 731.90 2,543,297.27 264,113.32 1.50 1,337.65 6,423.00 9.50 185.00 6,217.87 6,088.87 -1,245.99 732.31 2,543,278.28 264,113.35 3.65 1,356.41 6,523.00 9.50 169.00 6,316.52 6,187.52 -1,262.31 733.16 2,543,261.94 264,113.87 2.63 1,372.63 6,623.00 10.50 172.00 6,415.00 6,286.00 -1,279.44 736.01 2,543,244.77 264,116.37 1.13 1,389.99 6,723.00 10.50 180.00 6,513.33 6,384.33 -1,297.57 737.27 2,543,226.61 264,117.27 1.46 1,408.06 6,823.00 8.50 155.00 6,611.99 6,482.99 -1,313.39 740.40 2,543,210.73 264,120.07 4.54 1,424.18 6,923.00 9.50 148.00 6,710.76 6,581.76 -1,327.09 747.90 2,543,196.88 264,127.29 1.48 1,438.99 7,023.00 11.00 152.00 6,809.16 6,680.16 -1,342.51 756.75 2,543,181.28 264,135.82 1.66 1,455.74 7,123.00 15.00 155.00 6,906.58 6,777.58 -1,362.67 766.70 2,543,160.93 264,145.37 4.06 1,477.35 7,223.00 16.25 156.00 7,002.89 6,873.89 -1,387.18 777.86 2,543,136.19 264,156.03 1.28 1,503.46 7,323.00 16.50 161.00 7,098.83 6,969.83 -1,413.39 788.18 2,543,109.78 264,165.80 1.43 1,531.09 7,423.00 17.75 159.00 7,194.40 7,065.40 -1,441.05 798.26 2,543,081.92 264,175.33 1.38 1,560.10 7,523.00 17.50 159.00 7,289.71 7,160.71 -1,469.32 809.11 2,543,053.44 264,185.60 0.25 1,589.85 7,623.00 16.00 162.00 7,385.46 7,256.46 -1,496.47 818.76 2,543,026.11 264,194.70 1.73 1,618.28 7,723.00 16.50 165.00 7,481.47 7,352.47 -1,523.29 826.70 2,542,999.13 264,202.08 0.98 1,646.09 7,823.00 16.00 172.00 7,577.48 7,448.48 -1,550.66 832.29 2,542,971.65 264,207.12 2.02 1,674.01 7,923.00 16.50 169.00 7,673.49 7,544.49 -1,578.25 836.92 2,542,943.98 264,211.19 0.98 1,701.98 8,023.00 16.75 175.00 7,769.32 7,640.32 -1,606.54 840.88 2,542,915.61 264,214.58 1.73 1,730.53 8,123.00 16.75 178.00 7,865.07 7,736.07 -1,635.30 842.64 2,542,886.82 264,215.75 0.86 1,759.14 8,153.00 16.30 178.28 7,893.83 7,764.83 -1,643.83 842.92 2,542,878.29 264,215.85 1.53 1,767.59 Start Dir 12.3°/100':8153'MD,7893.83'TVD:45°RT TF 8,170.08 17.79 183.34 7,910.16 7,781.16 -1,648.83 842.84 2,542,873.29 264,215.68 12.30 1,772.50 End Dir :8170.08'MD,7910.16'TVD 10/2/2017 7:05:50PM Page 4 COMPASS 5000.1 Build 81D • • Halliburton HALLI B U RTO N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference:.1,.. Well Plan:GP-24-13RD2 Company: Hilcorp Alaska,LLC TVD Reference ior,_ GP 24-13RD2 @ 129.00usft Project: ., Granite Point MD Reference: GP 24-13RD2 @ 129.00usft Site: qGranite Point Platform North Reference. -.,,,' - ,..,,, True Well: Plan:GP-24-13RD2 Survey Calculation Method: Minimum Curvature Wellbore:' '-` GP 24-13RD2 Design: GP 24-13RD2 wp08 , 't` Planned Survey Measured Vertical Map Map -. „>...y, Depth Inclination Azimuth Depth TVDss r +N/-S +E/-W Northing.`' Easting DLS (usft) (°) (°) (usft) usft (usft) (usft) (usft) . y; (usft) 7,800.21 8,190.08 17.79 183.34 7,929.21 7,800.21 -1,654.93 842.49 2,542 867.20 264,215.20 0.00 1,778.44 , Start Dir 4°/100':8190.08'MD,7929.21'TVD 8,200.00 18.11 184.10 7,938.65 7,809.65 -1,657.98 842.29 2,542,864.15 264,214.94 4.00 1,781.40 8,300.00 21.49 190.46 8,032.73 7,903.73 -1,691.51 837.85 2,542,830.73 264,209.82 4.00 1,813.60 8,400.00 25.04 195.13 8,124.60 7,995.60 -1,729.96 829.00 2,542,792.46 264,200.19 4.00 1,849.87 8,500.00 28.70 198.69 8,213.79 8,084.79 -1,773.15 815.78 2,542,749.55 264,186.10 4.00 1,890.02 8,600.00 32.44 201.49 8,299.88 8,170.88 -1,820.87 798.26 2,542,702.19 264,167.61 4.00 1,933.86 8,700.00 36.23 203.77 8,382.45 8,253.45 -1,872.89 776.51 2,542,650.63 264,144.81 4.00 1,981.18 8,757.86 38.44 204.91 8,428.45 8,299.45 -1,904.85 762.04 2,542,618.97 264,129.69 4.00 2,010.05 End Dir :8757.86'MD,8428.45'TVD 1 8,800.00 38.44 204.91 8,461.46 8,332.46 -1,928.61 751.01 2,542,595.44 264,118.18 0.00 2,031.47 8,900.00 38.44 204.91 8,539.79 8,410.79 -1,984.99 724.82 2,542,539.61 264,090.85 0.00 2,082.29 9,000.00 38.44 204.91 8,618.12 8,489.12 -2,041.37 698.63 2,542,483.77 264,063.53 0.00 2,133.11 9,100.00 38.44 204.91 8,696.45 8,567.45 -2,097.75 672.45 2,542,427.94 264,036.21 0.00 2,183.93 9,200.00 38.44 204.91 8,774.78 8,645.78 -2,154.14 646.26 2,542,372.10 264,008.88 0.00 2,234.76 9,300.00 38.44 204.91 8,853.11 8,724.11 -2,210.52 620.08 2,542,316.27 263,981.56 0.00 2,285.58 9,400.00 38.44 204.91 8,931.44 8,802.44 -2,266.90 593.89 2,542,260.43 263,954.23 0.00 2,336.40 9,481.15 38.44 204.91 8,995.00 8,866.00 -2,312.65 572.64 2,542,215.12 263,932.06 0.00 2,377.64 Cl 9,500.00 38.44 204.91 9,009.77 8,880.77 -2,323.28 567.71 2,542,204.60 263,926.91 0.00 2,387.22 9,501.57 38.44 204.91 9,011.00 8,882.00 -2,324.16 567.30 2,542,203.72 263,926.48 0.00 2,388.02 C2 9,600.00 38.44 204.91 9,088.10 8,959.10 -2,379.66 541.52 2,542,148.76 263,899.59 0.00 2,438.04 9,700.00 38.44 204.91 9,166.43 9,037.43 -2,436.04 515.34 2,542,092.93 263,872.26 0.00 2,488.86 9,800.00 38.44 204.91 9,244.76 9,115.76 -2,492.42 489.15 2,542,037.09 263,844.94 0.00 2,539.68 9,900.00 38.44 204.91 9,323.09 9,194.09 -2,548.80 462.97 2,541,981.26 263,817.61 0.00 2,590.50 10,000.00 38.44 204.91 9,401.42 9,272.42 -2,605.18 436.78 2,541,925.42 263,790.29 0.00 2,641.32 10,100.00 38.44 204.91 9,479.75 9,350.75 -2,661.56 410.60 2,541,869.59 263,762.96 0.00 2,692.15 10,200.00 38.44 204.91 9,558.08 9,429.08 -2,717.94 384.41 2,541,813.75 263,735.64 0.00 2,742.97 10,247.14 38.44 204.91 9,595.00 9,466.00 -2,744.52 372.07 2,541,787.43 263,722.76 0.00 2,766.92 C5 10,300.00 38.44 204.91 9,636.41 9,507.41 -2,774.32 358.23 2.541,757.92 263,708.32 0.00 2,793.79 10,400.00 38.44 204.91 9,714.74 9,585.74 -2,830.70 332.04 2,541,702.08 263,680.99 0.00 2,844.61 10,461.20 38.44 204.91 9,762.67 9,633.67 -2,865.21 316.02 2,541,667.91 263,664.27 0.00 2,875.71 Start Dir 5°/100':10461.2'MD,9762.68'TVD 10,500.00 39.12 202.01 9,792.92 9,663.92 -2,887.49 306.35 2,541,645.82 263,654.15 5.00 2,895.92 10,514.30 39.39 200.97 9,804.00 9,675.00 -2,895.92 303.03 2,541,637.47 263,650.67 5.00 2,903.62 C6 10,600.00 41.19 194.95 9,869.39 9,740.39 -2,948.59 286.02 2,541,585.15 263,632.58 5.00 2,952.43 10,700.00 43.66 188.50 9,943.24 9,814.24 -3,014.58 272.41 2,541,519.45 263,617.64 5.00 3,014.95 10,800.00 46.45 182.64 10,013.91 9,884.91 -3,084.97 265.64 2,541,449.23 263,609.44 5.00 3,083.00 10,900.00 49.52 177.32 10,080.86 9,951.86 -3,159.20 265.75 2,541,375.00 263,608.05 5.00 3,156.07 11,000.00 52.81 172.48 10,143.58 10,014.58 -3,236.73 272.74 2,541,297.35 263,613.46 5.00 3,233.61 11,060.02 54.87 169.78 10,179.00 10,050.00 -3,284.60 280.22 2,541,249.34 263,619.97 5.00 3,282.04 C7 Sand Top 10/2/2017 7:05:50PM Page 5 COMPASS 5000.1 Build 81D 0 ! Halliburton 1-IALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference Well Plan:GP-24-13RD2 Company: Hilcorp Alaska,LLC TVD Reference: GP 24-13RD2 @ 129.00usft Project: Granite Point MD Reference: GP 24-13RD2 @ 129.O0usft Site: Granite Point Platform North Reference: - True Well: Plan:GP-24-13RD2 Survey Calculation Method: Minimum Curvature Wellbore: f, r GP 24-13RD2 Design: GP 24-13RD2wp08 • ,f.„ g Planned Survey Measured :- - Vertical . '� -'' Map Map Depth Inclination Azimuth Depth TVDss +N/-S T +E/-W Northing t Easting DLS (usft) (°) , O .m (usft) usft (usft) --- "(usft) : (usft) ,, .,.., (usft) 10 072.60 v ' A,-4+t-'1'' „..., 11,100.00 56.28 168.06 10,201.60 10,072.60 -3,316.96 286.56 2,541,216.86 263,625.65 5.00 3,315.02 11,200.00 59.89 163.99 10,254.47 10,125.47 -3,399.28 307.11 2,541,134.15 263,644.52 5.00 3,399.68 11,256.79 62.00 161.81 10,282.05 10,153.05 -3,446.72 321.71 2,541,086.42 263,658.15 5.00 3,448.96 End Dir :11256.79'MD,10282.05'TVD 11,300.00 62.00 161.81 10,302.34 10,173.34 -3,482.96 333.62 2,541,049.94 263,669.32 0.00 3,486.74 11,356.79 62.00 161.81 10,329.00 10,200.00 -3,530.60 349.27 2,541,002.00 263,684.00 0.00 3,536.41 11,366.79 62.00 161.81 10,333.69 10,204.69 -3,538.99 352.02 2,540,993.56 263,686.58 0.00 3,545.15 Start Dir 5°/100':11366.79'MD,10333.69'TVD 11,400.00 63.66 161.81 10,348.86 10,219.86 -3,567.06 361.25 2,540,965.31 263,695.23 5.00 3,574.41 11,500.00 68.66 161.81 10,389.26 10,260.26 -3,653.93 389.79 2,540,877.88 263,722.00 5.00 3,664.98 11,600.00 73.66 161.81 10,421.54 10,292.54 -3,743.82 419.32 2,540,787.42 263,749.70 5.00 3,758.68 11,626.18 74.97 161.81 10,428.62 10,299.62 -3,767.76 427.18 2,540,763.32 263,757.08 5.00 3,783.64 End Dir :11626.18'MD,10428.62'TVD 11,700.00 74.97 161.81 10,447.77 10,318.77 -3,835.49 449.44 2,540,695.15 263,777.95 0.00 3,854.26 11,800.00 74.97 161.81 10,473.70 10,344.70 -3,927.25 479.58 2,540,602.80 263,806.22 0.00 3,949.91 11,900.00 74.97 161.81 10,499.63 10,370.63 -4,019.00 509.73 2,540,510.46 263,834.50 0.00 4,045.56 12,000.00 74.97 161.81 10,525.57 10,396.57 -4,110.76 539.87 2,540,418.12 263,862.77 0.00 4,141.22 12,100.00 74.97 161.81 10,551.50 10,422.50 -4,202.51 570.01 2,540,325.77 263,891.05 0.00 4,236.87 12,200.00 74.97 161.81 10,577.43 10,448.43 -4,294.26 600.16 2,540,233.43 263,919.32 0.00 4,332.52 12,300.00 74.97 161.81 10,603.37 10,474.37 -4,386.02 630.30 2,540,141.09 263,947.59 0.00 4,428.18 12,400.00 74.97 161.81 10,629.30 10,500.30 -4,477.77 660.45 2,540,048.74 263,975.87 0.00 4,523.83 12,500.00 74.97 161.81 10,655.23 10,526.23 -4,569.52 690.59 2,539,956.40 264,004.14 0.00 4,619.48 12,600.00 74.97 161.81 10,681.17 10,552.17 -4,661.28 720.74 2,539,864.05 264,032.41 0.00 4,715.14 12,700.00 74.97 161.81 10,707.10 10,578.10 -4,753.03 750.88 2,539,771.71 264,060.69 0.00 4,810.79 12,800.00 74.97 161.81 10,733.03 10,604.03 -4,844.79 781.03 2,539,679.37 264,088.96 0.00 4,906.44 12,900.00 74.97 161.81 10,758.97 10,629.97 -4,936.54 811.17 2,539,587.02 264,117.23 0.00 5,002.10 13,000.00 74.97 161.81 10,784.90 10,655.90 -5,028.29 841.32 2,539,494.68 264,145.51 0.00 5,097.75 13,100.00 74.97 161.81 10,810.83 10,681.83 -5,120.05 871.46 2,539,402.33 264,173.78 0.00 5,193.41 13,200.00 74.97 161.81 10,836.77 10,707.77 -5,211.80 901.60 2,539,309.99 264,202.05 0.00 5,289.06 13,300.00 74.97 161.81 10,862.70 10,733.70 -5,303.56 931.75 2,539,217.65 264,230.33 0.00 5,384.71 13,401.41 74.97 161.81 10,889.00 10,760.00 -5,396.60 962.32 2,539,124.00 264,259.00 0.00 5,481.72 13,501.40 74.97 161.81 10,914.93 10,785.93 -5,488.34 992.46 2,539,031.67 264,287.27 0.00 5,577.36 Total Depth:13501.4'MD,10914.93'TVD 10/2/2017 7:05:50PM Page 6 COMPASS 5000.1 Build 810 • • Halliburton IIALLIBLIRTON Standard Proposal Report _Y Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference:z Well Plan:GP-24-13RD2 Company: Hilcorp Alaska,LLC TVD Reference: GP 24-13RD2 @ 129.00usft Project: Granite Point MD Reference: GP 24-13RD2 @ 129.00usft Site: Granite Point Platform North Reference: True Well: Plan:GP-24-13RD2 Survey Calculation Method:j Minimum Curvature Wellbore: ",GP 24-13RD2 Design: Illiaitlil :` `GP 24 13RD2 wp08 ", "` Targets ..,: Target Name „- -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-w Northing Easting -Shapeif„ x ( (°) (usft) .- (usft) (usft) - (usft) ' (usft) GP 24-13RD2 wp08 Tgt1 0.00 0.00 10,329.00 -3,530.60 349.27 2,541,002.00 263,684.00 -plan hits target center -Circle(radius 100.00) GP 24-13RD2 wp08 Tgt2 0.00 0.00 10,889.00 -5,396.60 962.32 2,539,124.00 264,259.00 -plan hits target center -Circle(radius 100.00) GP 24-13RD2 wp08 BHL 0.00 0.00 10,914.93 -5,488.36 992.46 2,539,031.65 264,287.27 -plan misses target center by 0.02usft at 13501.40usft MD(10914.93 TVD,-5488.34 N,992.46 E) -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth ,i , Diameter. Diameter ' (usft)YzNfitmlikk, (usft) 13,501.40 10,914.93 8 1/2"x 7" 7 8-1/2 I - Formations Measured Vertical ',1y.,` Vertical " DipT Depth Depth Depth SS v Dip Direction (usft) (usft) x =v : _ 9,481.15 8,995.00 Cl 0.00 9,501.57 9,011.00 C2 0.00 10,514.30 9,804.00 C6 0.00 10,247.14 9,595.00 C5 0.00 11,060.02 10,179.00 C7 Sand Top 0.00 Plan Annotations ; Measured Vertical Local Coordinates .X 'l _ ° Depth Depth +N/-S +E/-W`` (usft) (usft) (usft) (usft) u`- Comment 8,153.00 7,893.83 -1,643.83 842.92 Start Dir 12.3°/100':8153'MD,7893.83'TVD:45°RT TF 8,170.08 7,910.16 -1,648.83 842.84 End Dir :8170.08'MD,7910.16'TVD 8,190.08 7,929.21 -1,654.93 842.49 Start Dir 4°/100':8190.08'MD,7929.21'TVD 8,757.86 8,428.45 -1,904.85 762.04 End Dir :8757.86'MD,8428.45'TVD 10,461.20 9,762.67 -2,865.21 316.02 Start Dir 5°/100':10461.2'MD,9762.68'TVD 11,256.79 10,282.05 -3,446.72 321.71 End Dir :11256.79'MD,10282.05'TVD 11,366.79 10,333.69 -3,538.99 352.02 Start Dir 5°/100':11366.79'MD,10333.69'TVD 11,626.18 10,428.62 -3,767.76 427.18 End Dir :11626.18'MD,10428.62'TVD 13,501.40 10,914.93 -5,488.34 992.46 Total Depth:13501.4'MD,10914.93'TVD 10/2/2017 7:05:50PM Page 7 COMPASS 5000.1 Build 81D • • Hilcorp Alaska, LLC Granite Point Granite Point Platform Plan: GP-24-13RD2 GP 24-13RD2 GP 24-13RD2 wp08 Sperry Drilling Services Clearance Summary Anticollision Report 02 October,2017 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: Granite Point Platform•Plan:GP-24.13RD2•GP 24.13RD2•GP 24.13RD2 wp08 Well Coordinates: 2,544,538.84 N,263,406.53E(60°57'29.20"N,151°19'52.25"W) Datum Height: GP 24-13RD2 @ 129.00usft Scan Range:8,153.00 to 13,501.40 usft.Measured Depth. Scan Radius is 1,547.84 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build:810 Scan Type: Global Filte. Scan Type: 25.00 ,,- ,WINIMININEP R. 'M HALLIBURTON Sperry Drilling Services I • Hilcorp Alaska,LLC HALLI B U RTO N Granite Point Anticollision Report for Plan: GP-24-13RD2-GP 24-13RD2 wp08 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: Granite Point Platform-Plan:GP-24-13RD2-GP 24-13RD2-GP 24-13RD2 wp08 Scan Range: 8,153.00 to 13,501.40 usft.Measured Depth. Scan Radius is 1,547.84 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Granite Point Platform �..- ,, .a ,., GP-12-24-GP-12-24-GP-12-24 12,151.20 1,488.70 12151.20 1,163.60 11,345.85 4.839 Centre Distance Pass- GP-12-24-GP-12-24-GP-12-24 12,278.00 1,471.71 12,278.00 1,157.43 11,383.67 4.683 Ellipse Separation Pass- GP-12-24-GP-12-24-GP-12-24 12,528.00 1,510.56 12,528.00 1,179.64 11,450.26 4.565 Clearance Factor Pass- GP-32-13RD-GP-33-13-GP-33-13 8,153.00 1,001.76 8,153.00 816.33 7,992.10 5.403 Clearance Factor Pass- Plan:GP-24-13RD2-GP-24-13-GP-24-13 8,453.00 47.82 8,453.00 41.45 8,422.86 7.511 Clearance Factor Pass- Plan:GP-24-13RD2-GP-24-13RD-GP-24-13RD 8,453.00 47.82 8,453.00 41.43 8,423.86 7.488 Clearance Factor Pass- RIG:GP-11-24RD-GP-11-24-GP-11-24 10,703.00 1,052.75 10,703.00 800.96 10,396.52 4.181 Clearance Factor Pass- RIG:GP-11-24RD-GP-11-24-GP-11-24 10,722.08 1,052.55 10,722.08 800.87 10,409.17 4.182 Ellipse Separation Pass- RIG:GP-11-24RD-GP-11-24 PB1-GP-11-24 PBI 10,578.00 1,036.85 10,578.00 777.92 10,288.00 4.004 Clearance Factor Pass- RIG:GP-11-24RD-GP-11-24 PB1-GP-11-24 PBI 10,628.00 1,032.20 10,628.00 775.14 10,288.00 4.015 Ellipse Separation Pass- RIG:GP-11-24RD-GP-11-24 PB1-GP-11-24 PB1 10,665.64 1,031.14 10,665.64 775.82 10,288.00 4.039 Centre Distance Pass- RIG:GP-11-24RD-RIG:GP 11-24RD-GP 11-24RD W 10,478.00 407.21 10,478.00 255.56 10,478.72 2.685 Clearance Factor Pass- RIG:GP-11-24RD-RIG:GP 11-24RD-GP 11-24RD W 10,653.00 358.03 10,653.00 233.63 10,566.74 2.878 Ellipse Separation Pass- RIG:GP-11-24RD-RIG:GP 11-24RD-GP 11-24RD W 10,780.20 347.42 10,780.20 242.27 10,634.39 3.304 Centre Distance Pass- Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 123.00 8,153.00 CB-Gyro-MS 8,153.00 8,420.00 GP 24-13RD2 wp08 MWD_Interp Azi+sag 8,420.00 13,501.40 GP 24-13RD2 wp08 MWD+SC+sag 02 October,2017-18:18 Page 2 of 5 COMPASS • • Hilcorp Alaska,L I C HALLIBURTON Granite Punt Anticollision Report for Plan: GP-24-13RD2 -GP 24-13RD2 wp08 Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. t ber 2017- 18:18 P e 3 0f5 COMPASS 02 Oc oPage • 0 Hilcorp Alaska,LLC HALLI B U RTON Granite Point Anticollision Report for Plan: GP-24-13RD2 -GP 24-13RD2 wp08 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to GP 24-13RD2 @ 129.00usft.Northing and Fasting are relative to Plan:GP-24-13RD2. Coordinate System is US State Plane 1927(Enact solution),Alaska Zone 04. Central Meridian is-150,00°,Grid Convergence at Surface is: -1.16°. lar-22-1JKLAS,U1-,21-131U,t0E-21-1,5KU VU Ladder Plot GP-22-13RD3,GP-22-13RDPB1,GP-22-13RDPB1VU GP-22-13RD3,GP-22-13RD2,GP-22-13RD2 V0 T r r GP31-13,GP31-13,GP31-13V0 i ,%.1, /A GP31-31 -14,GP31-14V0 C i dGP-31-14RD2,GP31-14RD,GP31-14RDVO y 1350----1 A f_ GP31-31GP31-14R22,GP-31-14RD2 VO = GP31-23,GP31-23,GP-31-23 V0 O Yl to j GP32-13RD,GP32-13,GP32-13 VO - - GP32-13RD,GP32-13RD,GP32-13ROV0 O GP-32-13RD,GP-32-13RD PB1,GP32-13RDPB1 VO O __0 GP32-32 -13,GP33-13V0 a /' GP32-23,GP32-23,GP32-23V0 d GP32-23,GP32-23PB1,GP-332-23PB1 VO CO GP32-23,GP33-23,GP33-23V0 . GP33-33 -33-14,GP-33-14V0 C GP33-14RD,GP33-14RD,GP33-14RDV0 N o 4 i GP-42-23RD,GP-42-23,GP-42-23V0 lir GP-42-23RD,GP-42-23RD,GP-42-23RDVO LI GP-0411,GP-44-11,GP-44-11 VO ----- L GP-44-14,GP-44-14,GP-44-14 V0 CD U I ,. GP50,GP50,GP50V0 IGP51,GP51,GP51 VO GP52,GP-52,GP52V1) 0 2500 5000 7500 10000 12500 GP53,GP53,GP53V0 Measured Depth(2500 usft/in) GP-53,GP-53 PILOT,GP-53PLOTVO GP53,GP53PLOT PBI,GP53 PLOTPB1 VO 02 October.2017- 18:18 Page 4 of 5 COMPASS • • Hilcorp Alaska,LLC HALLI B U RTO N Granite Point Anticollision Report for Plan: GP-24-13RD2 -GP 24-13RD2 wp08 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor __...... ____...... ...._.__— - GP-22-13RD3,GP-22-13RD,GP-22-13RDV0 ..ill-GP-22-13RD3,GP-22-13RDPBI,GP-22-13RDPRIVO 10.00- ....... _. '.... - _.. .4.. GP-22-13R03,OP-22-13RD2,OP-22-13RD2V0 - GP31-13,GP31-13,GP-31-13V0 8.75— : L. -0-GP-31-14RD2,GP31-14,GP-31-14V0 ____.. ..______. ......_ -------- ..8..GP-31-14RD2,GP31-14RD,GP-31-14RDV0 _ - 40.GP31-14RD2,GP31-14RD2,GP3I-14RD2V0 7.50 ---- -.. -4-•GP31-23,GP-31-23,GP-31-23V0 GP32-13RD,GP32-13,GP32-13V0 o -$GP-32-13RD,GP32-32 -13RDVO N 6.25- A „ ■ _ _ $GP32-13RD,GP-32-13RDPB1,GP32-13RDPB1 VO o i - .....GP32-13RD,GP33-13,GP33-13V0 tL _ .. '/ A -)I(-GP-32-23,GP32-23,GP32-23V0 c 5.00 o \, m .\ - Z-GP32-23,GP32-23PB1,GP32-23PB1 VO c ,.g/i, 4-GP-32-23,GP-33-23,GP-33-23V0 m ♦-... -0-GP33-14RD,GP33-14,GP33-14V0 CD3.75- ._...__ ._.__...__ __._._. _.__-___ _ - _ - ... -- ---- - '-- GP -33 -14RD,GP33-33 4E GP-42-23RD,GP-42-23,GP-42-23V0 -♦GP-42-23RD,GP-42-23RD,GP-42-23RDV0 250 ._. - .. ..- - -- - - - 4 GP-14-11,GP-44-11,GP-44-11 V0 Collision Avoidance Req__ nar ---1 )-Zone-Stop Drilling _ GP-04-14,GP-04-14,GP-44-14 V0 GP-50,GP-50,GP-50V0 -9-GP51,GP51,GP51 V0 $-GP52,GP-52,GP52V0 0.00 a 11 i , i r i i i i -Q-GP-53,GP-53,GP-53V0 0 1250 2500 3750 5000 6250 7500 8750 10000 11250 12500 13750 15000 4 GP-53,GP-53 PLOT GP-53PLOTVO MeasuedDepth(2503usttln) $GP-53,GP-53PLOTPB1,GP53PLOTPBIVS 02 October,2017-18:18 Page 5 of 5 COMPASS \, \'11 .P-12-13 BHL \ \i / — — GP-51 BHL \ - r _GP_32-2 - - 'p •-5213FQ - __ GP-3 -13 BHL / Y 2 fip. rr �-- / / / GP-33-13 BHL ��\ �� l / / 1 / is. \ G�2-13RD3 PB1 BHL ^�` - - 4RD BHL ///1 / �p� / / / / = •\ GP-22-14T PB2 BHL GX in 1,GP-33-14 BHL /�// // 7- \\ ti \\ GP-44-14,$t L' L/ i \ \\ ♦-7 ,tiP-55QHL i �� \\\ \\\ / Ji / 1. �. \\ GP-22-13RD3�iLr-y \ GP-32-13RDPB BIS //// / / GP-24-13RI� :: .-24-13 •BHL • / / / ... r i�,� / 1 // / / 'VON—R1?M1 // / / ! I �� N. / / QP-11-24 •;r A i/ // —✓ 'r. -2 '11 BH : j 1 / 1 '-i� e GB-31-23 BHL / / y �� r // a x1-24RD aVL // '/ i, \ 1 ADL018761 �� ;e o O• �` // / // \ / S �/ / // O -/ / �// .01 Q ; GP-11-24RD PB BHL //f,P-32-23�I/1L,r_33-23 BHLB 1 1 X �r''r nesole 1 OQ V // 1 `11 v A / 1� O `a / GP-54PB BHr M I w "1 t �j l i g i I 1 CJD3 9® / 1 , s 1 I i 1 I 0 I 1 \% / i 1 I 1 1 I I 1 I I I I I I I / I )GP-54 BHL I • I h II II u 4GP-53 I I ' Legend 1 III1 Granite Point Platform I ME Granite Point Unit Boundary@DS ADL374045 1g @0 GP 12-24 Wellbore (idle injector) I 0 GP 11-24RD Wellbore 1 1 I o GP 24-13RD2 Wellbore P-53 BHL a----�1 GP 24-13RD2 1000ft buffer • • Bettis, Patricia K (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Monday, November 6, 2017 2:11 PM To: Bettis, Patricia K (DOA) Cc: Michael Schoetz; Kevin Tabler Subject: RE: GPS 24-13RD2 (PTD 217-143): Permit to Drill Application Good afternoon Patricia! The correct number or top production interval is 565' FSL, 1939' FWL,Sec 13,T1ON, R12W,SM,AK. It appears that the top that was included in the spacing exception is for the Tyonek C7,which is the interval we will perf. Let me know if you have any additional questions. Thank you for the help! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday, November 06, 2017 1:30 PM To: Monty Myers<mmyers@hilcorp.com> Subject:GPS 24-13RD2 (PTD 217-143): Permit to Drill Application Good afternoon Monty, On Form 10-401, Hilcorp states that the top production interval is 565 feet FSL and 1939 feet FWL Section 13,T1ON, R12W.S.M. On the spacing exception request, Hilcorp states that the top production intervals is 400 feet FNL and 1,654 feet FWL Section 24,T1ON-R12W, S.M Please verify which footage for top production interval is correct. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 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 1 • • Bettis, Patricia K (DOA) )3J/7 From: Colombie,Jody J (DOA) Sent: Friday, November 3, 2017 11:29 AM To: Seamount, Dan T (DOA); Foerster, Catherine P (DOA); French, Hollis (DOA); Ballantine, Tab A (LAW); Bettis, Patricia K(DOA) Subject: FW: Spacing Exception for GP 24-13RD2 Well Attachments: Application for Spacing Exception Granite Point 24-13RD2 Well 11_3_2017.pdf; GP 24-13RD2 Spacing Exception Exhibit A Zoom In.pdf From: Michael Schoetz [mailto:mschoetz@hilcorp.com] Sent: Friday, November 03, 2017 11:21 AM To:Carlisle, Samantha J (DOA)<samantha.carlisle@alaska.gov> Cc:Colombie,Jody J (DOA)<jody.colombie@alaska.gov>; Pike, Kevin W(DNR)<kevin.pike@alaska.gov>; Walsh, Chantal R (DNR) <chantal.walsh@alaska.gov>; Kevin Tabler<ktabler@hilcorp.com>; Cody Terrell<cterrell@hilcorp.com>; Matt Brown<mbrown@hilcorp.com>;Thomas Nenahlo<tnenahlo@hilcorp.com>; Corey Ramstad <cramstad@hilcorp.com>; Larry Greenstein <Igreenstein@hilcorp.com> Subject:Spacing Exception for GP 24-13RD2 Well Ms. Carlisle, Attached,please find a copy of Hilcorp's application for a spacing exception required to re-drill the Granite Point 24-13RD2 well, in the Middle Kenai Oil Pool. Hilcorp submitted to AOGCC,the Permit to Drill GP 24-13RD2 on October 3r1,2017,which is pending AOGCC approval. It is requested that the Commission approve, by Administrative Approval, pursuant to Rule 7 of Conservation Order No. 76, an exception to the well spacing for re-drilling the GP 24-13RD2 Well. A hard copy will by hand delivered to the AOGCC office today via courier. If you have any questions, please contact me at the number below. Thank you, Michael W. Schoetz Hilcorp Alaska,LLC Landman Office: (907)777-8414 Mobile: (281)-685-0902 Email: mschoetz(i hilcorp.com 3800 Centerpoint Dr.,Suite 1400 I Anchorage,Alaska 99503 Hilcorp Energy Company's new address is 1111 Travis, Houston, TX 77002. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, November 2, 2017 10:53 AM To: 'Monty Myers' Subject: RE: Granite Pt ST 24-13RD2 (PTD 217-143): Permit to Drill Application Thanks Monty, Actually I was wrong. The policy change took place in 2014. To comply with the existing spacing requirements specified by CO 76, Hilcorp must apply for a spacing exception for the drilling and completion of the proposed Granite Pt ST 24-13RD2 as soon as possible. A permit to drill will not be issued until a spacing exception is approved or the pool rules are amended to specify no spacing restrictions with respect to drilling unit boundaries and no interwell spacing restrictions. A 500 foot restriction will still apply to the exterior boundary of the pool. Patricia From: Monty Myers [mailto:mmyers@hilcorp.com] Sent:Thursday, November 2, 2017 10:37 AM To: Bettis, Patricia K (DOA)<patricia.bettis@alaska.gov> Cc:Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov> Subject: RE: Granite Pt ST 24-13RD2 (PTD 217-143): Permit to Drill Application Patricia, I am not sure what changed in 2015, but the permit to drill does not allow production from the well. However,the completion 10-403 sundry will include a request for perforating and completing the well and the request for the spacing exception. I am only requesting a 10-401, permission to drill a hole and put casing in the proper place. We will be requesting a public hearing for changes to the pool rules which will allow for unlimited spacing. Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday, November 02, 2017 9:27 AM To: Monty Myers<mmyers( hilcorp.com> Cc: Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov> Subject: RE: Granite Pt ST 24-13RD2 (PTD 217-143): Permit to Drill Application Monty, 1 • It has been AOGCC's policy to conduct business in this matter since 2015. If Hilcorp would like to present oral arguments at a public hearing, please submit a formal letter requesting a hearing. Patricia From: Monty Myers [mailto:mmyers@hilcorp.com] Sent:Thursday, November 2, 2017 9:02 AM To: Bettis, Patricia K (DOA)<patricia.bettis@alaska.gov> Cc:Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov> Subject: RE: Granite Pt ST 24-13RD2 (PTD 217-143): Permit to Drill Application Patricia, This doesn't seem to make sense with what we have been told in the past. Do you have time for a quick conference call this morning? Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Wednesday, November 01, 2017 2:54 PM To: Monty Myers<mmyers@hilcorp.com> Subject: RE: Granite Pt ST 24-13RD2 (PTD 217-143): Permit to Drill Application Monty, This is the same procedure as was done for GPS 22-13RD3. See Conservation Order 76.34 issued July 11, 2017. A permit to drill will not be issued until a spacing exception is approved. Patricia From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Wednesday, November 1, 2017 1:28 PM To: Bettis, Patricia K(DOA) <patricia.bettis@alaska.gov> Cc: Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov> Subject: RE: Granite Pt ST 24-13RD2 (PTD 217-143): Permit to Drill Application Patricia, Can we apply the spacing exception to the completion portion of the PTD only?They are submitted separately. In the past we have been able to drill, case and cement but not perforate and produce the well until the spacing exception has been filed and approved. The completion engineer typically applies the spacing exception to his sundry and not the drilling PTD. Please advise. Monty M Myers 2 • • Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Wednesday, November 01, 2017 12:02 PM To: Monty Myers<mmyersPhilcorp.com> Subject: Granite Pt ST 24-13RD2 (PTD 217-143): Permit to Drill Application Monty, Hilcorp needs to apply for a spacing exception for the drilling and completion of the proposed Granite Pt ST 24- 13RD2. A permit to drill will not be issued until a spacing exception is approved. Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage, AK 99501 Tel: (907)793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 3 Granite Point Platform n 0 PROPOSED • well:Granite Pt St#24-13RD Last Completed:Future PTD: 180-116 HammAAlaska.Li c API: 50-733-20080-01 R .q=1.2 Casing Detail: RKB to TBG Head= 38' SIZE WT GRADE CONN iD TOP BTM. 18" 70.59 B Ventura Surf 592' i Cl 13-3/8" 61.0 J-55 Butt.LT&C 12.515 Surf 3,960' L (t 9-5/8" 40&43.5 N-80&S-95 Butt.LT&C 8.755 Surf ±8322'(KW) 7" 29 N-80 Butt.LT&C 6.184 9,054' 10,640' Tubing Detail: /Z. A. , 3-112" 9.2 L-80 EUE 8rd 2.992 ±9,375' 9,379' F ", 3-1/2" 9.2 N-80 Buttress 2.992 9,379' 10,359' I ! S 1\-1a Jewelry Details No Depth Depth ID OD Item (MD) (ND) 1' 1 ±8,322' ±8,056' CIBP(set for whipstock) 1 _ ~ 2 _ 9,r( 379' 9,076' 2.97 HES No-Go Sub w/20'seal assy. 3 9,380' 9,077' 4.0 HES 7"23-323#BWD Permanent Packer ..4- 3B 9,379' 9,076' 2.97 HES Seal Assembly (9,379-9,400) t'. .'F" ,.sky . _. * fit." ., ,:e: 4 9,383' 9,080' 4.0 HES Seal-bore Extension (9,383-9,407) � -`'. . s�' ' ' t" . 5 9,407' 9,103' 4.408 HES Mill-out Extension (9,407-9A15) ..---',1.4-1:11111 *rif . 6 9,451' 9,145' 3.00 Baker G-22 Locator .- 7 9,452' 9,146' 4.00 Baker Model"FB-1"Ret.Prod.Pkr. =�, 2 Li 3,3B 7B 9,452' 9,146' 3.0 Baker 80-40 Seal Assembly(L=16.72) (9,452-9,469) A VI l - - g IN- 8 9,467' 9,160' 3-1/2"Camco MMGW Mandrel#1 W/Dummy valve. _ T I 9 9,690' 9,374' 3.00 Baker Model"G-22"Locator w/80-40 Seal Assy,16.43 Restriction In Tbg. rng @ 2359• tools 10 9,690' 9,374' Baker Model"FB-1"Ret.Prod.Pkr. >2.5°OD - _ 111 1 _ 11 9,693' 9,377' Millout Ext.w/5"8rd X 3-1/2"Butt.XO � 1 qi>6. `' 7 7B 12 9,720' 9,403' 3-1/2"Camco MMGW Mandrel#2 w/Dummy Valve 13 1U,1bS' r 9,829' 3.00 Baker Model"6-22"Locator w/80-40 Seal Assy,16.43 Ing 8 14 10,165' 9,829' Baker Model"FB-1"Ret.Prod.Pkr. C 2 15 10,168' 9,832' Millout Ext.w/5"8rd X 3-1/2"Butt.X0 16 10,217' 9,879' 3-1/2"Camco MMGW Mandrel#3 9 17 10,286' 9,946' 3-1/2"Camco MMGW Mandrel#4 - 18 10,358' 10,015' NA Bull Plug (btm 10,359') :► 1p 11 Perforated Tbg.on 11"' 12 Fill tagged 3/12/88 @ 10,123. Collapsed TBG tagged w/1.5"ID 9/9/88 9711'-9713.5' -..7.-= Fish:Two Ks BellySprings " ' 10 shots a 4spf D. -- C 5 p'ngs(3/8"x3 xl/16")3/16/88 @ 10,123;Dummy Valve lost 11/6/82 @ 10,300'; phase C 5 Dummy Valve W/0 Prong stuck in#2 Mandrel @ 9,720' Tagged collapsed tbg _ C6 4/1/88 a 10,106�� inn first tagged on 3/12/96 „ 13 PERFORATION DETAIL _ Top Ettm Top Btm Ili'.�1: � 14 _ Zone (MD) (MD) (TVD) (TVD) F f Date Status 15 9,505' 9,507' 9,196' 9,198' 2' 11/5/1980 Sqz Perfs f/Bond 16 9,548' 9,550' 9,238' 9,240' 2' 11/4/1980 Sqz Pens ft Bond 4 17 a•s _ 10,372' 10,374' 10,028' 10,030' 2' 11/4/1980 _Sqz Perfs f/Bond _ 10,418' 10,420' 10,073' 10,075' 2' 11/4/1980 Sqz Perfs f/Bond 18 _ C2 9,505' 9,550' 9,196' 9,240' 45' 11/10/1980 Open f/injection C7 C5 9,845' 9,917' 9,522' 9,591' 72' 11/10/1980 Open f/Injection - C5 9,944' 9,954' 9,617' 9,627' 10' 11/10/1980 Open f/Injection C6 10,060' 10,090' 9,728' 9,757' 30' 11/10/1980 Open f/Injection C7 10,330' 10,345' 9,968' 10,002' 15' 11/10/1980 Isolated due to fill in tbg. I C7 10,358' 10,374' 10,015' 10,030' 16' 11/10/1980 Isolated due to fill in tbg. ,/--- C7 10,400' 10,420' 10,055' 10,075' 20' 11/10/1980 _ Isolated due to fill in tbg. KB E L EY: = 105' C7 10,426' 10,436' 10,080' 10,090' 10' 11/10/1980 Isolated due to fill in tbg. PBTD = 10,588'TD = 10,640' C7 10,464' 10,480' 10,117' 10,132' 16' 11/10/1980 Isolated due to fillintbg. MAX HOLE ANGLE =21.25°Oa 2600' Updated by:111.3/15/17 Well Work Prognosis r 7-14* Well: GP 24-13rd Wimp nlxeka,LLC l Date: 04/07/2017 Well Name: GRANITE PT ST#24- API Number: S0-733-20080-0 13RD(GP 24-13rd) Current Status: Shut-In Injector Leg: Leg#3 Estimated Start Date: May 10, 2017 Rig: Moncla 404& Kuukpik#5 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 180-116 First Call Engineer: Dan Marlowe (907)283-1329 (0) (907)398-9904(M) Second Call Engineer: Monty Myers (907)777-8431(0) (907)538-1168(M) Current Bottom Hole Pressure: 3,635 psi @ 9,196'TVD 0.395 lbs/ft(7.60 ppg)based on SIBHP Maximum Expected BHP: 3,635 psi CO 9,196'TVD 0.395 lbs/ft(7.60 ppg)based on SIBHP Maximum Potential Surface Pressure: 2,715 psi Using 0.1 psi/ft gradient per 20AAC25.280(b)(4) Brief Well Summary GP-24-13rd is a shut-in C sands injector last worked over in October 1997. This workover will plug back the existing completion and prepare the well to sidetrack into the C-7. Last Casing Test: 03/17/2005 MITIA 9,157'to 2,289 psi Procedure: Phase 1. MIRU Moncla 404 2. RU e-line and RIH to+/-9,375'and punch tubing.Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/3,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. Attempt to un-sting seals. If no go,RU e-line and RIH to±9,375'and cyt..tubing. 6. Unseat hanger and POOH with completion. 7. RIH with bit and scraper to±9,050',circulate clean. POOH. 8. RIH with work-string and spot a balanced cement plug from±9,350 to±8,950 on top of the injection packer. (well will not take injection fluid) 9. POOH w/work-string 10. Pressure Test casing to 2,500 psig for 30 minutes and chart. 11. RU a-line and RIH w/CIBP to±8,322',±5'above casing connection.POOH 1. RIH with±2,000'of kill string 2. Set BPV, ND BOP, NU Dry Hole Tree and test. cNt 3. Suspend operations r w� 5' Gt'3P • • Well Work P • :nosis 111 Welt: GP -13rd Massa,Hikorp LLc Date: 04/ /2017 Phase II 1. Resume operations with Kuukpik#5 2. MIRU Kuukpik#5 11 3. Circulate well 4. ND Wellhead, NU BOP and test to 250psi low/3,500psi high.(Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 5. Monitor well to ensure it is static. 6. Circulate well and pull kill string 7. PU whipstock and mitts and RIH to CIBP. 8. Orient and set whipstock in 9-5/8". 9. Swap well to OBM drilling fluid. 10. Mill 8-1/2"window and 20'of new formation. POOH and LD mills. ***Remaining Procedure to be included on the Permit to Drill Sundry for the sidetrack*** General sequence of operations pertaining to drilling procedure: (informational only) 1. PU directional BHA and TIH to window. L... PTA aert. 5 f T 2. Drill 8-1/2" hole to the C-7 sands. 3. Run/Cement/and cleanout 7" casing. 4. Swap tot, Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue Anchorage,Alaska 99501 Re: THE APPLICATION OF Hilcorp ) Conservation Order No. 76.35 Alaska, LLC to drill and complete the ) Granite Point State 24-13RD2 development ) Granite Point State 24-13RD2 oil well within 1,000 feet of, and within the ) Granite Point Unit same governmental quarter section as,wells ) Granite Point Field that are, or may be capable of, producing ) Middle Kenai Oil Pool from the same pool. ) ) November 8, 2017 IT APPEARING THAT: By a letter received November 3,2017, Hilcorp Alaska, LLC (Hilcorp)requests an administrative approval under Conservation Order 76, Rule 7 to allow drilling and completion of the Granite Point State 24-13RD2 development oil well within 1,000 feet of, and within the same governmental quarter section as, wells that are, or may be capable of, producing from the same pool. FINDINGS: 1. Hilcorp is the operator of the Granite Point Field, Granite Point Unit and the proposed Granite Point State (GPS) 24-13RD2 development oil well to be located on the west side of the Cook Inlet, Kenai Peninsula Borough, Alaska. 2. The GPS 24-13RD2 well will be an offshore, deviated development oil well with a surface location of 2,392 feet from the south line and 1,376 feet from the east line of Section 13, Township 10 North,Range 12 West,Seward Meridian(S.M.). The top of the Middle Kenai producing interval location is 565 feet from the south line and 1,939 feet from the west line of Section 13,Township 10 North,Range 12 West, S.M.The bottom hole location is 2,599 feet from the north line and 2,363 feet from the west line of Section 24,Township 10 North, Range 12 West, S.M. 3. GPS 24-13RD2 well will be located entirely within State of Alaska Oil and Gas Lease ADL 18761. 4. GPS 24-13RD2 well will be completed within the Middle Kenai Oil Pool within an area governed by Conservation Order No. 76. 5. GPS 24-13RD2 will be the third well within the southwest quarter of Section 13 and northwest quarter of Section 24 open to, or capable of producing, from the Middle Kenai Oil Pool. 6. GPS 24-13RD2 will be within 1,000 feet to the GPS 11-24RD development well completed in the Middle Kenai Oil Pool. 7. Conservation Order 76, Rule 2. Spacing provides a. not more than two completed wells shall be allowed in any governmental quarter section; and b. no pay opened to the well bore shall be nearer than 500 feet to any property line nor nearer than 1,000 feet to any well drilling to or capable of producing from the same pool. ! • CO 76.35 November 8,2017 Page 2 of 2 8. Conservation Order 76, Rule 7. Administrative Approval specifies in part that the Alaska Oil and Gas Conservation Commission (AOGCC) "...may authorize the conversion or drilling of any well at any location...reasonably designed to further the purposes of the project." 9. The drilling and completion of GPS 24-13RD2 is designed to maximize recovery from the Middle Kenai Oil Pool at Granite Point Field by accessing un-drained reserves in discontinuous, lenticular oil reservoirs that cannot be reached by wells conforming to applicable spacing restrictions. 10. The potentially affected landowners, owners and operators within a 1,000 foot radius of the GPS 24-13RD2 well are Hilcorp and the State of Alaska, Department of Natural Resources (DNR). In conformance to Rule 7 of Conservation Order No. 76, Hilcorp gave notice of this request. On November 3, 2017, Hilcorp sent notice of its application to the DNR. The AOGCC received no objection regarding Hilcorp's request. CONCLUSIONS: 1. An exception to the well spacing provisions of Rule 2,CO 76 is necessary to allow drilling, completion, and production of the GPS 24-13RD2 development oil well to maximize recovery of reserves. 2. A spacing exception to allow drilling, completion, and production of the GPS 24-13RD2 development oil well is consistent with sound engineering and geoscience principles and will not result in waste or jeopardize correlative rights of adjoining or nearby owners. NOW THEREFORE IT IS ORDERED: Hilcorp's November 3, 2017 application for an order granting an exception to the well spacing requirements of Rule 2 of Conservation Order No. 76 to allow drilling,completion,and production of the GPS 24-13RD2 development oil well is approved. Hilcorp may proceed as long as it complies with the terms of the Granite Point Unit agreement, applicable Alaska laws,and all other legal requirements. �OlL yy„ DONE at Anchorage, Alaska and dated November 8, 2017. , //signature on file// //signature on file// //signature on file// 4011 Hollis French Daniel T. Seamount, Jr. Cathy P. Foerster �`4,aT,N o'"id - -4210N Commissioner Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b),"[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: �f ctJ— 13 ?,t 2, PTD: 02 ?--M3 14-Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: 6/ca✓1 I_ fit;at- POOL: TW1 r/. i 91 �'�. 1`4„„., �I Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 2/2015 • 0 ❑❑ cm , o ca- co D Y m, _`o , _, aa)); , Q , a) a m. , , ; ; , , ,, , , , , ami U la ° 5 . oo WI (Ln 3 ; ' a , , , , , , a a 73 > )n' Q, 0 ° �' E Q .13. E y. CO 0 D) Z' . o. Z' —, �, 0 0. > a a r, o' RI rn a, N' t, � n, , ° y -° d 0m, 8 CO c, W. N, w C. M•. X, w' y 0, �� 'y0 �, , rn , E, Op, m' N' , O) I- �. O p, y, a) Ty 0) mm •y (A3Co, , V, a ZC, u. , Ja) CC 20 El?' , O, 7, .N, C C y am °, Qy L • N , y .OO. W, , 4 .O, , , y, 13 y , 0, , O, -OmO y, a) O. r , • I- T.)' , d >, (1L ° . , 9, 2 Z o ,INI COO Q, a ; � L.0, o, io O, u, >> a) ac , E. 3Yo, , 0o 2, o ' °, .°, m . , a -o_ 33 a o °, ao , ;a N� NN C , , C. C0, , , N, (, 0N, ' a)VVN : VZ ood, cc, , X' >, , .' NQN, ' ' . . CN• , M � . N 'c'''N c , (5 N 'a; � ; NO3 ' X — ' y a �, , NE y l'• W. Of O O I— 7. a) v o 4, N o , o ` � . o oa o= N' Ca ' ,-- oZ Z N . _' � ' � a) 0 m ; N => o, ' yZ cE °, , o,. ' ' n •oc >, ao_ 0 � mg0ci aE , � c , V, , ^ . , Nx, u , 2, ca (f)' o. a) Z , 0 ; aaa V' Q' ya ° , _ , 1-' 9..) , O , a 7' Q, .E 7' N' NX' V W Q' C. 0 0 0 • (n Q UW w 0 i•-. CO I MZ 5 g, ° (0 i, I' W' , 0 i ax) co , , , , , ; ; , , , , .c DCO Q Q a), y, aa), OO, a), y, yO, O, a, QQQQ QQQa), a) a), a), yQy, a), a), oay, yy,, Qp. O, o, < < < CD O ZZ >- >- >- >- ZZ - - >- ZZZZZ ZZZZ - >- >- >- - Z - - >- ZZ >- Z Z Z , , , , , , }, }, , }, , >. im to 0. Ua, �ao c V _ C' , � O DE. XZ as , Cl) � °. � , )j ,Y t g o'CoW 0 i1III ' 0 'O) h aNL , ,, 0, O.oCp0DCNm, �y' a >_;' o,' �' ' d0,a' = Q. ' Cm , ' co . O 'O0 . H � c. O0 a. .. W In CO, > ; > v 4 N ' u! a) ,I- 5 =r)' ' C` , ) •E' m � ° C _ w F' t o °ts =" cu)' yw ° O r ' ooO , p �, _ ° 3 fla � o °, . 3, y �' �' T c.Z Q' v o � 4o' Ooyrn U' a a ), , aa , a) , g > 0, ogm ° a' ° c. E' o > > _0. vw a . o o' , y m, o' E, m iom' Q m. n' ao, o, o) ' y C c4 S Q(9 N, , a?aC. , maN, am a)' o, tt 'Oa )a) cs '°, -a m' .GL, N wM, cm, Nc, N, o al, o a 3' co >. 3 , _ � lik W •V 5. � Y C13 yvoO . a ' • a) o, y � y, 0'o o 0- .Oc. a � m y -O . > 2, m ` 0 , ° Q 0 co o', o t o@N , � N' y pN' ' Oa), E. OOy OO ..0' N 0, Oa -7 EN (0' E 2 4°) O ' a '.-' T to C) O , o NU y a 'O y y y y a CV tl a o ww -° y , v -p N' CO O . :: T CO' O'*5 D 4 y m a m mm o � o . °. ° ct v dao, mE C, g E. 4 m, .N m, . `- -CT T . I, win2 o C) w, NC . a a yN. > N' > a) c, a) O` Q- L .5, N Il a f .fl — -O -O -O 0 • , Cy, .1:71 .D, LGD My y gLy - - . N� V , � p 0Q C y' E, ), a), y, y m, -o ° r C C y, 0 a), „, N. 0, 0, _ 2 o 8 . c E. N.. . c ' °' y' �ca c .- c u ° o o 0 00o y 5, o o, 6 i w.. g a) cU 8 ili lc cZ, 0, -JD �, � S' (1) 00a' a0 � a,, a 0co, 0, 00,, 0a �; da0mm' U _; yam' a 0, coui0' rho E N. O N M a U) (O a0 0) O N M A (O (O N. CO O) O N M (() (0 h 00 O) ° N M (p CO N. CO 0) r N N N N N N N N N N M M M CO co co co co co • Q N- N. 1� C .a)ce co o CIS a 0) 0 +y.'rci c) () W r COte00 C° ) ....• O' J ^ co a) Off)/ ) N 'C w 0 E a m C a -I o a °D F- Q Q a w Q C9 C7 Q d GP 24-13RD2 50-733-20080-02-00 Granite Point Field Kenai Peninsula Borough, Alaska November 8, 2017 – December 4, 2017 Provided by: Approved by: Corey Ramstad Compiled by: Allen Odegaard Josh Dubowski Distribution Date: December 14, 2017 GP 24-13RD2 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW .......................................................................................................... 2 1.1 Equipment Summary ..................................................................................................................................... 2 1.2 Crew ............................................................................................................................................................... 2 2 GENERAL WELL DETAILS .............................................................................................................................. 3 2.1 Well Objectives .............................................................................................................................................. 3 2.2 Hole Data ....................................................................................................................................................... 4 2.3 Daily Activity Summary .................................................................................................................................. 4 3 GEOLOGICAL DATA ......................................................................................................................................... 7 3.1 Lithostratigraphy ........................................................................................................................................... 7 3.2 Lithology Details ............................................................................................................................................ 8 3.3 Geological Sampling Program ...................................................................................................................... 16 4 Drilling Data ....................................................................................................................................................... 17 4.1 Surveys ......................................................................................................................................................... 17 4.1 Bit Record .................................................................................................................................................... 22 4.2 Mud Record ................................................................................................................................................. 23 4.3 Drilling Progress ........................................................................................................................................... 24 5 SHOW REPORTS ............................................................................................................................................ 25 6 DAILY REPORTS ............................................................................................................................................. 26 Enclosures 2” / 100’ Formation Log (MD/TVD) 5” / 100’ Formation Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) Final Data CD GP 24-13RD2 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Flame ionization total gas & chromatography. 0 hrs. -- Effective Circulating Density (ECD) Halliburton 0 hrs. — Hook Load / Weight on bit PASON 0 hrs. — Mud Flow In PASON 0 hrs. — Mud Flow Out PASON 0 hrs. — Mudlogging Unit Computer System HP Compaq Pentium 4 (X2, DML & Rigwatch) 0 hrs. — Pit Volumes, Pit Gain/Loss PASON 0 hrs. — Pump Pressure PASON 0 hrs. — Pump stroke counters PASON 0 hrs. — Rate of Penetration PASON 0 hrs. — RPM PASON 0 hrs. — 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML030 Logging Geologists Years1 Days2 Sample Catchers Years Days2 Allen Odegaard 20 20 Eric Andrews 5 9 Josh Dubowski 10 26 Jake Roberts 4 28 Garnet Knopp 1 9 Eli Callan 3 15 Dave Deatherage 35 8 *1 Years’ experience as Logging Geologist *2 Days at wellsite between rig up and rig down of logging unit. GP 24-13RD2 3 2 GENERAL WELL DETAILS 2.1 Well Objectives GP 24-13RD2 is an oil production well planned to be re-drilled in a South-Easterly direction from the existing GP 24-13 utilizing the existing casing program down to 8153’ MD / 7894’ TVD. At 8153’ MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Tyonek targets. A 4583’ x 8.5” open hole section is planned. A 7” 26# L-80 DWC/C prod liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 2-7/8” gas lift completion. The window was milled from 8130’ TOW to 8147’ BOW. Open hole was milled to 8167’ for FIT and an additional 10’ milled to 8177’ for tool clearance. The kickoff point was 8130 ’MD. TD was reached at 13,493’ MD. 7” liner was hung from the 9-5/8” casing at 5,821’ MD and run down to 10,893’ MD. 5” liner was hung from the 7” casing @ 10,449’ and run down to 13,023’ MD. Operator: HILCORP ALASKA, LLC Well Name: GP 24-13RD2 Field: Granite Point Field County: Kenai Peninsula Borough State: Alaska Company Representatives: Marvin Rogers, Rance Pederson Location: Surface Coordinates 2392' FNL, 1376' FW L, Sec. 13, T10N, R12W, SM, AK Mud Line Elevation 75’ Rotary Table Elevation 129’ RKB Classification: Development - Oil API #: 733-20080-02-00 Permit #: 217-143 Rig Name/Type: Kuukpik 5 / Arctic double Spud Date November 8, 2017 Total Depth Date: December 04, 2017 Total Depth 13,493’ MD / 10,712’ TVD Primary Targets Tyonek C1 – C7 Total Depth Formation: Tyonek C7 Completion Status: — LWD-MWD Services. Halliburton / Sperry Drilling Services Directional Drilling Halliburton / Sperry Drilling Services Drilling Fluids Service Halliburton / Baroid Wireline Logging Service — GP 24-13RD2 4 2.2 Hole Data Hole Section Max Depth TD Formation MW ppg Dev oinc Csg Dia Shoe Depth LOT ppg MD (ft) TVD (ft) MD (ft) TVD (ft) 8.5” Mill 8,177’ 7,916.95’ Tyonek 8.9 15.5 9.625” 8,130’ 7,872.74’ 12.5 8.5” 13,493’ 10,712.01’ Tyonek C-7 9.5 69.5 7” 10,893 10,107.4 n/a 8.5” 13,493’ 10,712.01’ Tyonek C-7 9.5 69.5 5” 13,023 10,729.5 n/a 2.3 Daily Activity Summary 8 Nov, 2017: Pick up BHA #2 and shallow pulse test. Trip in hole to 5315’, Run in hole to 8039’. Establish circulation and orient to 65R begin slacking off and tag CBP @ 8148’ set anchor with 15K down. WT tool face change to 53R. Set whipstock shear @ 35K down. Top of window @ 8130’. Drain Pits and prep for bringing on OBM. Displace well to OBM taking displacement returns to production. Change shaker screens and pick up single for milling window. Mill window from 8130’ to 8140’. 9 Nov, 2017: Mill window and rat hole from 8140’ to 8167’. Condition mud and perform FIT to 12.5 EMW. Finish drilling rat hole down to 8177’. Pump slug and pull out of the hole. Lay down milling BHA, Rig up and test geo span. Picking up Drilling BHA at report time. 10 Nov, 2017: Continue making up BHA #2, shallow test and load sources. Trip in hole to 2600’ and break in geo. Trip in hole to 8059’, slip and cut 130’ of drilling line, circulate and condition mud. Wash and ream to bottom and drill ahead until report time. 11 Nov, 2017: Continue drilling hole as per directional driller down to 9490’. Prep to short trip. 12 Nov, 2017: Circulate hole clean, monitor well (static), pump dry job and TOOH to 9086’. Wash and ream from 9086’ to 9056’ 40K overpull @ 9086’, 30K @ 9381’, TOOH on elevators to 8934’. Trip in hole to 9487’ and continue drilling 8.5” hole section as per directional driller to 9877’ where the decision was made to pull out of the hole and check the bit. 13 Nov, 2017: Rack back one stand, Kelly up, pump sweep and circulate hole clean. 25% increased cuttings when sweep came back. Monitor well (static) and begin pulling out of hole. Work through tight coal spots on elevators at 8065’. Pull out of hole and lay down BHA. Make up new BHA with MIRL, shallow test and begin tripping into the hole. 14 Nov, 2017: Trip in hole to 8074’, service drawworks/top drive. Trip in hole to 9622’, wash and ream down to 9887’. Pump high viscosity sweep and trip out of hole to 8511’ through tight coal spots. Pump slug and pull out to 4000’ and pulse test MWD (good). Pump slug and continue pulling out. Lay down agitator, rack back HWDP, jars and drill collars. Make up shock sub, drill collar, one stand of HWDP. Shallow test (good). Trip in hole to 4572’ and fill pipe and test MWD. Service rig. Continue tripping into hole at report time. 15 Nov, 2017: Continue tripping into the hole to 8180’. Slip and cut 113’ of drill line. Trip in to 9793’, wash and ream to bottom. Stage pumps up to drill rate, tag fill at 9880’. Wash and ream to bottom. Drill as per DD to 10298’ at report time. 16 Nov, 2017: Continue drilling 8.5” hole as per directional driller to 10661’. Service rig and obtain slow pump rates. Continue drilling to 10694’ at report time. GP 24-13RD2 5 17 Nov, 2017: Continue drilling to 11,032’ Pumped sweep and circulated bottoms up. Pulling out of hole for short trip currently. 18 Nov, 2017: Picked up out of hole for short trip to 9,846’. During rig service found a broken bracket on D/S E-Brake. Brake was repaired and tripped back in hole. Tight spots while TIH fired off 3 jars @ 30k. Reestablished circulation and washed and reamed the hole. Currently pumping sweep and circulating at 11,027’. 19 Nov, 2017: Circulate sweep out, 10bbls late with 10% increase. Drill ahead to 11096’ and perform a rig service. Continue drilling ahead to 11168’ and circulate bottoms up. Set back one stand of drill pipe, Kelly up and pump a sweep. Sweep back late by 20bbls with 50% increase in cuttings. Monitor well (static). Pull out of hole through tight spots that correlated with coals at 9120’ and 9076’. Monitor well (static). Continue pulling out of hole at report time. 20 Nov, 2017: Finish pulling out of the hole and lay down BHA. Pick up BHA #4 and shallow test MWD. Run in hole to 2923’ and fill pipe. Continue tripping into hole to 8081’. Cut and slip 97’ of drill line. Troubleshoot turning off ABG tool on MWD. R/U to test BOP’s and begin testing. 21 Nov, 2017: Finish testing BOP’s and lay down testing equipment. Test geo pilot (good). Trip into hole to 10625’, wash and ream to bottom. Pump sweep and drill ahead to 11181’. MP #1 liner flange bolt broke, repair pump while circulating on #2. Drill ahead 11240’ and get SPR’s. Troubleshoot pumps to reduce the noise for the MWD tools at report time. 22 Nov, 2017: Continue drilling down to 11402’. Circulate and reciprocate pipe while replacing fluid end in mud pump #1. Wait on boat with fluid end pod. Continue installing fluid end pod #1. Circulate and reciprocate pipe. Run mud pump #1 through bleeder. Test mud pump #1 with mud pump #2 at drilling rate. Drill down to 11426’. Re-torque bolts on mud pump #1 fluid end pod. Service drawworks. Continue drilling down to 11471’ at report time. 23 Nov, 2017: Continue drilling 8.5” hole as per DD. Troubleshoot brake and PLC issues and recheck torque on bolts for fluid end of MP #1. Continue drilling to 11718’. Obtain SPR’s, service rig and check torque on MP #1 fluid end bolts. 24 Nov, 2017: Continued drilling to 11,812’ MD when Geo Pilot quit responding. Circulated and pumped a sweep then picked up out of the hole. Pumped out of hole at 10,303’-8,112’ and washed through tight spots correlated with coals. Serviced the drawworks and traveling equipment. Observed well (Static) currently pulling out of hole at report time. 25 Nov, 2017: Continue POOH, unload sources, download MWD and lay down BHA #4. Pick up BHA #5 and shallow test (not pulsing). Troubleshoot MWD tools and determine pulser bad. Change out pulser and test (good). Trip in hole to 4170’ and fill pipe. Trip in hole to 8080’ and work boat. Slip and cut 81’ of drilling line. Service rig and change out 3” nipple on jumper hose. Continue tripping into hole at report time. 26 Nov, 2017: Continue tripping in hole, working through tight spots to 11741’. Wash and ream to bottom. Drill ahead with various parameters as to try and build angle to 11959’. Troubleshoot G-total and stick slip issues. Servicing drawworks, washpipe and HPUs at report time. 27 Nov, 2017: Continue drilling ahead and attempt to build angle to 12052’. Pick up and time drill at 1 FPH from 12050’-12055’ with minimal WOB. Inclination 73.22. Continue to time drill at 1 FPH from 12055’-12061’ with minimal WOB. Inclination 73.48 at report time. 28 Nov, 2017: Continue time drilling at 1 FPH to 12078’. Directional drill to 12180’ at report time. GP 24-13RD2 6 29 Nov, 2017: Continue drilling ahead to 12420’ as per directional driller. Service drawworks, top drive and check torque on mud pump fluid end pods at report time. 30 Nov, 2017: Continue drilling ahead to 12450’ but unable to desired azimuth turn. Pump high viscosity sweep and circulate hole clean. Pull out of hole to 11304’ then pump out until the shoe. Service drawworks, top drive and crown. Pump slug and pull out of the hole. Laying down BHA at report time. 1 Dec, 2017: Lay down BHA #5, M/U BHA #6 and shallow test (good). Run in hole to 8076’. Perform rig service. Trip into hole on elevators to 10655’. Wash and ream down through 10991’. Trip in on elevators from 10991’ to 12420’. Wash and ream to bottom. Drill ahead per directional driller to 12493’ @ report time. 2 Dec, 2017 Drilled from 12493’ to 12753’ as per directional driller. Continue drilling at report time. 3 Dec, 2017 Drilled from 12753’ to 13104’ as per directional driller. Service top drive, drawworks and repair bad 480 receptacle in MCC room. Continue drilling at report time. 4 Dec, 2017 Drilled from 13115' to TD at 13493', Circulate bottoms up, POOH to 13,204’, Spot 35BBL pill, POOH to 12,700’, pump sweep, circulate hole clean. 5 Dec, 2017 Circulate and condition mud; monitor well; POOH on elevators to 11,347’; pump out of hole to 9,835’ with 75 GPM; POOH with pumps 3 BPM 9,835’ – 8,122’; clean & clear rig floor; slip & cut drill line 135’, service rig and drawworks. Pump dry job, install stripping rubber, POOH from 8122’ to HWDP (L/D last 12 stands of DP coming out). Make up test plug and test joint. Drain stack and land test plug, bleed down entire accumulator system. Check bottles, C/O lower rams to 7”, fill system with water and purge air. Test BOP, AOGCC waive witness test gas alarms. Test all BOPE on 4 ½” test joint; bag, upper blinds, dart, TIW, upper/lower IBOP, all CMW, man/super choke, inside/outside mud cross valves, kill demco, koomey draw dawn. Start=3000 psi, closing=1500 psi, 200=24sec, final=116sec, 4 back up bottles 2500 psi avg. Lay down 4 ½” test joint, pick up 7” test joint. 6 Dec. 2017 Test 7” bag and lower rams; lay down 7” test joint; pick up and make up 2 7/8’ test joint; test 2 7/8’ bag, VBR’s, test flow and PVT. Lay down test joint, C/O all 4 air boots on stack. Stand back and lay down BHA components, unload Haliburton sources, download MWD. Lay down BHA as per DD/MWD. Clean and clear rig floor, pick up clean out BHA to 357’, RIH from 357’ to 8100’. Circulate and condition mud. TIH and wash through tight spots at 2.5 BPM/6o SPM at 10630’. Circulate and condition mud. RIH to 13000’, circulate and condition mud. GP 24-13RD2 7 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Tops picked by Hilcorp Geologist Corey Ramstad FORMATION PROGNOSED ACTUAL MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) KOP 8,153’ 7,894’ -7,765’ 8,130’ 7,872’ -7,743’ C1 9,480’ 8,955’ -8,826’ 9,254’ 8,950’ -8,821’ C1 Base N/A N/A N/A 9,342’ 8,950’ -8,821’ C2 9,501’ 9,011’ -8,882’ 9,542’ 9,116’ -8,987’ C2 Base N/A N/A N/A 9,600’ 9,164’ -9,035’ C5A 10,246’ 9,595’ -9,466’ 9,968’ 9,467’ -9,338’ C5A Base N/A N/A N/A 10,141’ 9,601’ -9,472’ C6 10,513’ 9,804’ -9,675’ 10,289’ 9,713’ -9,584’ C6 Base N/A N/A N/A 10,384’ 9,782’ -9,653’ C7A 11,059’ 10,179’ -10,050’ 10,873’ 10,096’ -9,967’ C7A Base N/A N/A N/A 10,925’ 10,126’ -9,997’ C7B N/A N/A N/A 10,966’ 10,150’ -10,021’ C7B Base N/A N/A N/A 11,199’ 10,271’ -10,142’ C7C N/A N/A N/A 11,220’ 10,281’ -10,152’ C7C (2) N/A N/A N/A 13,300’ 10,740’ -10,611’ C7B (2) N/A N/A N/A 13,440’ 10,721’ -10,592’ TD 13,501’ 10915’ -10,786’ 13,493’ 10,712’ -10,583’ *Note: the C3 and C4 are shaled out in this area of the field GP 24-13RD2 8 3.2 Lithology Details Lithology descriptions of all Kenai Group rock cuttings samples started immediately after drilling out the kick off point, then continued as per pre-set plans and procedures, and modified when directed by the Hilcorp operations geologist. The Kenai Group of Alaska’s Cook Inlet Basin, which includes the Sterling, Beluga, Tyonek, Hemlock and West Foreland Formations, was deposited by a variable-energy fluvial system within a large closed fore- arc basin. The characteristic sedimentary stratigraphy consists of dominant massive to thinly bedded sandstone and claystone-siltstone, generally abundant thin inter-beds of air fall and re-deposited volcanic ash, minor beds of basal or modal conglomerate and extensively-distributed thin beds of coal and carbonaceous rocks. Gradational upward-fining sequences and bi-modal distribution zones are abundant within sandstone sections. Note that in Canrig’s Lithology Descriptions, the special modifying term “tuffaceous” was created to address the pervasive presence and diversity of soft-sediment volcanogenic- origin rocks in the Cook Inlet area. Though generally applied to significantly ash-rich clay-silt-sand lithologies, its wide use in descriptions may include discernible micro-shard concentrations of disaggregated volcanic glass to vitric air fall volcanic ash to smectite-bentonite clays derived from devitrified ash to rare layers of vitric ignimbrite. Tuffaceous Claystone / Siltstone (8130' - 8200') = dark grayish black to dark gray with pale olive to brownish hues; moderate to poor induration; irregular shaped cuttings habit with PDC bit buttercurl cuttings common; silty to clayey texture; dull to earthy luster easily rehydrated; planar fracture; good cohesiveness; poor adhesiveness non-calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; no oil indicators. Tuffaceous Siltstone (8200' - 8290') = dark medium gray with blackish hues to dark brown with dark gray to black hues; moderate to good induration; tough to trace crumbly; planar to irregular to trace blocky fracture; platy to tabular to bit stacked cuttings habit; dull to earthy to greasy luster; silty to gritty texture; thick to thin and interbedded with thin claystones and minor amounts of carbonaceous shales and sand; non calcareous; semi hydrophilic; no hydrocarbon indicators observed. Tuffaceous Claystone / Sandstone (8290' - 8390') = dark blackish gray to dark brownish gray with black to pale yellow hues; tough to slightly brittle; good to moderate induration; planar to irregular fracture; platy to bit stacked cuttings; dull to earthy luster; silty to gritty texture; the sandstone are dark yellowish brown to dark medium grey with brown and black hues; easily friable to unconsolidated; lower medium to upper fine to lower medium; moderate sorting; sub rounded to sub spherical; matrix supported; non calcareous; dominated by clear to translucent quartz; carbonaceous banding semi common; minor dark lithics; no hydrocarbon indicators observed. Tuffaceous Claystone / Siltstone (8400' - 8470') = dark brown with pale yellow hues to dark brownish gray to medium dark gray; poor to slightly moderate induration; crumbly to brittle to trace semi tough; irregular to planar fracture; platy to bit stacked cuttings; dull to earthy to greasy luster; clayey to silty to slightly gritty texture; trace deformed carbonaceous banding; non calcareous; semi hydrophilic; moderate pale brownish gray siltstone; minor quartz rich sands; devitrified ash clumps common. Coal (8470' - 8500') = black with brownish black secondary hues; very firm to hard and brittle; wedge-like to platy and flak y; earthy luster; smooth to slightly silty texture; planar fracture dominant; bituminous to sub-bituminous. GP 24-13RD2 9 Tuffaceous Sandstone / Sand (8500'- 8590') = light medium gray with pale yellowish hues to medium brown with red to black hues; easily friable to unconsolidated; upper fine to upper medium to upper coarse and upper very fine; poor to moderate sorting; sub rounded to sub angular to angular; sub spherical to trace sub discoidal; grain supported; dominated by clear to translucent quartz with common dark lithics; minor carbonaceous shale sediment; ashy matrix; moderate reaction to HCl; minor siltstones and shales throughout; no hydrocarbon indicators observed. Tuffaceous Sandstone / Sand (8610'-8680') = light medium gray with pale yellowish hues to medium brown with red to black hues; moderately friable to firm to trace unconsolidated; upper fine to upper medium to upper coarse and upper very fine; poor to moderate sorting; sub rounded to sub angular to angular; sub spherical to trace sub discoidal; matrix to grain supported; moderate reaction to HCl; siltstone and claystones common; typically good induration and ranging from dark brownish black to dark reddish brown; no hydrocarbon indicators. Coal (8680' - 8720') = black with brownish black secondary hues; very firm to hard and brittle; wedge-like to platy and flaky; earthy luster; smooth to slightly silty texture; planar fracture; bituminous to sub- bituminous. Tuffaceous Claystone / Tuffaceous Siltstone (8720' - 8780') = medium gray to medium light gray with light gray hues; firm to crumbly; irregular shaped with PDC buttercurl common; silty to clayey texture; dull to earthy luster; easily rehydrated; very soft and mushy; good cohesiveness; poor adhesiveness; non- calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; no hydrocarbon indicators observed. Tuffaceous Sandstone / Sand (8780' - 8860') = light medium gray with pale yellowish hues to medium brown with red to black secondary hues; firm to moderately friable to friable to firm to unconsolidated; upper fine to upper medium to upper coarse and upper very fine; poor to moderate sorting; sub- rounded to sub-angular to angular; sub-spherical to trace sub-discoidal; matrix to grain supported; slight reaction to HCl; siltstone and claystones common; typically good induration; no hydro- carbon indicators. Coal (8860' - 8900') = black with brownish black secondary hues; very firm to hard and brittle, occasionally crumbly; wedge-like to platy and flaky; earthy luster; smooth to slightly silty texture; planar fracture; some bedding delineation; bituminous to sub-bituminous. Tuffaceous Claystone / Tuffaceous Siltstone (8900' - 8970') = medium gray to medium light gray with light gray hues; firm to crumbly; irregular shaped with PDC buttercurl common; silty to clayey texture; dull to earthy luster; easily rehydrated; very soft and mushy; good cohesiveness; poor adhesiveness; non- calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; contains about 10% - 20% white to off white ash; no hydrocarbon indicators. Tuffaceous Sandstone / Sand (8970' - 9050') = light medium gray with pale yellowish hues to medium brown with red to black secondary hues; firm to moderately friable to friable to firm to unconsolidated; upper fine to upper medium to upper coarse and upper very fine; poor to moderate sorting; sub- rounded to sub-angular to angular; sub- spherical to trace sub-discoidal; matrix to grain supported; matrix contains 10% or more of a white to off-white ash; or more of; very slightly calcareous; siltstone and claystones common; typically good induration; no hydro- carbon indicators. Coal (9050' - 9090') = black with brownish black secondary hues; very firm to hard and brittle, occasionally crumbly; wedge-like to platy and flaky; earthy luster; smooth to slightly silty texture; planar fracture; some bedding delineation; bituminous to sub-bituminous. Tuff (9090' - 9140') = white to off white to very light gray; very soft and mushy; dull luster; smooth to silty to gritty texture; nearly pure bentonite but commonly with ultrafine quartz and volcanic lithics; interbedded with claystone, siltstone and sandstone; no detectable oil indicators. GP 24-13RD2 10 Claystone / Tuffaceous Sandstone (9130' - 9230') = black with dark reddish hues to very dark brown with black and red hues; moderate induration; semi tough to crumbly; planar to irregular to trace earthy fracture; platy to bit stacked cuttings; dull to earthy; clayey to silty to gritty texture; trace carbonaceous banding; semi hydrophilic overall; the sandstones are pale gray with yellowish hues; firm to easily friable to minor unconsolidated; upper medium to lower fine with upper coarse to upper very fine common; moderate to poor sorting; sub angular to sub rounded; sub spherical to sub discoidal; grain supported by ashy matrix; no hydrocarbon indicators observed. Sandstone / Sand (9230' - 9310') = dark medium grayish brown to dark brown with red to yellow hues to trace grayish yellow clasts; firmly friable to easily friable to unconsolidated; lower medium to upper very fine with lower coarse to lower very fine common; poor to moderate sorting; sub rounded to sub angular; sub spherical to spherical to sub discoidal; grain supported with trace ash supported clasts; non calcareous; dominated by clear to translucent quartz; dark lithics and carbonaceous sediment common but not abundant; minor amounts of claystone and siltstone. Tuffaceous Sandstone / Claystone (9310' - 9410') = dark yellowish brown to medium brown with dark gray to black hues; moderate to easily friable to minor unconsolidated; lower medium to upper fine with lower fine to lower coarse common; moderate sorting; sub angular to sub rounded; sub spherical to sub discoidal; 50/50 grain and matrix supported; matrix composed primarily of devitrified ash; non calcareous; dominated by clear to translucent quartz; siltstones are typically dark blackish gray to dark grayish brown; moderate induration; irregular to planar fracture; planar to bit stacked cuttings; dull to earthy luster; silty texture; trace carbonaceous banding; minor shales. Tuffaceous Sandstone / Claystone (9410' - 9510') = dark brown with reddish yellow hues to dark medium brown with dark gray to black hues; moderate to easily friable to minor unconsolidated; lower medium to upper fine with upper very fine to lower coarse common; moderate sorting; sub angular to sub rounded; sub spherical to sub discoidal; contains both grain and matrix supported clasts; non calcareous; dominated by clear to translucent quartz. Coal (9510' - 9560') = black with brownish black secondary hues; very firm to hard and brittle, occasionally crumbly; wedge-like to platy and flaky; earthy luster; smooth to slightly silty texture; planar fracture; some bedding delineation observed; bituminous to sub- bituminous. Tuffaceous Sandstone / Sand (9560' - 9650') = very light yellowish brown to light gray and grayish white; firm friable to easily friable to unconsolidated; upper fine to lower coarse grained; trace to common upper coarse grains; poorly to moderately sorted; sub-angular to sub-rounded to rounded; sub-spherical to trace sub-discoidal; grain supported; dominated by clear to translucent quartz with common dark lithics; trace reaction to HCl; often interbedded with siltstones and claystones; no cut; no odor; no fluorescence or hydrocarbon indicators over oil based drilling fluid. Tuffaceous Siltstone / Claystone (9650'- 9720') = medium brown to light to medium gray to brown, occasionally with pale yellow to reddish hues; easily friable; unconsolidated; occasionally grading to a tuffaceous sandstone; claystones are dark blackish brown to dark brown with pale yellow and red hues; poor to moderate induration; semi-tough; planar to irregular to occasional conchoidal fracture; platy to tabular cuttings habit; very common PDC bit buttercurl cuttings; dull to earthy to greasy luster; no fluorescence or hydrocarbon indicators over oil based mud. Tuffaceous Sandstone / Claystone (9720' - 9810') = medium yellowish brown to very pale light grayish brown; friable to soft to minor unconsolidated; lower fine to upper medium with common lower coarse to upper very fine; poor to moderate sorting; sub rounded to sub angular; sub spherical; dominated by clear to translucent quartz; dark lithics and carbonaceous sediment common but not abundant; grain supported with an ashy matrix; dark brown to black claystones common; moderate induration planar to irregular fracture; platy to tabular cuttings habit; dull to earthy luster; silty to gritty texture; no hydrocarbon indicators observed. GP 24-13RD2 11 Tuffaceous Claystone / Sandstone (9810' - 9887') = dark black with dark brown hues to very dark brown with dusky red hues; moderate induration; planar to irregular fracture; platy cuttings habit; dull to earthy luster. Tuffaceous Siltstone / Claystone (9887'- 9990') = medium brown to light to medium gray to brown, occasionally with pale yellow to reddish hues; easily friable; unconsolidated; occasionally grading to a tuffaceous sandstone; claystones are dark blackish brown to dark brown with pale yellow and red hues; poor to moderate induration; semi-tough; planar to irregular to occasional conchoidal fracture; platy to tabular cuttings habit; very common PDC bit buttercurl cuttings; dull to earthy to greasy luster; dull yellow- white fluorescence due to oil based mud contamination; no cut; no odor; no hydrocarbon indicators over oil based mud. Tuffaceous Sandstone / Sand (9990' - 10090') = very light yellowish brown to light gray and grayish white; easily friable to unconsolidated; upper fine to lower coarse grained; poor to moderate sorting; sub- angular to sub-rounded to rounded; sub-spherical to trace sub- discoidal; grain supported; dominated by clear to translucent quartz with common dark lithics; trace reaction to HCl; often interbedded with siltstones and claystones; dull yellow sample fluorescence with occasional brighter patches which appear to be brighter and more uniform than background oil based mud contamination; instant dull yellowish white cut fluorescence; dark straw visible cut; dull yellow residual cut fluorescence; light brown residual cut; no odor. Tuffaceous Sandstone / Sand (10090' - 10210') = medium brown with dusky reddish to black hues; easily friable to unconsolidated; lower fine to upper medium with lower coarse and upper very fine semi common; poor to moderate sorting; sub angular to sub rounded to angular; sub spherical to sub discoidal; grain supported; dominated by clear to translucent quartz with common dark lithics and minor carbonaceous sediment; trace reaction to HCl; often interbedded with siltstones and claystones; trace patchy moderate yellowish gold sample fluorescence on <10% of sample; moderate streaming visible cut; pale brown to dark straw; moderate bluish white streaming cut fluorescence; dark straw visible cut; dull yellowish white residual cut fluorescence; light brown residual cut; no odor or visible staining. Tuffaceous Siltstone / Sandstone (10210' - 10270') = dark brown with blackish hues to very dark brown with dusky reddish hues; moderate to poor induration; soft to occasionally semi tough; irregular to planar to semi conchoidal fracture; tabular to platy to bit stacked cuttings; dull to slightly waxy luster; silty texture; moderately thick and interbedded with silt and sand; trace carbonaceous banding; no hydrocarbon indicators. Tuffaceous Sandstone / Sand (10280' - 10380') = dark brown with dusky reddish to black hues to blackish brown to trace pale yellowish brown; easily friable to unconsolidated; lower medium to upper coarse with upper coarse and lower fine common; trace 2-4mm bit broken quartz grains poor sorting; sub angular to sub rounded to angular; sub spherical to sub discoidal; grain supported; dominated by clear to translucent quartz with common dark lithics and minor carbonaceous sediment; dull yellowish gold overall fluorescence with <5% patchy moderate yellow fluorescence; very slow streaming visible cut; very pale brown; slow, weak bluish white streaming cut fluorescence; light brown residual cut; dull yellowish white residual cut fluorescence; no odor or visible staining. Tuffaceous Siltstone / Claystone (10380' - 10500') = dark brownish gray with blackish hues to pale yellowish brown to medium brown; crumbly to brittle to trace semi-tough; poor to moderate induration; planar to irregular to trace earthy fracture; platy to PDC buttercurl cuttings; dull to earthy; clayey to silty to gritty texture; predominantly non-calcareous with trace HCl reaction on some ash heavy clasts; semi- hydrophilic overall; dark blackish gray claystone; often grades to a moderately indurated shale; planar to slightly conchoidal fracture; dull to greasy luster; interbedded with minor tuffaceous sandstones and unconsolidated sands; no odor; no hydrocarbon indicators over oil based mud. GP 24-13RD2 12 Tuffaceous Siltstone / Claystone (10500' - 10590') = dark brown with dusky red hues to dark grayish brown with blackish hues; semi tough to soft to crumbly; moderate to poor induration; planar to irregular fracture; platy tabular to bit stacked cuttings; dull to earthy to slightly waxy luster; clayey to silty texture; predominantly non-calcareous with trace HCl reaction on some ash heavy clasts; slightly hydrophilic; dark grayish black claystone; typically grades to a moderately indurated shale; planar to conchoidal to trace irregular fracture; dull to waxy luster; minor carbonaceous banding; trace interbedded sands; no odor; no hydrocarbon indicators observed over background oil based mud. Tuffaceous Siltstone / Claystone (10590' - 10660') = dark grayish brown with black to dusky reddish hues to moderate brown with pale yellowish hues; semi tough to soft; moderate induration; planar to irregular fracture; platy tabular to bit stacked cuttings; dull to earthy to slightly waxy luster; clayey to silty texture; minor carbonaceous banding; trace interbedded sands; no odor; no hydrocarbon indicators observed over background oil based mud. Coal (10660' - 10730') = dark brownish black to matte black; sub bituminous to bituminous; brittle to crumbly; hackly to splintery to trace semi conchoidal; irregular to wedge-like to platy cuttings habit; earthy to slightly resinous and waxy; matte texture; semi thick and interbedded with silt, clay and sandstones; visible off gassing. Tuffaceous Siltstone (10730' - 10790') = overall olive gray, trace light gray; mushy, amorphous to stiff; dull luster; very finely silty/grainy texture; no evident structure; dominant argillaceous with only trace bentonitic; grades strongly to tuffaceous claystone, rarely to tuffaceous sandstone; any hydro- carbon indicators masked by oil based drilling fluid contamination. Tuffaceous Claystone (10790' - 10830') = overall olive gray; soft and mushy; amorphous cuttings; dull luster; very finely grainy texture to slightly smooth texture; grades evenly to tuffaceous siltstone; any hydrocarbon indicators masked by oil based drilling fluid. Coal (10830' - 10880') = dark brownish black to matte black; sub-bituminous to bituminous; brittle to crumbly; hackly to splintery to trace semi-conchoidal to conchoidal fracture; irregular to wedge-like to platy cuttings habit; earthy to slightly resinous and waxy; matte texture; semi-thick and inter- bedded with siltstones, claystones and sandstones; trace visible off gassing. Tuffaceous Claystone / Siltstone (10880' - 10970') = dark grayish brown with blackish hues to dark brown with dusky red hues; typically grades to a moderately indurated shale; planar to conchoidal to trace irregular fracture; dull to waxy luster; slightly hydrophilic; minor carbonaceous banding; the siltstones are typically semi tough to crumbly; moderate to poor induration; planar to irregular fracture; platy to tabular to occasional bit stacked cuttings; dull to waxy luster; clayey to silty texture; interbedded sands are common but not abundant; no odor; no hydrocarbon indicators observed over background oil based mud. Tuffaceous Sandstone / Sand (10970' - 11035') = dark yellowish brown to medium brown with dusky reddish hues; unconsolidated to soft to trace firm; upper medium lower fine with lower coarse to upper very fine common; moderate to poor sorting; sub rounded to rounded to sub angular; sub discoidal to sub spherical; dominated by clear to translucent quartz; dark lithics and carbonaceous sediment common; grain supported; very dull yellowish gold sample fluorescence; very slow pale bluish white streaming cut; weak greenish yellow residual cut fluorescence; very pale brown residual cut; no odor; no free oil. Tuffaceous Sandstone / Sand (11035' - 11170') = dark yellowish brown to medium brown with dusky reddish hues; unconsolidated to soft to firm to hard; upper very fine to medium lower fine with lower coarse common; moderately to poorly sorted; rounded to sub-rounded to sub -angular; sub-discoidal to sub- spherical; dominated by clear to trans- lucent quartz; dark lithics and carbonaceous sediment common; grain supported; very dull yellowish gold sample fluorescence; very slow pale blue-white streaming cut; weak yellow white residual cut fluorescence; very pale brown residual cut; no visible oil staining; no odor. GP 24-13RD2 13 Tuffaceous Sandstone / Siltstone (11170' - 11350') = medium gray with brownish hues to dark medium gray; firm to friable to unconsolidated; upper medium lower fine; lower coarse to upper very fine common; moderate to poor sorting; sub rounded to rounded; sub discoidal to sub spherical; minor medium gray siltstone; well indurated; tough to dense; irregular fracture; tabular cuttings habit; minor carbonaceous banding; occasionally bentonitic and grading to tuffaceous sandstone; also commonly fining down medium to dark gray tuffaceous claystone; very dull yellowish gold sample fluorescence; very slow pale blue-white streaming cut; weak yellow white residual cut fluorescence; very pale brown residual cut; no visible oil staining; no odor. Tuffaceous Sandstone / Sand (11360' - 11450') = medium gray with brownish hues to medium gray with dusky yellow to red hues; unconsolidated to easily friable to minor firm; lower medium to lower fine; lower coarse to upper very fine common; moderate to poor sorting; sub rounded to sub angular to rounded; sub spherical to sub discoidal; grain supported; non calcareous; predominantly clear to translucent quartz; minor dark lithics and trace carbonaceous sediment; very weak yellowish gold sample fluorescence; clear to very pale amber cut; slow translucent bluish white cut fluorescence; very faint straw residual cut; very dull greenish yellow residual cut fluorescence; no free oil in sample. Tuffaceous Sandstone / Sand (11450' - 11560') = dark medium brown with dusky yellow to red hues to medium gray with brownish hues; easily friable to unconsolidated to minor firm; upper medium to upper fine; lower coarse to upper very fine common; moderate to poor sorting; sub rounded to sub angular to rounded; sub spherical to sub discoidal; grain supported; predominantly clear to translucent quartz; minor dark lithics and trace carbonaceous sediment; weak yellowish gold sample fluorescence; slow translucent pale bluish white cut fluorescence; clear to slightly very pale straw cut; very faint straw residual cut; very dull greenish yellow residual cut fluorescence; no oil; no odor. Tuffaceous Sandstone / Sand (11560' - 11670') = medium brown with grayish hues to dark medium brown with dusky red to pale yellow hues; unconsolidated to easily friable to trace firm; upper medium to upper fine; lower coarse to upper very fine common; moderate to poor sorting; sub rounded to sub angular to rounded; sub spherical to sub discoidal trace sub prismoidal; grain supported; predominantly clear to translucent quartz; minor dark lithics and carbonaceous sediment; weak yellowish gold sample fluorescence; slow translucent pale bluish white cut fluorescence; clear to slightly very pale straw cut; very faint straw residual cut; very dull greenish yellow residual cut fluorescence; no oil; no odor. Tuffaceous Sandstone / Sand (11680' - 11780') = medium brown with grayish hues to dark medium brown with dusky red to pale yellow hues; unconsolidated to easily friable; upper medium to upper fine; moderate to poor sorting; sub angular sub rounded to angular; sub spherical to sub discoidal; weak yellowish gold sample fluorescence with trace patchy on <5%; slow to moderate translucent bluish white cut fluorescence; pale brown visible cut; pale brown residual cut; moderate greenish yellow residual cut fluorescence; no oil; no odor. Tuffaceous Sandstone / Sand (11780' - 11920') = medium brown with grayish hues to dark medium brown with dusky red to pale yellow hues; unconsolidated to easily friable to friable to firm friable; upper medium to upper fine grained; moderate to poor sorting; subangular subrounded to angular; subspherical to subdiscoidal; patchy weak to moderate yellowish gold sample fluorescence; slow to moderate translucent bluish white cut fluorescence; pale brown visible cut; pale brown residual cut; moderate yellow-white residual cut fluorescence; oil staining visible; no odor. Tuffaceous Sandstone / Sand (11920' - 11990') = dark medium brown with dusky red hues to medium brown with grayish hues; unconsolidated to easily friable; upper medium to upper fine; moderate to poor sorting; subangular to subrounded; subspherical to subdiscoidal; weak yellowish gold sample fluorescence with trace patchy on <5%; slow to moderate translucent bluish white cut fluorescence; very pale brown visible cut; very pale brown residual cut; moderate greenish yellow residual cut fluorescence; no oil; no odor. GP 24-13RD2 14 Sand / Tuffaceous Sandstone (11990' - 12090') = medium grayish brown to dark gray unconsolidated grains to semi-consolidated clusters rich in gray to smoky quartz with minor pink, black, and light blue lithics; lower fine to upper medium grained; poor to fair sorting; subrounded to subangular; low to moderate sphericity; dull to earthy luster; minor sugary texture; minor curved cuttings habit; very minor sample fluorescence; slow/weak bluish white cut fluorescence. Sand / Tuffaceous Sandstone (12090' - 12170') = dark medium brownish gray with dusky red hues to dark medium brown; unconsolidated to easily friable; lower fine to upper medium grained; poor to fair sorting; subrounded to subangular; subspherical to subdiscoidal; predominantly clear to translucent with minor dark lithics; grain supported; very weak yellowish gold sample fluorescence; slow transparent pale bluish white cut fluorescence; pale brown visible cut; dull greenish yellow residual fluorescence; no odor; no free oil. Tuffaceous Sandstone / Sand (12170' - 12270') = medium brownish gray to olive gray unconsolidated grains and semi-consolidated clusters; mostly clear to smoky blue/gray quartz with abundant blue, pink, and black lithics and some angular granules of laminated tan/olive green tuffaceous siltstone; upper fine to lower coarse grained; fair sorting; subrounded to subangular; dull to earthy luster and occasionally sparkling; weak yellowish sample fluorescence; moderate bluish white cut fluorescence; brown visible cut; no free oil; no odor. Sand / Tuffaceous Sandstone (12270' - 12350') = medium brownish gray to dark olive gray with greenish hues; unconsolidated grains and clumpy easily friable clusters; mostly clear to light gray quartz with lesser black and tan lithics; minor angular curved fragments of laminated tuffaceous siltstone; lower fine to lower coarse grained; fair sorting; subangular to subrounded; dull to frosted luster; medium bluish white cut fluorescence and streaming fluorescence; pale brown visible cut. Sand / Tuffaceous Sandstone (12350' - 12430') = dark medium brown with dusky red hues to dark medium brownish gray; unconsolidated to easily friable to trace firm; lower fine to lower medium grained; moderate to poor sorting; sub rounded to sub angular; sub spherical; predominantly clear to translucent quartz grains with minor dark lithics; grain supported; very weak yellowish gold to dark orange sample fluorescence; slow transparent pale bluish white cut fluorescence; pale brown visible cut; dull greenish yellow residual fluorescence; very pale brown residual cut; no free oil; no odor. Sand / Tuffaceous Sandstone (12430' - 12530') = medium brown with dusky red hues to medium brownish gray with blackish hues; unconsolidated to easily friable; upper fine to lower medium; moderate to poor sorting; sub rounded to sub angular to rounded; sub spherical to sub discoidal; clear to translucent quartz grains; grain supported; very weak yellowish gold to dark orange sample fluorescence; slow transparent pale bluish white cut fluorescence; pale brown visible cut; dull goldish yellow residual fluorescence; very pale brown residual cut; no free oil; no odor. Tuffaceous Sandstone (12530' - 12630') = light olive gray to medium brownish gray granule-sized firmly friable clusters and lesser unconsolidated grains; mostly grain-supported with minor clayey cement; dominantly smoky-blue translucent to white quartz with minor black, blue, and light brown lithics; upper fine to lower very coarse grained with a few conglomerate grains; poor to fair sorting; subangular to subrounded; moderate sphericity; dull but sometimes sparkling luster; occasional subangular bit-curl granules of laminated tuffaceous siltstone; weak to moderate yellow/gold sample fluorescence; moderate bluish-white cut and streaming fluorescence; light brown visible cut; moderate blue-white residual fluorescence; pale brown residual cut. Sand / Tuffaceous Sandstone (12630' - 12740') = dark medium grayish brown with dusky red hues to medium brown with blackish hues; unconsolidated to easily friable; lower medium to upper fine; trace bit broken quartz grains; moderate to poor sorting; sub rounded to sub angular to rounded; sub spherical to sub discoidal; clear to translucent quartz grains; grain supported; minor dense medium gray siltstone; well GP 24-13RD2 15 indurated; irregular to trace planar fracture; m oderate green-gold grain fluorescence on ~30% of sample; very dull yellowish gold fluorescence overall; slow to moderate translucent bluish white cut fluorescence; pale brown visible cut; dull greenish gold residual fluorescence; very pale brown residual. Tuffaceous Sandstone / Sand (12740' - 12850') = medium olive gray to dark brownish gray semi- consolidated clusters and unconsolidated grains; abundant clear to smoky blue-gray quartz with lesser black and tan lithics and minor white ashy fragments; varying between grain-supported and clayey matrix- supported; upper fine to lower coarse grained; fair sorting; subrounded to subangular; massive to platy cuttings habit; varying weak yellow/gold sample fluorescence; moderate to bright blue/ white cut fluorescence with some streaming fluorescence; medium brown visible cut; moderate gold-white residual fluorescence, pale brown residual cut ring. Tuffaceous Sandstone / Sandstone (12850' - 12950') = medium gray to medium olive brown granule sized firmly friable clusters and unconsolidated grains; clear to translucent blue-gray quartz abundant with lesser black and tan lithics, orthoclase, and subangular siltstone particles; mostly grain-supported with varying clayey matrix; upper fine to upper medium grained; fair sorting; subrounded; massive to platy cuttings habit; weak to moderate yellow sample fluorescence; moderate to bright blue-white cut fluorescence with medium to fast streaming fluorescence, brown visible cut; pale gold-white residual fluorescence; pale brown cut ring; no odor. Sand / Tuffaceous Sandstone (12950' - 13060') = dark medium brown with dusky red hues to medium brown with black to dark gray hues; unconsolidated to easily friable; upper fine to lower medium with upper medium to upper very fine semi common; trace bit broken quartz grains; moderate to poor sorting; sub rounded to sub angular to rounded; sub spherical to sub discoidal; clear to translucent quartz grains; grain supported; minor dense medium to dark medium gray siltstone; well indurated; irregular to trace planar fracture; deformed carbonaceous banding common; trace very pale yellow-gold sample fluorescence to no fluorescence; very slow transparent white cut fluorescence; very pale brown to clear visible cut; dull greenish gold residual fluorescence; very pale brown to clear residual cut; no free oil; no odor. Sand / Tuffaceous Sandstone (13060' - 13150') = medium brown with dusky red to black hues to dark medium brown with grayish hues; unconsolidated to easily friable; upper medium to lower fine and trace lower coarse; trace bit broken quartz grains; moderate sorting; sub rounded to sub angular; sub spherical to sub discoidal; clear to translucent quartz grains; grain supported; trace very pale yellow-gold sample fluorescence; very slow transparent white cut fluorescence; very pale brown to clear visible cut; dull greenish gold residual fluorescence; very pale brown to clear residual cut; no free oil; no odor. Tuffaceous Sandstone / Sand (13150' - (13260') = medium olive gray to dark brownish gray granule sized friable subrounded clusters and unconsolidated grains; dominant in clear to translucent blue/gray quartz with lesser black lithics and pink feldspars; mostly grain supported with minor varying clayey matrix; lower fine to lower coarse grained; fair sorting; subangular to rounded; moderate sphericity; nodular to platy cuttings habit; trace to minor pale gold sample fluorescence possibly influenced by obm; slow transparent white cut fluorescence and very minor streaming fluorescence; pale brown visible cut; very pale gold residual fluorescence; minor pale brown cut ring; no odor. Tuffaceous Sandstone / Tuffaceous Siltstone (13260' - 13350') = light brownish gray to medium gray semi-consolidated granular clusters and unconsolidated sand grains; mostly quartz with lesser black and tan lithics and pink feldspars; varying clay matrix content; fine to lower coarse grained; fair sorting; subangular to subrounded; grades downward into 50/50 mix of sandstone and gray angular laminated wedge like fragments of tuffaceous siltstone and claystone; very weak sample fluorescence; slow white cut fluorescence and some streaming fluorescence; very pale brown visible cut; very pale brown residual cut ring on the more sand-dominated portions of the depth interval. GP 24-13RD2 16 Tuffaceous Sandstone / Tuffaceous Siltstone (13350' - 13410') = medium gray to medium brown granular clusters and unconsolidated grains; quartz dominant with lesser black lithics and minor pink feldspars; inter- bedded with laminated clayey gray siltstone; fine to lower coarse grained; fair sorting; very minor sample and cut fluorescence. Sub-Bituminous coal (13410' - 13455') = dark brown to black with metallic hues from disseminated sulfides delineating proto plant structures; low density; thinly laminated; moderate silt ash content; appears allochthomous lacking any association with carbonaceous shale. 3.3 Geological Sampling Program set type and purpose interval frequency distribution A Washed and Dried Reference 8,130’ – 13,493’ 30’ Debra Oudean Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99503 B Washed and Dried Reference 8,130’ – 13,493’ 30’ Debra Oudean Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99503 Box 1: 8,130’ – 9,870’ Box 2: 9,870’ – 12,030’ Box 3: 12,030’ – 13,493’ GP 24-13RD2 17 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) 0.0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 123.0 0.75 118.00 123.00 -0.38 0.71 0.51 0.61 223.0 1.00 195.00 222.99 -1.53 1.06 1.70 1.11 323.0 2.25 247.00 322.95 -3.14 -0.97 2.90 1.81 423.0 4.00 186.00 422.82 -7.38 -3.14 6.64 3.51 523.0 5.50 184.00 522.47 -15.62 -3.84 14.60 1.51 623.0 6.00 177.00 621.97 -25.63 -3.90 24.41 0.86 723.0 5.00 183.00 721.51 -35.20 -3.86 33.81 1.15 823.0 5.00 188.00 821.13 -43.86 -4.69 42.16 0.44 923.0 3.50 190.00 920.85 -51.19 -5.83 49.13 1.51 1,023.0 4.00 187.00 1,020.64 -57.65 -6.78 55.30 0.54 1,123.0 6.00 151.00 1,120.28 -65.69 -4.67 63.59 3.63 1,223.0 7.25 150.00 1,219.61 -75.73 1.02 74.53 1.26 1,323.0 8.25 158.00 1,318.70 -87.84 6.86 87.54 1.47 1,423.0 8.75 163.00 1,417.60 -101.77 11.77 102.15 0.89 1,523.0 10.25 158.00 1,516.23 -117.29 17.33 118.44 1.71 1,623.0 11.25 131.00 1,614.53 -131.95 28.03 134.88 5.09 1,723.0 11.75 133.00 1,712.52 -145.30 42.84 150.80 0.64 1,823.0 13.00 131.00 1,810.20 -159.62 58.77 167.90 1.32 1,923.0 14.25 136.00 1,907.39 -175.85 75.81 187.09 1.72 2,023.0 15.00 136.00 2,004.15 -194.02 93.35 208.26 0.75 2,123.0 15.75 140.00 2,100.57 -213.72 111.07 230.99 1.30 2,223.0 17.50 136.00 2,196.39 -234.94 130.24 255.47 2.09 2,323.0 19.00 140.00 2,291.36 -258.22 151.15 282.32 1.95 2,423.0 20.50 141.00 2,385.47 -284.30 172.63 312.02 1.54 2,523.0 21.00 141.00 2,478.99 -311.84 194.93 343.30 0.50 2,623.0 21.25 144.00 2,572.27 -340.42 216.86 375.55 1.11 2,723.0 21.00 142.00 2,665.55 -369.21 238.54 407.94 0.76 2,823.0 21.50 141.00 2,758.75 -397.57 261.11 440.08 0.62 2,923.0 19.50 141.00 2,852.41 -424.78 283.14 471.00 2.00 3,023.0 18.75 142.00 2,946.89 -450.42 303.54 500.06 0.82 GP 24-13RD2 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) 3,123.0 17.25 140.00 3,042.00 -474.44 322.97 527.35 1.62 3,223.0 17.25 142.00 3,137.50 -497.49 341.63 553.53 0.59 3,323.0 16.50 145.00 3,233.20 -520.80 358.90 579.72 1.15 3,423.0 15.50 145.00 3,329.32 -543.38 374.71 604.90 1.00 3,523.0 15.00 140.00 3,425.80 -564.24 390.70 628.42 1.41 3,623.0 16.25 143.00 3,522.11 -585.33 407.43 652.32 1.49 3,723.0 18.25 140.00 3,617.61 -608.50 425.92 678.59 2.19 3,823.0 19.50 143.00 3,712.23 -633.83 446.03 707.29 1.58 3,923.0 18.50 142.00 3,806.78 -659.66 465.85 736.43 1.05 4,023.0 18.00 140.00 3,901.75 -684.00 485.55 764.08 0.80 4,123.0 18.00 141.00 3,996.86 -707.84 505.20 791.23 0.31 4,223.0 17.50 144.00 4,092.10 -732.01 523.76 818.50 1.04 4,323.0 16.75 145.00 4,187.66 -755.98 540.86 845.29 0.81 4,423.0 16.00 140.00 4,283.61 -778.34 557.99 870.51 1.60 4,523.0 16.50 143.00 4,379.62 -800.24 575.40 895.33 0.98 4,623.0 15.00 147.00 4,475.86 -822.44 590.99 920.10 1.85 4,723.0 15.00 147.00 4,572.46 -844.15 605.09 944.09 0.00 4,823.0 14.00 152.00 4,669.27 -865.68 617.82 967.66 1.60 4,923.0 14.50 153.00 4,766.20 -887.52 629.18 991.26 0.56 5,023.0 13.75 150.00 4,863.17 -908.96 640.80 1,014.53 1.05 5,123.0 13.75 153.00 4,960.31 -929.84 652.14 1,037.20 0.71 5,223.0 14.50 158.00 5,057.29 -952.04 662.23 1,060.91 1.43 5,323.0 14.50 156.00 5,154.10 -975.09 672.01 1,085.40 0.50 5,423.0 15.00 160.00 5,250.81 -998.68 681.53 1,110.38 1.13 5,523.0 15.50 164.00 5,347.29 -1,023.69 689.64 1,136.47 1.16 5,623.0 16.00 165.00 5,443.54 -1,049.85 696.89 1,163.53 0.57 5,723.0 16.00 166.00 5,539.66 -1,076.53 703.79 1,191.04 0.28 5,823.0 15.50 170.00 5,635.91 -1,103.06 709.44 1,218.17 1.20 5,923.0 15.50 167.00 5,732.28 -1,129.24 714.77 1,244.88 0.80 6,023.0 15.25 171.00 5,828.70 -1,155.25 719.83 1,271.38 1.09 6,123.0 14.75 170.00 5,925.29 -1,180.78 724.10 1,297.25 0.56 6,223.0 13.50 169.00 6,022.27 -1,204.77 728.54 1,321.65 1.27 6,323.0 12.50 174.00 6,119.71 -1,227.00 731.90 1,344.11 1.50 6,423.0 9.50 185.00 6,217.87 -1,245.99 732.31 1,362.83 3.65 6,523.0 9.50 169.00 6,316.52 -1,262.31 733.16 1,379.01 2.63 6,623.0 10.50 172.00 6,415.00 -1,279.44 736.01 1,396.37 1.13 GP 24-13RD2 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) 6,723.0 10.50 180.00 6,513.33 -1,297.57 737.27 1,414.41 1.46 6,823.0 8.50 155.00 6,611.99 -1,313.39 740.40 1,430.53 4.54 6,923.0 9.50 148.00 6,710.76 -1,327.09 747.90 1,445.41 1.48 7,023.0 11.00 152.00 6,809.16 -1,342.51 756.75 1,462.24 1.66 7,123.0 15.00 155.00 6,906.58 -1,362.67 766.70 1,483.93 4.06 7,223.0 16.25 156.00 7,002.89 -1,387.18 777.86 1,510.12 1.28 7,323.0 16.50 161.00 7,098.83 -1,413.39 788.18 1,537.82 1.43 7,423.0 17.75 159.00 7,194.40 -1,441.05 798.26 1,566.89 1.38 7,523.0 17.50 159.00 7,289.71 -1,469.32 809.11 1,596.71 0.25 7,623.0 16.00 162.00 7,385.46 -1,496.46 818.76 1,625.20 1.73 7,723.0 16.50 165.00 7,481.47 -1,523.29 826.70 1,653.04 0.98 7,823.0 16.00 172.00 7,577.48 -1,550.66 832.29 1,680.98 2.02 7,923.0 16.50 169.00 7,673.49 -1,578.25 836.92 1,708.94 0.98 8,023.0 16.75 175.00 7,769.32 -1,606.54 840.88 1,737.47 1.73 8,123.0 16.75 178.00 7,865.07 -1,635.30 842.64 1,766.04 0.86 8,130.0 16.64 178.06 7,871.78 -1,637.31 842.71 1,768.02 1.59 8,187.35 15.48 188.64 7,926.90 -1,653.09 841.84 1,783.34 5.48 8,249.61 16.23 200.82 7,986.81 -1,669.44 837.50 1,798.57 5.47 8,313.74 16.91 212.36 8,048.29 -1,685.70 829.32 1,812.97 5.23 8,373.44 17.97 222.06 8,105.26 -1,699.88 818.50 1,824.82 5.18 8,434.67 18.95 235.42 8,163.36 -1,712.54 803.97 1,834.48 7.07 8,497.64 20.78 237.06 8,222.58 -1,724.42 786.18 1,842.75 3.04 8,559.82 22.48 237.66 8,280.38 -1,736.78 766.88 1,851.20 2.75 8,620.78 23.56 235.12 8,336.49 -1,749.98 747.04 1,860.37 2.40 8,683.72 24.86 231.42 8,393.90 -1,765.42 726.38 1,871.59 3.17 8,743.72 26.70 231.09 8,447.93 -1,781.75 706.03 1,883.73 3.08 8,807.37 28.73 231.35 8,504.27 -1,800.29 682.96 1,897.53 3.21 8,869.07 30.85 228.90 8,557.81 -1,819.96 659.45 1,912.35 3.96 8,931.14 32.94 225.19 8,610.51 -1,842.32 635.48 1,929.73 4.61 8,992.56 34.54 224.35 8,661.59 -1,866.54 611.46 1,948.92 2.71 9,055.69 34.36 225.61 8,713.65 -1,891.80 586.22 1,968.89 1.16 9,118.28 34.94 225.50 8,765.14 -1,916.71 560.81 1,988.51 0.95 9,180.60 34.76 224.28 8,816.28 -1,941.94 535.68 2,008.48 1.15 9,241.15 33.51 224.33 8,866.40 -1,966.26 511.94 2,027.82 2.07 9,305.45 34.78 223.71 8,919.61 -1,992.21 486.87 2,048.51 2.06 9,367.11 34.30 222.51 8,970.40 -2,017.73 462.97 2,069.00 1.36 GP 24-13RD2 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) 9,429.05 33.71 223.37 9,021.75 -2,043.09 439.38 2,089.39 1.22 9,489.46 33.78 224.59 9,071.98 -2,067.24 416.08 2,108.65 1.13 9,552.84 33.83 223.85 9,124.65 -2,092.51 391.49 2,128.76 0.65 9,614.39 34.74 219.94 9,175.51 -2,118.31 368.35 2,149.68 3.87 9,677.39 34.43 215.25 9,227.39 -2,146.63 346.55 2,173.31 4.26 9,738.59 34.23 211.33 9,277.93 -2,175.46 327.61 2,198.00 3.62 9,801.39 33.74 207.27 9,330.01 -2,206.05 310.43 2,224.76 3.70 9,857.93 33.94 204.48 9,376.98 -2,234.38 296.70 2,249.94 2.76 9,920.20 34.56 202.11 9,428.45 -2,266.57 282.84 2,278.89 2.36 9,985.81 36.68 199.25 9,481.79 -2,302.31 269.37 2,311.41 4.10 10,045.21 39.27 194.00 9,528.62 -2,337.32 258.97 2,343.79 6.97 10,107.36 40.84 189.11 9,576.20 -2,376.48 251.00 2,380.71 5.66 10,168.40 41.05 186.37 9,622.31 -2,416.11 245.61 2,418.59 2.96 10,230.82 40.89 184.42 9,669.44 -2,456.85 241.76 2,457.84 2.07 10,293.88 42.17 182.39 9,716.65 -2,498.58 239.29 2,498.33 2.94 10,356.16 44.15 180.89 9,762.08 -2,541.16 238.08 2,539.90 3.59 10,414.69 44.94 179.67 9,803.79 -2,582.22 237.88 2,580.16 1.98 10,479.19 46.05 178.55 9,849.01 -2,628.21 238.60 2,625.45 2.13 10,541.30 46.91 177.71 9,891.78 -2,673.22 240.08 2,669.91 1.69 10,604.01 49.30 179.46 9,933.65 -2,719.88 241.21 2,715.93 4.34 10,665.51 52.25 178.46 9,972.54 -2,767.51 242.09 2,762.85 4.96 10,727.62 53.56 177.31 10,010.00 -2,817.01 243.92 2,811.80 2.57 10,785.36 54.02 173.19 10,044.11 -2,863.43 247.78 2,858.10 5.81 10,850.97 53.50 170.11 10,082.90 -2,915.78 255.45 2,910.95 3.87 10,912.48 54.49 170.01 10,119.06 -2,964.79 264.04 2,960.70 1.61 10,973.20 55.69 167.87 10,153.82 -3,013.65 273.60 3,010.48 3.50 11,034.45 56.66 164.52 10,187.92 -3,063.05 285.74 3,061.29 4.81 11,096.79 59.32 162.77 10,220.96 -3,113.76 300.63 3,113.92 4.89 11,118.67 59.95 162.50 10,232.02 -3,131.78 306.27 3,132.68 3.06 11,181.51 61.22 161.39 10,262.88 -3,183.82 323.24 3,187.00 2.54 11,240.58 62.29 161.61 10,290.84 -3,233.17 339.75 3,238.59 1.84 11,302.09 63.80 161.92 10,318.72 -3,285.24 356.90 3,292.98 2.50 11,366.91 65.16 163.12 10,346.64 -3,341.03 374.47 3,351.10 2.68 11,426.15 66.59 163.20 10,370.86 -3,392.78 390.13 3,404.88 2.42 11,489.62 67.87 163.82 10,395.43 -3,448.89 406.75 3,463.13 2.21 11,553.53 67.73 164.41 10,419.57 -3,505.80 422.94 3,522.09 0.89 GP 24-13RD2 21 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) 11,613.94 69.45 165.85 10,441.62 -3,560.16 437.37 3,578.20 3.60 11,673.85 71.29 168.19 10,461.75 -3,615.14 450.03 3,634.59 4.79 11,736.08 72.91 170.37 10,480.88 -3,673.32 461.04 3,693.80 4.23 11,801.39 74.68 172.65 10,499.11 -3,735.34 470.30 3,756.45 4.31 11,865.07 75.24 173.77 10,515.64 -3,796.41 477.56 3,817.78 1.91 11,922.49 74.62 175.18 10,530.57 -3,851.59 482.90 3,872.97 2.60 11,985.98 73.31 176.86 10,548.11 -3,912.46 487.14 3,933.53 3.27 12,049.87 73.50 180.00 10,566.36 -3,973.66 488.82 3,993.92 4.72 12,112.83 75.87 182.56 10,582.98 -4,034.36 487.45 4,053.24 5.44 12,171.50 78.10 185.34 10,596.50 -4,091.37 483.51 4,108.46 5.98 12,236.69 77.79 187.75 10,609.81 -4,154.71 476.24 4,169.24 3.64 12,299.46 78.41 190.13 10,622.76 -4,215.38 466.70 4,226.98 3.85 12,357.90 79.67 192.93 10,633.88 -4,271.58 455.23 4,279.96 5.17 12,390.80 79.86 194.06 10,639.72 -4,303.07 447.68 4,309.43 3.44 12,448.72 81.35 195.73 10,649.18 -4,358.28 432.99 4,360.83 3.84 12,508.69 82.59 190.91 10,657.56 -4,416.05 419.31 4,414.92 8.23 12,572.72 82.65 188.94 10,665.79 -4,478.60 408.37 4,474.23 3.05 12,635.36 81.97 186.32 10,674.18 -4,540.12 400.13 4,533.05 4.27 12,697.49 82.22 183.57 10,682.73 -4,601.42 394.82 4,592.21 4.41 12,756.41 83.47 182.21 10,690.06 -4,659.81 391.87 4,648.96 3.13 12,820.11 82.84 179.27 10,697.66 -4,723.04 391.06 4,710.88 4.68 12886.30 81.02 177.11 10706.95 -4788.53 393.13 4775.57 4.24 12945.87 79.06 174.23 10717.25 -4847.03 397.55 4833.83 5.79 13008.71 80.98 175.17 10728.14 -4908.65 403.26 4895.41 3.40 13069.89 83.74 176.67 10736.27 -4969.13 407.57 4955.60 5.12 13130.01 86.58 178.57 10741.34 -5028.97 410.05 5014.82 5.67 13190.87 89.43 179.05 10743.46 -5089.78 411.32 5074.75 4.75 13255.56 92.20 179.29 10742.54 -5154.45 412.25 5138.41 4.29 13319.19 95.48 179.96 10738.29 -5217.92 412.67 5200.80 5.26 13383.83 98.21 179.92 10730.59 -5282.10 412.73 5263.80 4.23 13445.94 100.41 179.48 10720.54 -5343.38 413.05 5324.03 3.61 13461.18 100.32 179.23 10717.80 -5358.38 413.22 5338.77 1.71 13493.00 100.32 179.23 10712.10 -5389.68 413.64 5369.58 0.02 Note: Survey @ 13,493’ is a projection to total depth. GP 24-13RD2 22 4.1 Bit Record BIT NO. SIZE TYPE S/N JETS/ TFA IN OUT Feet Drilled HRS AVE ROP (Ft/HR) CONDITION Mill 8.5” Window Mill 13346364 — 8,130’ 8,177’ 47’ 14.0 3.1 In Gauge 1 8.5” HDBS MMD75DC 12931975 7x12 / 0.7731 8,177’ 9,887’ 1,710’ 45.0 55.6 1-2-CT-A-X-1-WT-ROP 2 8.5” Hughes Kymera Hybrid 5248500 1x15,2x16, 1x18 / 0.8138 9,887’ 11,168’ 1,281’ 57.1 22.4 2-5-BT-G-E-I-WT-ROP 3 8.5” NOV / Reed SK716M A234355 7x12 / 0.7731 11,168’ 11,812’ 644’ 26.8 24.0 1-3-CT-A-X-I-CT-DTF 4 8.5” Varel / V711PDG1HRU PDC 4009435 3x12, 5x11 / 0.7954 11,812’ 12,450’ 638’ 81.6 7.8 2-3-WT-A-X-I-ER-BHA 5 8.5” Kymera HP524 Hybrid 7046452 2x18, 2x14 / 0.7977 12,450’ 13,493’ 1043’ 59.1 24.9 3-2-RO-N-E-IN-WT-TD GP 24-13RD2 23 4.2 Mud Record Contractor: Halliburton Baroid Date Depth MD TVD MW (ppg) VIS (s/qt) PV YP Gels HTHP (cc) FC Sols (%) O/W Ratio Sd (%) ASG AgNO3 CaCl2 (ppbl) Lime (ppb) Enviromul 11/8/17 8131 7872 8.90 86 22 10 7/17/20 3.4 0/2 7.4 80.7/19.3 0.01 2.880 1.7 11.12 3.63 11/9/17 8177 7916 8.90 92 19 9 7/0/0 3.2 0/2 5.5 77.8/22.2 0.01 3.744 1.6 13.06 7.38 11/10/17 8380 8110 9.00 92 21 10 7/16/20 3.2 0/2 7.1 76.9/23.1 0.01 3.744 1.6 14.03 4.92 11/11/17 9340 8951 9.05 85 28 11 8/20/24 3.0 0/2 6.9 78.0/22.0 0.01 3.372 1.7 15.49 7.38 11/12/17 9882 9350 9.05 80 30 12 9/26/31 2.6 0/2 7.9 78.9/21.1 0.01 3.078 1.8 15.97 7.38 11/13/17 9887 9401 9.10 116 29 12 9/24/29 2.6 0/2 7.8 78.9/21.1 0.01 3.155 1.8 16.46 10.10 11/14/17 9887 9401 9.10 195 28 12 8/24/33 2./6 0/2 7.8 78.9/21.1 0.01 3.155 1.8 16.46 9.84 11/15/17 10237 9673 9.4 92 33 12 10/29/38 2.4 0/2 8.3 79.9/20.1 0.01 3.477 1.8 15.97 10.23 11/16/17 10650 9966 9.5 85 28 12 9/29/35 2.6 0/2 9.1 82.0/18.0 0.01 3.477 1.6 15.97 7.25 11/17/17 11030 10185 9.5 78 33 13 10/31/42 2.6 0/2 9.6 83.1/16.9 0.01 3.362 1.6 15.00 7.12 11/18/17 11032 10187 9.5 117 26 13 9/32/42 2.6 0/2 9.6 83.1/16.9 0.01 3.362 1.6 15.00 7.51 11/19/17 11168 10255 9.5 90 29 11 10/29/41 2.6 0/2 10.1 84.1/15.9 0.01 3.303 1.6 14.03 7.38 11/20/17 11168 10255 9.65 221 27 13 11/33/44 2.4 0/2 10.3 84.1/15.9 0.01 3.430 1.5 14.03 7.38 11/21/17 11241 10291 9.5 117 25 20 13/37/56 2.4 0/2 10.0 84.1/15.9 0.01 3.319 1.6 13.54 8.55 11/22/17 11427 10371 9.5 87 29 12 12/32/41 2.4 0/2 9.8 84.2/15.8 0.01 3.380 1.6 14.03 8.42 11/23/17 11678 10463 9.5 87 30 13 12/36/45 2.4 0/2 9.9 85.3/14.7 0.01 3.397 1.5 13.06 7.77 11/24/17 11813 10502 9.55 133 31 15 12/36/48 2.4 0/2 10.2 85.3/14.7 0.01 3.398 1.4 12.09 8.29 11/25/17 11813 10502 9.65 158 30 17 15/38/50 2.4 0/2 10.7 85.5/14.5 0.01 3.392 1.4 12.09 8.03 11/26/17 11952 10537 9.5 80 28 14 13/31/39 2.4 0/2 10.5 85.8/14.2 0.01 3.281 1.4 12.57 7.38 11/27/17 12060 10571 9.5 83 28 13 12/31/40 2.4 0/2 9.8 83.9/16.1 0.01 3.386 1.5 12.57 8.29 11/28/17 12173 10601 9.5 79 32 13 12/32/41 2.4 0/2 9.7 82.2/17.8 0.01 3.359 1.5 12.57 8.29 11/29/17 12410 10644 9.5 73 31 14 13/34/45 2.4 0/2 9.6 83.1/16.9 0.01 3.423 1.4 13.54 7.9 11/30/17 12450 10650 9.5 115 31 12 11/30/38 2.3 0/2 10.3 83.0/17.0 0.01 3.244 1.4 12.57 7.77 12/01/17 12474 10654 9.55 105 33 15 15/36/46 2.3 0/2 10.2 83.0/17.0 0.01 3.308 1.5 13.06 7.12 12/02/17 12728 10688 9.53 78 32 15 13/34/42 2.4 0/2 10.2 83.0/17.0 0.01 3.280 1.5 13.06 7.25 12/03/17 13104 10740 9.5 76 30 16 13/31/40 2.4 0/2 10.3 83.8/16.2 0.01 3.261 1.5 12.57 7.12 12/04/17 13493 10712 9.5 71 28 14 12/28/36 2.4 0/2 10.0 84.1/15.9 0.01 3.328 1.4 12.09 6.22 12/05/17 13493 10712 9.63 183 28 16 13/29/38 2.4 0/2 10.8 80.3/19.7 0.01 3.236 1.4 12.09 5.83 12/06/17 13493 10712 9.55 104 28 15 13/29/38 2.4 0/2 10.8 84.0/16.0 0.01 3.209 1.4 12.09 6.60 Abbreviations: MW = Mud Weight VIS = Funnel Viscosity PV = Plastic Viscosity YP = Yield Point Gels = Gel Strength FL = Water or Filtrate Loss FC = Filter Cake O/W = Oil to Water ratio Sols = Solids Sd = Sand content MBT = Methylene Blue Alk, Pm = Alkalinity, Mud pH = Acidity Cl = Chlorides Ca = Hardness Calcium nr = Not Recorded GP 24-13RD2 24 4.3 Drilling Progress Days vs Depth 7500 8500 9500 10500 11500 12500 13500 11/8/1711/9/1711/10/1711/11/1711/12/1711/13/1711/14/1711/15/1711/16/1711/17/1711/18/1711/19/1711/20/1711/21/1711/22/1711/23/1711/24/1711/25/1711/26/1711/27/1711/28/1711/29/1711/30/1712/1/1712/2/1712/3/1712/4/1712/5/1712/6/1712/7/1712/8/1712/9/1712/10/1712/11/1712/12/1712/13/1712/14/1712/15/178.5" GP 24-13 RD2 GP 24-13RD2 25 5 SHOW REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:25 9964'MD 10141'MD Country:25 9464'TVD 9602'TVD ROP (fph)48 ft/hr 36 ft/hr 43 ft/hr 143 ft/hr WOB 18 klbs 18 klbs 13 klbs 20 klbs RPM 130 rpm 139 rpm 180 rpm 180 rpm PP 2741 psi 2792 psi 2913 psi 2940 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chlorides Total Gas 38 116 131 161 C1 (ppm)5,329 17,810 22,455 25,244 C2 (ppm)192 1,316 760 1,824 C3 (ppm)56 475 287 707 C4 (ppm)13 165 116 268 C5 (ppm)2 43 45 71 Intensity None Amount 0%Opacity Transpr Amount 30% At Shakers No Color None-Gray Color Dk Straw Color V Lt Brn Type None Amount 100%Speed Instant Intensity Weak-Dull Fluor Color None Distribution Even Opacity Transpr Color v pl yel Outgassing No Intensity Weak-Dull Intensity Weak-Dull Mud Type Oil-LVT Color yellow Color pale yel Report by: Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain Josh Dubowski / Allen Odegaard Show Summary Oil Indicators Lithology Averages Hilcorp Alaska, LLC 50-733-20080-02-00GP 24-13 RD2 Granite Point Field Kuukpik 5 11/15/2017 11:00 AM Very light yellowish brown to light gray and grayish white; easily friable to unconsolidated; upper fine to lower coarse grained; poor to moderate sorting; sub-angular to sub-rounded to rounded; sub-spherical to trace sub- discoidal; grain supported; dominated by clear to translucent quartz with common dark lithics; trace reaction to HCl; often interbedded with siltstones and claystones; Petroleum Odor Before During After Maximum Weak to moderate oil show with OBM contamination interfering with hydrocarbon fluorescence and odor. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 1.1 1.0 10.0 100.0 1000.0 10000.0 1 2 3 4ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas Hydrocarbon Show Report #2 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:25 10295'MD 10382'MD Country:25 9717'TVD 9780'TVD ROP (fph)41 ft/hr 37 ft/hr 14 ft/hr 156 ft/hr WOB 17 klbs 18 klbs 18 klbs 22 klbs RPM 179 rpm 180 rpm 168 rpm 180 rpm PP 2849 psi 2883 psi 2845 psi 2944 psi Mud Weight 9.5 lbs/gal 9.5 lbs/gal 9.5 lbs/gal 9.5 lbs/gal Chlorides Total Gas 61 109 46 190 C1 (ppm)8,857 16,432 4,474 32,285 C2 (ppm)249 1,319 538 1,788 C3 (ppm)90 356 132 631 C4 (ppm)47 134 60 246 C5 (ppm)25 51 38 69 Intensity None Amount 0%Opacity Transpr Amount 30% At Shakers No Color None-Gray Color V Lt Brn Color V Lt Brn Type None Amount 5%Speed Slow Intensity Weak-Dull Fluor Color None Distribution Patchy Opacity Transpr Color v pl yel Outgassing No Intensity Moderate Intensity Weak-Dull Mud Type Oil-LVT Color yellow Color blue-wht Report by: Weak to moderate oil show with OBM contamination interfering with hydrocarbon fluorescence and odor. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 1.0 11/16/2017 12:00 AM Dark brown with dusky reddish to black hues to blackish brown to trace pale yellowish brown; easily friable to unconsolidated; lower medium to upper coarse with upper coarse and lower fine common; trace 2-4mm bit broken quartz grains poor sorting; sub angular to sub rounded to angular; sub spherical to sub discoidal; grain supported; dominated by clear to translucent quartz with common dark lithics and minor carbonaceous sediment. Petroleum Odor Before During After Maximum Josh Dubowski / Allen Odegaard Show Summary Oil Indicators Lithology Averages Hilcorp Alaska, LLC 50-733-20080-02-00GP 24-13 RD2 Granite Point Field Kuukpik 5 Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain 1.0 10.0 100.0 1000.0 10000.0 1 2 3 4ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas Hydrocarbon Show Report #3 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:25 11276'MD 11812'MD Country:25 10307'TVD 10502'TVD ROP (fph)30 ft/hr 31 ft/hr 11 ft/hr 119 ft/hr WOB 11 klbs 9 klbs 10 klbs 15 klbs RPM 125 rpm 146 rpm 157 rpm 161 rpm PP 2683 psi 2637 psi 2718 psi 2741 psi Mud Weight 9.5 lbs/gal 9.5 lbs/gal 9.5 lbs/gal 9.5 lbs/gal Chlorides Total Gas 44 87 85 179 C1 (ppm)6,835 12,906 15,439 30,598 C2 (ppm)280 1,080 347 2,113 C3 (ppm)139 280 82 774 C4 (ppm)48 90 24 279 C5 (ppm)9 38 9 67 Intensity None Amount 0%Opacity Transpr Amount 10% At Shakers No Color None-Gray Color Amber Color Faint Type None Amount 5%Speed Slow Intensity Weak-Dull Fluor Color None Distribution Even Opacity Transpr Color yel-grn Outgassing No Intensity None-v wk Intensity Weak-Dull Mud Type Oil-LVT Color lt yel Color blue-wht Report by: Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain Josh DubowskI Show Summary Oil Indicators Lithology Averages Hilcorp Alaska, LLC 50-733-20080-02-00GP 24-13 RD2 Granite Point Field Kuukpik 5 11/22/2017 1:55 AM medium gray with brownish hues to medium gray with dusky yellow to red hues; unconsolidated to easily friable to minor firm; lower medium to lower fine; lower coarse to upper very fine common; moderate to poor sorting; sub rounded to sub angular to rounded; sub spherical to sub discoidal; grain supported; non calcareous; predominantly clear to translucent quartz; minor dark lithics and trace carbonaceous sediment. Petroleum Odor Before During After Maximum Weak to moderate oil show with OBM contamination interfering with hydrocarbon fluorescence and odor. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 1.0 1.0 10.0 100.0 1000.0 10000.0 1 2 3 4ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas Hydrocarbon Show Report #4 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:25 11813'MD 12050'MD Country:25 10502'TVD 10566'TVD ROP (fph)33 ft/hr 14 ft/hr 1 ft/hr 87 ft/hr WOB 10 klbs 10 klbs 4 klbs 14 klbs RPM 138 rpm 152 rpm 115 rpm 160 rpm PP 2666 psi 2350 psi 1072 psi 2858 psi Mud Weight 9.5 lbs/gal 9.5 lbs/gal 9.5 lbs/gal 9.5 lbs/gal Chlorides Total Gas 78 53 19 185 C1 (ppm)10,083 7,716 2,270 35,786 C2 (ppm)1,521 612 90 1,356 C3 (ppm)192 102 17 311 C4 (ppm)52 30 8 88 C5 (ppm)45 17 6 35 Intensity None Amount 0%Opacity Transpr Amount 10% At Shakers No Color None-Gray Color V Lt Brn Color V Lt Brn Type None Amount 5%Speed Slow Intensity Weak-Dull Fluor Color None Distribution Patchy Opacity Translu Color yel-grn Outgassing No Intensity Weak-Dull Intensity Weak-Dull Mud Type Oil-LVT Color lt yel Color blue-wht Report by: Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain Josh DubowskI Show Summary Oil Indicators Lithology Averages Hilcorp Alaska, LLC 50-733-20080-02-00GP 24-13 RD2 Granite Point Field Kuukpik 5 11/26/2017 4:20 AM Dark medium brown with dusky red hues to medium brown with grayish hues; unconsolidated to easily friable; upper medium to upper fine; moderate to poor sorting; sub angular to sub rounded; sub spherical to sub discoidal. Petroleum Odor Before During After Maximum Weak to moderate oil show with OBM contamination interfering with hydrocarbon fluorescence and odor. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 1.0 1.0 10.0 100.0 1000.0 10000.0 1 2 3 4ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas Hydrocarbon Show Report #5 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:25 12112'MD 12450'MD Country:25 10582'TVD 10649'TVD ROP (fph)13 ft/hr 14 ft/hr 14 ft/hr 98 ft/hr WOB 13 klbs 9 klbs 16 klbs 13 klbs RPM 160 rpm 146 rpm 118 rpm 161 rpm PP 2537 psi 2543 psi 2665 psi 2773 psi Mud Weight 9.5 lbs/gal 9.5 lbs/gal 9.5 lbs/gal 9.5 lbs/gal Chlorides Total Gas 33 47 73 77 C1 (ppm)4,331 5,911 13,219 10,332 C2 (ppm)510 853 359 1,541 C3 (ppm)40 96 143 174 C4 (ppm)7 25 43 41 C5 (ppm)8 25 7 41 Intensity None Amount 0%Opacity Transpr Amount 10% At Shakers No Color None-Gray Color Brown Color V Lt Brn Type None Amount 5%Speed Slow Intensity Weak-Dull Fluor Color None Distribution Patchy Opacity Translu Color yel-grn Outgassing No Intensity Weak-Dull Intensity Moderate Mud Type Oil-LVT Color lt yel Color blue-wht Report by: Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain Josh DubowskI Show Summary Oil Indicators Lithology Averages Hilcorp Alaska, LLC 50-733-20080-02-00GP 24-13 RD2 Granite Point Field Kuukpik 5 11/28/2017 7:00 PM Medium brownish gray to olive gray unconsolidated grains and semi-consolidated clusters; mostly clear to smoky blue/gray quartz with abundant blue, pink, and black lithics and some angular granules of laminated tan- olive green tuffaceous siltstone; upper fine to lower coarse grained; fair sorting; subrounded to subangular; dull to earthy luster and occasionally sparkling. Petroleum Odor Before During After Maximum Weak to moderate oil show with OBM contamination interfering with hydrocarbon fluorescence and odor. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 1.3 1.0 10.0 100.0 1000.0 10000.0 1 2 3 4ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas Hydrocarbon Show Report #6 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:25 12451'MD 12690'MD Country:25 10649'TVD 10681'TVD ROP (fph)10 ft/hr 17 ft/hr 11 ft/hr 89 ft/hr WOB 9 klbs 18 klbs 20 klbs 25 klbs RPM 120 rpm 133 rpm 157 rpm 160 rpm PP 2504 psi 2635 psi 2505 psi 3108 psi Mud Weight 9.5 lbs/gal 9.5 lbs/gal 9.5 lbs/gal 9.5 lbs/gal Chlorides Total Gas 40 77 42 142 C1 (ppm)5,173 12,539 6,313 23,779 C2 (ppm)574 697 283 1,366 C3 (ppm)85 284 100 592 C4 (ppm)27 102 42 235 C5 (ppm)19 31 18 62 Intensity None Amount 0%Opacity Transpr Amount 10% At Shakers No Color None-Gray Color V Lt Brn Color V Lt Brn Type None Amount 10%Speed Slow Intensity Weak-Dull Fluor Color None Distribution Even Opacity Translu Color yel-grn Outgassing No Intensity Weak-Dull Intensity Moderate Mud Type Oil-LVT Color lt yel Color blue-wht Report by: Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain Josh DubowskI Show Summary Oil Indicators Lithology Averages Hilcorp Alaska, LLC 50-733-20080-02-00GP 24-13 RD2 Granite Point Field Kuukpik 5 12/1/2017 3:40 AM Light olive gray to medium brownish gray granule-sized firmly friable clusters and lesser unconsolidated grains; mostly grain-supported with minor clayey cement; dominantly smoky-blue translucent to white quartz with minor black, blue, and light brown lithics; upper fine to lower very coarse grained with a few conglomerate grains; poor to fair sorting; subangular to subrounded; moderate sphericity; dull but sometimes sparkling luster; occasional subangular bit-curl granules of laminated tuffaceous siltstone. Petroleum Odor Before During After Maximum Weak to moderate oil show with OBM contamination interfering with hydrocarbon fluorescence and odor. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 1.1 1.0 10.0 100.0 1000.0 10000.0 1 2 3 4ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas Hydrocarbon Show Report #7 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:25 12800'MD 13300'MD Country:25 10695'TVD 10739'TVD ROP (fph)20 ft/hr 25 ft/hr 19 ft/hr 135 ft/hr WOB 20 klbs 20 klbs 18 klbs 23 klbs RPM 138 rpm 139 rpm 148 rpm 142 rpm PP 2539 psi 2630 psi 2616 psi 2778 psi Mud Weight 9.5 lbs/gal 9.5 lbs/gal 9.5 lbs/gal 9.6 lbs/gal Chlorides Total Gas 116 134 77 217 C1 (ppm)19,339 21,272 10,597 35,820 C2 (ppm)913 1,148 679 1,709 C3 (ppm)465 600 410 960 C4 (ppm)159 256 206 418 C5 (ppm)42 72 76 109 Intensity None Amount 0%Opacity Translu Amount 5% At Shakers No Color None-Gray Color Lt Brown Color V Lt Brn Type None Amount 5%Speed Slow Intensity Weak-Dull Fluor Color None Distribution Even Opacity Translu Color pale yel Outgassing No Intensity Weak-Dull Intensity Moderate Mud Type Oil-LVT Color yel-wht Color blue-wht Report by: Weak to moderate oil show with OBM contamination interfering with hydrocarbon fluorescence and odor. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 1.0 12/5/2017 8:00 AM Tuffaceous Sandstone / Sandstone = medium gray to medium olive brown granule sized firmly friable clusters and unconsolidated grains; clear to translucent blue-gray quartz abundant with lesser black and tan lithics, orthoclase, and subangular siltstone particles; mostly grain-supported with varying clayey matrix; upper fine to upper medium grained; fair sorting; subrounded; massive to platy cuttings habit. Petroleum Odor Before During After Maximum Garnet Knopp / Josh Dubowksi Show Summary Oil Indicators Lithology Averages Hilcorp Alaska, LLC 50-733-20080-02-00GP 24-13 RD2 Granite Point Field Kuukpik 5 Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain 1.0 10.0 100.0 1000.0 10000.0 1 2 3 4ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas GP 24-13RD2 26 6 DAILY REPORTS Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Rick Brumley, Adam Dorr DATE Nov 08, 2017 DEPTH 8140' PRESENT OPERATION Milling Window TIME 23:59 YESTERDAY 8130' 24 HOUR FOOTAGE 10' CASING INFORMATION 9 5/8" 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 8.5 Baker Hughs / Window Mill 0.922 8130' 10' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 4.5 @ 8138 1.2 @ 8132 2.1 2.4 FT/HR SURFACE TORQUE 7324 @ 8134 4592 @ 8139 6614.0 5811.8 FT-LBS WEIGHT ON BIT 12 @ 8140 0 @ 8131 4.9 12.2 KLBS ROTARY RPM 108 @ 8133 98 @ 8131 118.2 108.1 RPM PUMP PRESSURE 1778 @ 8139 1719 @ 8131 1943.0 1725.6 PSI DRILLING FLUIDS REPORT DEPTH MW 8.9 VIS 86 PV 22 YP 10 FL 3.4 Gels 7/17/20 CL- FC 0/2 SOL 7.4 SD 0.01 OIL 80.7/19.3 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 11 @ 8140 7 @ 8131 11.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 219 @ 8140 32 @ 8132 134.7 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 90% Cement, 10% Metal Shavings PRESENT LITHOLOGY 90% Cement, 10% Metal Shavings DAILY ACTIVITY SUMMARY Pick up BHA #2 and shallow pulse test. Trip in hole to 5315’, Run in hole to 8039’. Establish circulation and orient to 65R begin slacking off and tag CBP @ 8148’ set anchor with 15K down. WT tool face change to 53R. Set whipstock shear @ 35K down. Top of window @ 8130’. Drain Pits and prep for bringing on OBM. Displace well to OBM taking displacement returns to production. Change shaker screens and pick up single for milling window. Mill window from 8130’ to 8140’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Rick Brumley, Adam Dorr DATE Nov 09, 2017 DEPTH 8177 PRESENT OPERATION P/U BHA TIME 23:59 YESTERDAY 8140 24 HOUR FOOTAGE 37 CASING INFORMATION 9 5/8" 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 10.0 @ 8152 1.8 @ 8160 3.6 2.4 FT/HR SURFACE TORQUE 7032 @ 8159 4784 @ 8141 6276.7 6419.3 FT-LBS WEIGHT ON BIT 17 @ 8154 5 @ 8141 11.2 10.5 KLBS ROTARY RPM 117 @ 8171 107 @ 8153 115.5 117.1 RPM PUMP PRESSURE 1833 @ 8168 1713 @ 8170 1811.0 1724.6 PSI DRILLING FLUIDS REPORT DEPTH 8177 MW 8.9 VIS 92 PV 19 YP 9 FL 3.2 Gels 7/0/0 CL- FC 0/2 SOL 5.5 SD 0.01 OIL 77.8/22.2 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 19 @ 8163 11 @ 8141 15.6 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 746 @ 8171 187 @ 8141 454.8 CONNECTION GAS HIGH ETHANE (C-2) 29 @ 8155 7 @ 8168 14.2 AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 70% Tuffaceous Claystone 30% Tuffaceous Siltstone PRESENT LITHOLOGY 70% Tuffaceous Claystone 30% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Mill window and rat hole from 8140’ to 8167’. Condition mud and perform FIT to 12.5 EMW. Finish drilling rat hole down to 8177’. Pump slug and pull out of the hole. Lay down milling BHA, Rig up and test geo span. Picking up Drilling BHA at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Rick Brumley, Adam Dorr DATE Nov 10, 2017 DEPTH 8510 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 8177 24 HOUR FOOTAGE 333 CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8497.64 20.78 237.06 8222.58 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" HDBS MMD75DC 12931975 7x12 8177' 333' 9.6 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 556.4 @ 8439 0.9 @ 8469 41.6 128.01 FT/HR SURFACE TORQUE 10772 @ 8236 5959 @ 8177 7554.1 7774.56 FT-LBS WEIGHT ON BIT 16 @ 8203 5 @ 8178 9.7 10.21 KLBS ROTARY RPM 121 @ 8321 39 @ 8236 99.1 120.31 RPM PUMP PRESSURE 2501 @ 8187 1720 @ 8498 2293.4 2309.01 PSI DRILLING FLUIDS REPORT DEPTH 8380 MW 9.0 VIS 92 PV 21 YP 10 FL 3.2 Gels 7/16/20 CL- FC 0/2 SOL 7.1 SD 0.01 OIL 76.9/23.1 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 XL 25KSI, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 490 @ 8275 12 @ 8195 62.9 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 58469 @ 8419 503 @ 8194 5495.9 CONNECTION GAS HIGH ETHANE (C-2) 420 @ 8275 0 @ 8398 28.5 AVG PROPANE (C-3) 24 @ 8419 0 @ 8178 1.9 CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 54u / 25u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 50% Tuff Claystone, 30% Tuff Siltstone, 20% Sandstone PRESENT LITHOLOGY 50% Tuff Claystone, 30% Tuff Siltstone, 20% Sandstone DAILY ACTIVITY SUMMARY Continue making up BHA #2, shallow test and load sources. Trip in hole to 2600’ and break in geo. Trip in hole to 8059’, slip and cut 130’ of drilling line, circulate and condition mud. Wash and ream to bottom and drill ahead until report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Rick Brumley / Adam Dorr DATE Nov 11, 2017 DEPTH 9483' PRESENT OPERATION Short trip TIME 23:59 YESTERDAY 8510' 24 HOUR FOOTAGE 973' CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9429.05 33.71 223.37 9021.75 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" HDBS MMD75DC 12931975 7x12 8177' 1306' 25.75 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 2337.2 @ 9245 1.5 @ 9330 67.6 114.75 FT/HR SURFACE TORQUE 10910 @ 9270 5612 @ 9385 8179.9 8686.37 FT-LBS WEIGHT ON BIT 20 @ 9387 2 @ 9367 9.9 13.04 KLBS ROTARY RPM 130 @ 9370 108 @ 9387 121.1 129.42 RPM PUMP PRESSURE 2786 @ 9172 1858 @ 8521 2542.1 2669.62 PSI DRILLING FLUIDS REPORT DEPTH 9340 MW 9.05 VIS 85 PV 28 YP 11 FL 3.0 Gels 8/20/24 CL- FC 0/2 SOL 6.9 SD 0.01 OIL 78/22 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 XL 25KSI, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 482 @ 8720 19 @ 9266 64.2 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 95417 @ 8720 1676 @ 8623 10516.2 CONNECTION GAS HIGH ETHANE (C-2) 494 @ 9372 3 @ 9266 33.7 AVG PROPANE (C-3) 68 @ 9372 0 @ 9266 8.2 CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG - / 23u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 60% Claystone 30% Sandstone 10% Siltstone PRESENT LITHOLOGY 60% Claystone 40% Sandstone DAILY ACTIVITY SUMMARY Continue drilling hole as per directional driller down to 9490’. Prep to short trip. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Rick Brumley, Adam Dorr DATE Nov 13, 2017 DEPTH 9887' PRESENT OPERATION Circulating TIME 23:59 YESTERDAY 9483' 24 HOUR FOOTAGE 404' CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9801.39' 33.74 207.27 9330.01' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" HDBS MMD75DC 12931975 7x12 8177' 1710' 40.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 275.3 @ 9514 0.5 @ 9601 46.7 2.73 FT/HR SURFACE TORQUE 11228 @ 9882 7006 @ 9563 8618.3 9878.79 FT-LBS WEIGHT ON BIT 15 @ 9836 2 @ 9491 9.3 13.44 KLBS ROTARY RPM 160 @ 9594 119 @ 9562 130.9 128.57 RPM PUMP PRESSURE 2840 @ 9637 1869 @ 9862 2380.0 2196.29 PSI DRILLING FLUIDS REPORT DEPTH 9822' MW 9.05 VIS 80 PV 30 YP 12 FL 2.6 Gels 9/26/31 CL- FC 0/2 SOL 7.9 SD 0.01 OIL 78.9/21.1 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 XL 25KSI, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 305 @ 9520 21 @ 9752 63.9 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 60041 @ 9520 1323 @ 9752 8403.7 CONNECTION GAS HIGH ETHANE (C-2) 2176 @ 9598 19 @ 9492 265.1 AVG PROPANE (C-3) 889 @ 9598 5 @ 9500 82.9 CURRENT BUTANE (C-4) 296 @ 9598 0 @ 9860 24.6 CURRENT BACKGROUND/AVG 34u / 34u PENTANE (C-5) 77 @ 9599 3 @ 9654 4.6 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 40% Tuff sandstone 40% Tuff Claystone 10% Tuff siltstone 10% Coal PRESENT LITHOLOGY 80% Tuff Claystone 20% Tuff Sandstone DAILY ACTIVITY SUMMARY Circulate hole clean, monitor well (static), pump dry job and TOOH to 9086’. Wash and ream from 9086’ to 9056’ 40K overpull @ 9086’, 30K @ 9381’, TOOH on elevators to 8934’. Trip in hole to 9487’ and continue drilling 8.5” hole section as per directional driller to 9877’ where the decision was made to pull out of the hole and check the bit. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Rick Brumley, Adam Dorr DATE Nov 13, 2017 DEPTH 9887' PRESENT OPERATION Trip in hole TIME 23:59 YESTERDAY 9887' 24 HOUR FOOTAGE CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9801.39' 33.74 207.27 9330.01' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" HDBS MMD75DC 12931975 7x12 8177' 9877' 1710'45 1-2-CT-A-X-1-WT ROP 2 8.5" Hughes Kymera Hybrid 5248500 1x15, 2x16, 1x18 9887' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9822' MW 9.1 VIS 116 PV 29 YP 12 FL 2.6 Gels 9/24/29 CL- FC 0/2 SOL 7.8 SD 0.01 OIL 78.9/21.1 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 XL 25KSI, ADR, DGR, ALD, CTN, MRIL 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 No new footage drilled PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Rack back one stand, Kelly up, pump sweep and circulate hole clean. 25% increased cuttings when sweep came back. Monitor well (static) and begin pulling out of hole. Work through tight coal spots on elevators at 8065’. Pull out of hole and lay down BHA. Make up new BHA with MIRL, shallow test and begin tripping into the hole. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Rick Brumley, Adam Dorr, Rance Peterson DATE Nov 14, 2017 DEPTH 9887' PRESENT OPERATION Trip in hole TIME 23:59 YESTERDAY 9887' 24 HOUR FOOTAGE CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9801.39' 33.74 207.27 9330.01' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Hughes Kymera Hybrid 5248500 1x15, 2x16, 1x18 9887' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9822' MW 9.1 VIS 195 PV 28 YP 12 FL 2.6 Gels 8/24/33 CL- FC 0/2 SOL 7.8 SD 0.01 OIL 78.9/21.1 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 XL 25KSI, ADR, DGR, ALD, CTN, MRIL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 215u 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 No new footage drilled PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Trip in hole to 8074’, service drawworks/top drive. Trip in hole to 9622’, wash and ream down to 9887’. Pump high viscosity sweep and trip out of hole to 8511’ through tight coal spots. Pump slug and pull out to 4000’ and pulse test MWD (good). Pump slug and continue pulling out. Lay down agitator, rack back HWDP, jars and drill collars. Make up shock sub, drill collar, one stand of HWDP. Shallow test (good). Trip in hole to 4572’ and fill pipe and test MWD. Service rig. Continue tripping into hole at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Rick Brumley, Rance Pederson DATE Nov 15, 2017 DEPTH 10298 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 9887 24 HOUR FOOTAGE 411 CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10230.82 40.89 184.42 9669.44 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Hughes Kymera Hybrid 5248500 1x15, 2x16, 1x18 9887' 411' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 161.7 @ 9917 1.0 @ 10006 35.4 100.11 FT/HR SURFACE TORQUE 10962 @ 10039 7011 @ 9934 8947.1 9387.26 FT-LBS WEIGHT ON BIT 19 @ 10141 3 @ 9889 16.3 15.21 KLBS ROTARY RPM 179 @ 10198 119 @ 9889 152.9 179.67 RPM PUMP PRESSURE 2993 @ 10181 2101 @ 9895 2814.5 2890.17 PSI DRILLING FLUIDS REPORT DEPTH 10237 MW 9.4 VIS 92 PV 33 YP 12 FL 2.4 Gels 10/29/38 CL- FC 0/2 SOL 8.3 SD 0.01 OIL 79.9/20.1 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 XL 25KSI, ADR, DGR, ALD, CTN, MRIL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 286 @ 10258 16 @ 9918 94.3 TRIP GAS 139u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 57173 @ 10258 1457 @ 9935 14938.7 CONNECTION GAS HIGH ETHANE (C-2) 1823 @ 10136 13 @ 9890 745.5 AVG PROPANE (C-3) 707 @ 10088 2 @ 9918 274.3 CURRENT BUTANE (C-4) 267 @ 10059 0 @ 9907 102.6 CURRENT BACKGROUND/AVG 98u / 38u PENTANE (C-5) 71 @ 10136 0 @ 9935 32.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 60% Tuff Sandstone 30% Tuff Claystone 10% Coal PRESENT LITHOLOGY 80% Tuff Sandstone 20% Tuff Claystone DAILY ACTIVITY SUMMARY Continue tripping into the hole to 8180’. Slip and cut 113’ of drill line. Trip in to 9793’, wash and ream to bottom. Stage pumps up to drill rate, tag fill at 9880’. Wash and ream to bottom. Drill as per DD to 10298’ at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Rick Brumley, Rance Pederson DATE Nov 16, 2017 DEPTH 10694 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 10298 24 HOUR FOOTAGE 396 CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10604.01 49.3 179.46 9933.65 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Hughes Kymera Hybrid 5248500 1x15, 2x16, 1x18 9887' 807' 31.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 156.2 @ 10300 1.0 @ 10660 30.1 15.30 FT/HR SURFACE TORQUE 12061 @ 10559 7730 @ 10649 9162.5 8424.87 FT-LBS WEIGHT ON BIT 26 @ 10590 8 @ 10649 19.4 16.80 KLBS ROTARY RPM 179 @ 10325 98 @ 10529 130.4 99.07 RPM PUMP PRESSURE 2984 @ 10423 1977 @ 10587 2772.6 2677.61 PSI DRILLING FLUIDS REPORT DEPTH MW 9.5 VIS 85 PV 28 YP 12 FL 2.6 Gels 9/29/35 CL- FC 0/2 SOL 9.1 SD 0.01 OIL 82/18 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 XL 25KSI, ADR, DGR, ALD, CTN, MRIL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 308 @ 10631 23 @ 10537 91.5 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 61253 @ 10631 1638 @ 10537 14558.9 CONNECTION GAS HIGH ETHANE (C-2) 1788 @ 10348 65 @ 10660 506.1 AVG PROPANE (C-3) 660 @ 10483 15 @ 10660 148.9 CURRENT BUTANE (C-4) 253 @ 10483 4 @ 10694 61.2 CURRENT BACKGROUND/AVG 57u / 54u PENTANE (C-5) 68 @ 10301 0 @ 10673 25.9 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 30% Tuff claystone 30% Tuff Siltstone 20% Sandstone 20% Coal PRESENT LITHOLOGY 40% Tuff claystone 40% Tuff Siltstone 20% Sandstone DAILY ACTIVITY SUMMARY Continue drilling 8.5” hole as per Directional driller to 10661’. Service rig and obtain slow pump rates. Continue drilling to 10694’ at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Rick Brumley, Rance Pederson DATE Nov 17, 2017 DEPTH 11032' PRESENT OPERATION Short Trip TIME 23:59:59 YESTERDAY 10691' 24 HOUR FOOTAGE 341' CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10973 55.69 167.87 10314.28 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Hughes ymera Hybrid 5248200 1x15,2x16,1x18 9887' 1141' 47:55 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 156.6 @ 10981 1.4 @ 10899 32.1 6.51 FT/HR SURFACE TORQUE 13253 @ 10974 7726 @ 10721 9840.8 9639.66 FT-LBS WEIGHT ON BIT 26 @ 10742 12 @ 10910 20.8 24.76 KLBS ROTARY RPM 122 @ 11008 78 @ 10745 113.6 79.26 RPM PUMP PRESSURE 3129 @ 10830 2057 @ 10717 2939.4 3016.60 PSI DRILLING FLUIDS REPORT DEPTH 11030 MW 9.5 VIS 78 PV 33 YP 13 FL 2.6 Gels 10/31/42 CL- FC 0/2 SOL 9.6 SD 0.01 OIL 83.1/16.9 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 XL 25KSI, ADR, DGR, ALD, CTN, MRIL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 441 @ 10820 43 @ 10956 103.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 87557 @ 10820 5557 @ 10954 17319.4 CONNECTION GAS HIGH ETHANE (C-2) 1606 @ 11018 74 @ 10709 447.1 AVG PROPANE (C-3) 451 @ 11018 14 @ 10743 95.7 CURRENT BUTANE (C-4) 156 @ 11019 0 @ 10725 26.3 CURRENT BACKGROUND/AVG 12u / 35u PENTANE (C-5) 47 @ 11019 0 @ 10820 10.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 30% Sandstone, 30% Tuff Siltstone, 30% Tuff Claystone, 10% Coal PRESENT LITHOLOGY 80% Sandstone, 10% Tuff Siltstone, 10% Tuff Claystone DAILY ACTIVITY SUMMARY Continued drilling to 11,032.’ Pumped sweep and circulated bottoms up. Currently pulling out of hole for short trip. ’ CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Rick Brumley, Rance Pederson DATE Nov 18 2017 DEPTH 11032' PRESENT OPERATION Circulating TIME 23:59:59 YESTERDAY 11032' 24 HOUR FOOTAGE CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10973 55.69 167.87 10314.28 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Hughes ymera Hybrid 5248200 1x15,2x16,1x18 9887' 1141' 47:55 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 11/17/2017 MW 9.5 VIS 78 PV 33 YP 13 FL 2.6 Gels 10/31/42 CL- FC 0/2 SOL 8.6 SD 0.01 OIL 83.1/16.9 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 XL 25KSI, ADR, DGR, ALD, CTN, MRIL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 921u 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 100u/ 90u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY No new footage drilled PRESENT LITHOLOGY 80% Sandstone, 10% Tuff Siltstone, 10% Tuff Claystone DAILY ACTIVITY SUMMARY Picked up out of hole for short trip to 9,846’. During rig service found a broken bracket on D/S E-Brake. Brake was repaired and tripped back in hole. Tight spots while TIH fired off 3 jars @ 30k. Reestablished circulation and washed and reamed the hole. Currently pumping sweep and circulating at 11,027’ CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Rick Brumley, Rance Pederson DATE Nov 19, 2017 DEPTH 11168 PRESENT OPERATION POOH TIME 23:59 YESTERDAY 11032 24 HOUR FOOTAGE 136 CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11096.79 59.32 162.77 10220.96 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Hughes ymera Hybrid 5248200 1x15,2x16,1x18 9887' 1277 57.1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 134.8 @ 11100 1.2 @ 11124 21.8 4.50 FT/HR SURFACE TORQUE 11892 @ 11045 8178 @ 11163 10016.7 8384.70 FT-LBS WEIGHT ON BIT 26 @ 11155 18 @ 11096 22.9 25.09 KLBS ROTARY RPM 140 @ 11145 79 @ 11032 116.8 100.69 RPM PUMP PRESSURE 3238 @ 11158 2092 @ 11083 2880.5 3230.12 PSI DRILLING FLUIDS REPORT DEPTH 11168 MW 9.5 VIS 90 PV 29 YP 11 FL 2.6 Gels 10/29/41 CL- FC 0/2 SOL 10.1 SD 0.01 OIL 84.1/15.9 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 XL 25KSI, ADR, DGR, ALD, CTN, MRIL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 102 @ 11149 34 @ 11093 70.5 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 16680 @ 11047 4158 @ 11093 10766.1 CONNECTION GAS HIGH ETHANE (C-2) 1208 @ 11150 124 @ 11034 759.9 AVG PROPANE (C-3) 305 @ 11150 24 @ 11034 162.0 CURRENT BUTANE (C-4) 89 @ 11150 7 @ 11035 47.1 CURRENT BACKGROUND/AVG - / 76u PENTANE (C-5) 39 @ 11151 0 @ 11034 19.4 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 80% Tuff Sandstone 10% Tuff Claystone 10% Tuff Siltstone DAILY ACTIVITY SUMMARY Circulate sweep out, 10bbls late with 10% increase. Drill ahead to 11096’ and perform a rig service. Continue drilling ahead to 11168’ and circulate bottoms up. Set back one stand of drill pipe, Kelly up and pump a sweep. Sweep back late by 20bbls with 50% increase in cuttings. Monitor well (static). Pull out of hole through tight spots that correlated with coals at 9120’ and 9076’. Monitor well (static). Continue pulling out of hole at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2577.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Rick Brumley / Rance Pederson DATE Nov 20, 2017 DEPTH 11168 PRESENT OPERATION Testing BOP's TIME 23:59 YESTERDAY 11168 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11096.79 59.32 162.77 10220.96 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Hughes ymera Hybrid 5248200 1x15,2x16,1x18 9887' 11168' 1281' 57.1 2-5-BT-G-E-I-WT ROP 3 8.5" NOV/REED SK716M A234355 7x12 11168" DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 11168' MW 9.65 VIS 221 PV 27 YP 13 FL 2.4 Gels 11/33/44 CL- FC 0/2 SOL 10.3 SD 0.01 OIL 84.1/15.9 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 Dirigo Hybrid STD, ADR, DGR, ALD, CTN 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 pulling out of the hole and lay down BHA. Pick up BHA #4 and shallow test MWD. Run in hole to 2923’ and fill pipe. Continue tripping into hole to 8081’. Cut and slip 97’ of drill line. Troubleshoot turning off ABG tool on MWD. R/U to test BOP’s and begin testing. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Rick Brumley / Rance Pederson / Marvin Rogers DATE Nov 21, 2017 DEPTH 11240' PRESENT OPERATION Troubleshoot mud pump noise. TIME 23:59 YESTERDAY 11168' 24 HOUR FOOTAGE 72' CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11096.79' 59.32 162.77 10220.96' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" NOV/REED SK716M A234355 7x12 11168' 72' 2.2 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 134 @ 11100 4.5 @ 11168 58.2 22.66 FT/HR SURFACE TORQUE 12781 @ 11184 275 @ 11180 10561.4 10765.76 FT-LBS WEIGHT ON BIT 149 @ 11181 5 @ 11182 14.0 8.24 KLBS ROTARY RPM 140 @ 11178 15 @ 11180 136.7 140.08 RPM PUMP PRESSURE 3230 @ 11168 1339 @ 11181 2646.2 2722.75 PSI DRILLING FLUIDS REPORT DEPTH 11/20/2017 MW 9.65 VIS 221 PV 27 YP 13 FL 2.4 Gels 11/33/44 CL- FC 0/2 SOL 10.3 SD 0.01 OIL 84.1/16.9 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 Dirigo Hybrid STD, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 114 @ 11231 20 @ 11184 58.3 TRIP GAS 519u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 20442 @ 11232 2811 @ 11184 9521.5 CONNECTION GAS HIGH ETHANE (C-2) 735 @ 11232 34 @ 11184 387.1 AVG PROPANE (C-3) 347 @ 11232 11 @ 11183 137.0 CURRENT BUTANE (C-4) 99 @ 11232 2 @ 11186 39.7 CURRENT BACKGROUND/AVG 33u / 22u PENTANE (C-5) 23 @ 11168 0 @ 11192 7.2 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 80% Tuff Sandstone 10% Tuff Siltstone 10% Tuff Claystone PRESENT LITHOLOGY 80% Tuff Sandstone 10% Tuff Siltstone 10% Tuff Claystone DAILY ACTIVITY SUMMARY Finish testing BOP’s and lay down testing equipment. Test geo pilot (good). Trip into hole to 10625’, wash and ream to bottom. Pump sweep and drill ahead to 11181’. MP #1 liner flange bolt broke, repair pump while circulating on #2. Drill ahead 11240’ and get SPR’s. Troubleshoot pumps to reduce the noise for the MWD tools at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Marvin Rogers / Rance Pederson DATE Nov 22, 2017 DEPTH 11471 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 11240 24 HOUR FOOTAGE 231 CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11426.15 66.59 163.20 10370.86 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" NOV/REED SK716M A234355 7x12 11168' 303' 9.25 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 102.2 @ 11241 4.3 @ 11262 37.8 38.14 FT/HR SURFACE TORQUE 11724 @ 11276 8540 @ 11263 10556.2 10846.87 FT-LBS WEIGHT ON BIT 12 @ 11261 5 @ 11427 8.6 7.10 KLBS ROTARY RPM 140 @ 11240 108 @ 11276 138.1 139.41 RPM PUMP PRESSURE 2729 @ 11327 999 @ 11402 2679.8 2670.42 PSI DRILLING FLUIDS REPORT DEPTH 11427' MW 9.5 VIS 87 PV 29 YP 12 FL 2.4 Gels 12/32/41 CL- FC 0/2 SOL 9.8 SD 0.01 OIL 84.2/15.8 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 Dirigo Hybrid STD, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 179 @ 11342 23 @ 11264 93.6 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 30597 @ 11344 2762 @ 11264 15182.6 CONNECTION GAS HIGH ETHANE (C-2) 1447 @ 11344 103 @ 11271 721.0 AVG PROPANE (C-3) 774 @ 11344 52 @ 11269 343.1 CURRENT BUTANE (C-4) 278 @ 11344 20 @ 11271 116.8 CURRENT BACKGROUND/AVG 119u / 93u PENTANE (C-5) 67 @ 11342 0 @ 11267 30.4 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 80% Tuff Sandstone 10% Tuff Siltstone 10% Tuff Claystone PRESENT LITHOLOGY 80% Tuff Sandstone 10% Tuff Siltstone 10% Tuff Claystone DAILY ACTIVITY SUMMARY Continue drilling down to 11402’. Circulate and reciprocate pipe while replacing fluid end in mud pump #1. Wait on boat with fluid end pod. Continue installing fluid end pod #1. Circulate and reciprocate pipe. Run mud pump #1 through bleeder. Test mud pump #1 with mud pump #2 at drilling rate. Drill down to 11426’. Re-torque bolts on mud pump #1 fluid end pod. Service drawworks. Continue drilling down to 11471’ at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Marvin Rogers / Rance Pederson DATE Nov 23, 2017 DEPTH 11718 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 11471 24 HOUR FOOTAGE 247 CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11489.62 67.87 163.82 10395.43 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" NOV/REED SK716M A234355 7x12 11168' 550' 23.0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 91.9 @ 11489 1.9 @ 11574 27.3 83.31 FT/HR SURFACE TORQUE 13455 @ 11576 8033 @ 11566 10959.5 11115.75 FT-LBS WEIGHT ON BIT 14 @ 11574 1 @ 11522 10.1 10.05 KLBS ROTARY RPM 161 @ 11555 139 @ 11488 154.8 160.03 RPM PUMP PRESSURE 2709 @ 11526 2090 @ 11504 2615.7 2584.90 PSI DRILLING FLUIDS REPORT DEPTH 11678' MW 9.5 VIS 87 PV 30 YP 13 FL 2.4 Gels 12/36/45 CL- FC 0/2 SOL 9.9 SD 0.01 OIL 85.3/14.7 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 Dirigo Hybrid STD, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 149 @ 11582 32 @ 11554 81.5 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 22760 @ 11583 3784 @ 11554 11480.4 CONNECTION GAS HIGH ETHANE (C-2) 2112 @ 11583 228 @ 11551 1188.9 AVG PROPANE (C-3) 449 @ 11583 65 @ 11553 239.5 CURRENT BUTANE (C-4) 155 @ 11496 30 @ 11561 74.4 CURRENT BACKGROUND/AVG 89u / 85u PENTANE (C-5) 56 @ 11618 13 @ 11522 38.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 80% Tuff Sandstone 10% Tuff Siltstone 10% Tuff Claystone PRESENT LITHOLOGY 80% Tuff Sandstone 10% Tuff Siltstone 10% Tuff Claystone DAILY ACTIVITY SUMMARY Continue drilling 8.5” hole as per DD. Troubleshoot brake and PLC issues and recheck torque on bolts for fluid end of MP #1. Continue drilling to 11718’. Obtain SPR’s, service rig and check torque on MP #1 fluid end bolts. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Marvin Rodgers/ Rance Pederson DATE Nov 24, 2017 DEPTH 11812 PRESENT OPERATION POOH TIME 23:59:59 YESTERDAY 11718 24 HOUR FOOTAGE 94' CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11736.08 72.91 170.37 10480.88 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" NOV/REED SK716M A234355 7x12 11168' 644' 26.8 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 119.2 @ 11797 1.1 @ 11788 24.6 15.37 FT/HR SURFACE TORQUE 13804 @ 11811 10327 @ 11719 11561.3 12198.39 FT-LBS WEIGHT ON BIT 12 @ 11795 6 @ 11798 10.3 8.83 KLBS ROTARY RPM 160 @ 11718 136 @ 11742 142.5 138.28 RPM PUMP PRESSURE 2741 @ 11798 2071 @ 11736 2693.2 2668.81 PSI DRILLING FLUIDS REPORT DEPTH 11813 MW 9.55 VIS 133 PV 31 YP 15 FL 2.4 Gels 12/36/48 CL- FC 0/2 SOL 10.2 SD 0.01 OIL 85.3/14.7 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 Dirigo Hybrid STD, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 95 @ 11808 55 @ 11763.00000 75.7 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 12478 @ 11810 6963 @ 11797 9832.5 CONNECTION GAS HIGH ETHANE (C-2) 1992 @ 11810 986 @ 11797 1428.4 AVG PROPANE (C-3) 234 @ 11810 138 @ 11797 194.9 CURRENT BUTANE (C-4) 66 @ 11782 42 @ 11797 56.0 CURRENT BACKGROUND/AVG - / 38u PENTANE (C-5) 53 @ 11783 33 @ 11798 45.9 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 80% Tuff Sandstone 10% Tuff Siltstone 10% Tuff Claystone PRESENT LITHOLOGY 80% Tuff Sandstone 10% Tuff Siltstone 10% Tuff Claystone DAILY ACTIVITY SUMMARY Continued drilling to 11,812’ MD when Geo Pilot quit responding. Circulated and pumped a sweep then picked up out of the hole. Pumped out of hole at 10,303’-8,112’ and washed through tight spots correlated with coals. Serviced the drawworks and traveling equipment. Observed well (Static) currently pulling out of hole at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Marvin Rogers/ Rance Pederson DATE Nov 25, 2017 DEPTH 11812 PRESENT OPERATION trip in hole TIME 23:59:59 YESTERDAY 11812 24 HOUR FOOTAGE CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11736.08 72.91 170.37 10480.88 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" NOV/REED SK716M A234355 7x12 11168' 11812' 644' 26.8 1-3-CT-A-X-I-CT DTF 4 8.5" V711PDG1HRU PDC 4009435 3x12, 5x11 11812' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 11/25/2017 MW 9.55 VIS 133 PV 31 YP 15 FL 2.4 Gels 12/36/48 CL- FC 0/2 SOL 10.2 SD 0.01 OIL 85.3/14.7 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 Xl 25KSI, ADR, DGR, ALD, CTN 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 80% Tuff Sandstone 10% Tuff Siltstone 10% Tuff Claystone DAILY ACTIVITY SUMMARY Continue POOH, unload sources, download MWD and lay down BHA #4. Pick up BHA #5 and shallow test (not pulsing). Troubleshoot MWD tools and determine pulser bad. Change out pulser and test (good). Trip in hole to 4170’ and fill pipe. Trip in hole to 8080’ and work boat. Slip and cut 81’ of drilling line. Service rig and change out 3” nipple on jumper hose. Continue tripping into hole at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Marvin Rogers/ Rance Pederson DATE Nov 26, 2017 DEPTH 11959 PRESENT OPERATION Servicing Rig TIME 23:59 YESTERDAY 11812 24 HOUR FOOTAGE 147 CASING INFORMATION 9 5/8" 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 4 8.5" V711PDG1HRU PDC 4009435 3x12, 5x11 11812' 147' 17.0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 56.9 @ 11881 1.5 @ 11922 13.5 7.67 FT/HR SURFACE TORQUE 12240 @ 11947. 8335 @ 11923 10266.4 10305.32 FT-LBS WEIGHT ON BIT 13 @ 11838. 5 @ 11933 9.3 7.22 KLBS ROTARY RPM 160 @ 11943 119 @ 11923 149.7 120.52 RPM PUMP PRESSURE 2857 @ 11813 2162 @ 11959 2589.7 2162.83 PSI DRILLING FLUIDS REPORT DEPTH 11952 MW 9.5 VIS 80 PV 28 YP 14 FL 2.4 Gels 13/31/39 CL- FC 0/2 SOL 10.5 SD 0.01 OIL 85.8/14.2 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 Xl 25KSI, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 184 @ 11815 24 @ 11927.00000 56.7 TRIP GAS 547u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 35786 @ 11815 2801 @ 11927 8694.3 CONNECTION GAS HIGH ETHANE (C-2) 1668 @ 11812 118 @ 11932 580.2 AVG PROPANE (C-3) 310 @ 11882 18 @ 11827 111.7 CURRENT BUTANE (C-4) 88 @ 11882 2 @ 11827 33.5 CURRENT BACKGROUND/AVG 33u / 26u PENTANE (C-5) 50 @ 11812 0 @ 11826 17.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 90% Tuff Sandstone 10% Tuff Siltstone PRESENT LITHOLOGY 90% Tuff Sandstone 10% Tuff Siltstone DAILY ACTIVITY SUMMARY Continue tripping in hole, working through tight spots to 11741’. Wash and ream to bottom. Drill ahead with various parameters as to try and build angle to 11959’. Troubleshoot G-total and stick slip issues. Servicing drawworks, washpipe and HPUs at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Marvin Rogers/ Rance Pederson DATE Nov 27, 2017 DEPTH 12059 PRESENT OPERATION Time Drilling at 1 FPH TIME 23:59 YESTERDAY 11960 24 HOUR FOOTAGE 101 CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11985.98' 73.31 176.86 10548.11' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" V711PDG1HRU PDC 4009435 3x12, 5x11 11812' 248' 37.1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 87.5 @ 11971 1.0 @ 12059 13.5 1.00 FT/HR SURFACE TORQUE 13094 @ 12049 8836 @ 12053 10427.6 8912.79 FT-LBS WEIGHT ON BIT 14 @ 12011 1 @ 12052 9.7 3.20 KLBS ROTARY RPM 159 @ 12048 99 @ 12053 153.2 109.56 RPM PUMP PRESSURE 2564 @ 11960 1024 @ 12054 1929.9 1082.95 PSI DRILLING FLUIDS REPORT DEPTH 11952 MW 9.5 VIS 80 PV 28 YP 14 FL 2.4 Gels 13/31/39 CL- FC 0/2 SOL 10.5 SD 0.01 OIL 85.8/14.2 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 Xl 25KSI, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 68 @ 12029 17 @ 12055 45.1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 9796 @ 12028 1809 @ 12058 5988.0 CONNECTION GAS HIGH ETHANE (C-2) 1132 @ 12029 41 @ 12059 641.9 AVG PROPANE (C-3) 151 @ 12005 11 @ 12059 85.2 CURRENT BUTANE (C-4) 40 @ 12005 7 @ 12059 23.8 CURRENT BACKGROUND/AVG 16u / 30u PENTANE (C-5) 32 @ 11986 4 @ 12058 17.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 90% Tuff Sandstone 10% Tuff Siltstone PRESENT LITHOLOGY 90% Tuff Sandstone 10% Tuff Siltstone DAILY ACTIVITY SUMMARY Continue drilling ahead and attempt to build angle to 12052’. Pick up and time drill at 1 FPH from 12050’-12055’ with minimal WOB. Inclination 73.22. Continue to time drill at 1 FPH from 12055’-12061’ with minimal WOB. Inclination 73.48 at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Marvin Rogers/ Rance Pederson DATE Nov 28, 2017 DEPTH 12180 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 12059 24 HOUR FOOTAGE 121 CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12112.83 75.87 182.56 10582.98 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" V711PDG1HRU PDC 4009435 3x12, 5x11 11812' 369' 59.6 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 167.5 @ 12112 0.7 @ 12078 14.2 28.53 FT/HR SURFACE TORQUE 12511 @ 12111 8062 @ 12061 10583.0 11357.53 FT-LBS WEIGHT ON BIT 15 @ 12085 3 @ 12060 9.8 9.75 KLBS ROTARY RPM 160 @ 12126 109 @ 12059 155.0 160.57 RPM PUMP PRESSURE 2631 @ 12180 1064 @ 12063 2342.1 2631.94 PSI DRILLING FLUIDS REPORT DEPTH 12173' MW 9.5 VIS 79 PV 32 YP 13 FL 2.4 Gels 12/32/41 CL- FC 0/2 SOL 9.7 SD 0.01 OIL 82.2/17.8 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 Xl 25KSI, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 77 @ 12180 16 @ 12068.00000 44.3 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 10331 @ 12180 1895 @ 12061 5739.4 CONNECTION GAS HIGH ETHANE (C-2) 1541 @ 12180 32 @ 12067 800.4 AVG PROPANE (C-3) 173 @ 12180 6 @ 12071 76.3 CURRENT BUTANE (C-4) 37 @ 12180 0 @ 12082 16.4 CURRENT BACKGROUND/AVG 44u / 52u PENTANE (C-5) 39 @ 12180 0 @ 12077 18.2 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 90% Tuff Sandstone 10% Tuff Siltstone PRESENT LITHOLOGY 90% Tuff Sandstone 10% Tuff Siltstone DAILY ACTIVITY SUMMARY Continue time drilling at 1 FPH to 12078’. Directional drill to 12180’ at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2805.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Marvin Rogers / Rance Pederson DATE Nov 29, 2017 DEPTH 12420' PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 12180' 24 HOUR FOOTAGE 240' CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12357.9' 79.67 192.93 10633.88' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" V711PDG1HRU PDC 4009435 3x12, 5x11 11812' 609' 79.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 98.1 @ 12245 0.5 @ 12223 13.4 21.91 FT/HR SURFACE TORQUE 12055 @ 12183 9230 @ 12398 10662.6 10646.58 FT-LBS WEIGHT ON BIT 12 @ 12235 6 @ 12241 9.3 10.32 KLBS ROTARY RPM 160 @ 12180 120 @ 12223 145.1 121.21 RPM PUMP PRESSURE 2710 @ 12264 1501 @ 12240 2549.9 2498.35 PSI DRILLING FLUIDS REPORT DEPTH 12410' MW 9.5 VIS 73 PV 31 YP 14 FL 2.4 Gels 13/34/45 CL- FC 0/2 SOL 9.6 SD 0.01 OIL 83.1/16.9 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 Xl 25KSI, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 77 @ 12180 23 @ 12409 45.8 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 10331 @ 12180 2730 @ 12237 5603.8 CONNECTION GAS HIGH ETHANE (C-2) 1541 @ 12180 285 @ 12409 805.7 AVG PROPANE (C-3) 173 @ 12180 41 @ 12409 92.2 CURRENT BUTANE (C-4) 40 @ 12186 14 @ 12318 25.3 CURRENT BACKGROUND/AVG 32u / 32u PENTANE (C-5) 40 @ 12181 10 @ 12397 25.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 90% Tuff Sandstone 10% Tuff Siltstone PRESENT LITHOLOGY 80% Tuff Sandstone 20% Tuff Siltstone DAILY ACTIVITY SUMMARY Continue drilling ahead to 12420’ as per directional driller. Service drawworks, top drive and check torque on mud pump fluid end pods at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2805.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Marvin Rogers / Rance Pederson DATE Nov 30, 2017 DEPTH 12450 PRESENT OPERATION L/D BHA TIME 23:59 YESTERDAY 12420 24 HOUR FOOTAGE 30 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12390.8 79.86 194.06 4303.07 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" V711PDG1HRU PDC 4009435 3x12, 5x11 11812' 12450' 639' 82.0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 59.0 @ 12421 3.0 @ 12431 13.0 9.50 FT/HR SURFACE TORQUE 10874 @ 12449 9678 @ 12431 10730.7 10874.71 FT-LBS WEIGHT ON BIT 10 @ 12420 7 @ 12423 8.8 9.21 KLBS ROTARY RPM 121 @ 12420 118 @ 12442 122.6 118.46 RPM PUMP PRESSURE 2517 @ 12426 2468 @ 12434 2581.0 2499.16 PSI DRILLING FLUIDS REPORT DEPTH 11/29/2017 MW 9.5 VIS 73 PV 31 YP 14 FL 2.4 Gels 13/34/45 CL- FC 0/2 SOL 9.6 SD 0.01 OIL 83.1/16.9 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 Xl 25KSI, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 51 @ 12421 28 @ 12432 41.5 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 7490 @ 12421 3359 @ 12422 5405.3 CONNECTION GAS HIGH ETHANE (C-2) 728 @ 12438 343 @ 12422 581.7 AVG PROPANE (C-3) 116 @ 12439 53 @ 12432 89.0 CURRENT BUTANE (C-4) 36 @ 12439 17 @ 12422 27.9 CURRENT BACKGROUND/AVG PENTANE (C-5) 23 @ 12421 11 @ 12422 18.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 90% Tuff Sandstone 10% Tuff Siltstone DAILY ACTIVITY SUMMARY Continue drilling ahead to 12450’ but unable to desired azimuth turn. Pump high viscosity sweep and circulate hole clean. Pull out of hole to 11304’ then pump out until the shoe. Service drawworks, top drive and crown. Pump slug and pull out of the hole. Laying down BHA at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2805.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Marvin Rogers / Rance Pederson DATE Dec 01, 2017 DEPTH 12493 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 12450 24 HOUR FOOTAGE 43 CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12448.72 81.35 195.73 10649.18 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" V711PDG1HRU PDC 4009435 3x12, 5x11 11812' 12450' 639' 82.0 2-3-WT-A-X-I-ER BHA 5 8.5" Baker Kymera HP524 7046452 2x18, 2x14 12450' 43' 3.0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 49.6 @ 12481 2.5 @ 12451 15.9 10.69 FT/HR SURFACE TORQUE 11179 @ 12481 9551 @ 12450 10796.7 10400.44 AMPS WEIGHT ON BIT 19 @ 12475 6 @ 12451 17.4 19.71 KLBS ROTARY RPM 155 @ 12450 117 @ 12451 122.0 118.87 RPM PUMP PRESSURE 2772 @ 12450 2432 @ 12455 2747.1 2720.10 PSI DRILLING MUD REPORT DEPTH 12474 MW 9.55 VIS 105 PV 33 YP 15 FL 2.3 Gels 15/36/46 CL- FC 0/2 SOL 10.2 SD 0.01 OIL 83.0/17.0 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 Xl 25KSI, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 92 @ 12451 46 @ 12490 70.9 TRIP GAS 246u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 18431 @ 12451 6309 @ 12450 12624.2 CONNECTION GAS HIGH ETHANE (C-2) 738 @ 12450 85 @ 12451 404.5 AVG PROPANE (C-3) 217 @ 12477 20 @ 12451 154.1 CURRENT BUTANE (C-4) 65 @ 12479 7 @ 12451 47.0 CURRENT BACKGROUND/AVG 48u / 55u PENTANE (C-5) 27 @ 12450 0 @ 12454 9.2 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 90% Tuff Sandstone 10% Tuff Siltstone PRESENT LITHOLOGY 90% Tuff Sandstone 10% Tuff Siltstone DAILY ACTIVITY SUMMARY Lay down BHA #5, M/U BHA #6 and shallow test (good). Run in hole to 8076’. Perform rig service. Trip into hole on elevators to 10655’. Wash and ream down through 10991’. Trip in on elevators from 10991’ to 12420’. Wash and ream to bottom. Drill ahead per directional driller to 12493’ at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2805.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Marvin Rogers / Rance Pederson DATE Dec 02, 2017 DEPTH 12735 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 12493 24 HOUR FOOTAGE 242 CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12697.49 82.22 183.57 10682.73 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5" Baker Kymera HP524 7046452 2x18, 2x14 12450' 242' 23 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 89.3 @ 12542 0.1 @ 12659 16.2 5.28 FT/HR SURFACE TORQUE 12533 @ 12545 9043 @ 12671 10698.3 10278.41 AMPS WEIGHT ON BIT 25 @ 12726 11 @ 12541 19.2 24.73 KLBS ROTARY RPM 160 @ 12711 117 @ 12520. 140.4 159.75 RPM PUMP PRESSURE 3108 @ 12668 1897 @ 12681 2614.5 2592.60 PSI DRILLING MUD REPORT DEPTH 12728' MW 9.53 VIS 78 PV 32 YP 15 FL 2.4 Gels 13/34/42 CL- FC 0/2 SOL 10.2 SD 0.01 OIL 83.0/17.0 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 Xl 25KSI, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 142 @ 12609 20 @ 12683 70.5 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 23778 @ 12610 2421 @ 12683 11195.0 CONNECTION GAS HIGH ETHANE (C-2) 1366 @ 12610 93 @ 12683 667.8 AVG PROPANE (C-3) 591 @ 12610 23 @ 12713 268.9 CURRENT BUTANE (C-4) 235 @ 12610 15 @ 12726 99.3 CURRENT BACKGROUND/AVG 24u / 28u PENTANE (C-5) 61 @ 12616 2 @ 12726 32.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 90% Tuff Sandstone 10% Tuff Siltstone PRESENT LITHOLOGY 90% Tuff Sandstone 10% Tuff Siltstone DAILY ACTIVITY SUMMARY Drilled from 12493’ to 12753’as per directional driller. Continue drilling at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2805.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Marvin Rogers / Rance Pederson DATE Dec 03, 2017 DEPTH 13115' PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 12735' 24 HOUR FOOTAGE 380' CASING INFORMATION 9.5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13069.89 83.74 176.67 10736.27 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5" Baker Kymera HP524 7046452 2x18, 2x14 12450 622' 41.75 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 45 @ 12917 0.4 @ 12880 23.5 21.30 FT/HR SURFACE TORQUE 12403 @ 12902 9928 @ 12740 11369.1 12027.36 AMPS WEIGHT ON BIT 24 @ 12735 15 @ 12790 19.7 20.02 KLBS ROTARY RPM 159 @ 12735 137 @ 12744 139.8 139.85 RPM PUMP PRESSURE 2690 @ 12999 1933 @ 12938 2595.8 2676.11 PSI DRILLING MUD REPORT DEPTH 13104 MW 9.5 VIS 76 PV 30 YP 16 FL 2.4 Gels 13/31/40 CL- FC 0/2 SOL 10.3 SD 0.01 OIL 83.8/16.2 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Geo-Pilot 7600 Xl 25KSI, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 196 @ 12910 24 @ 12767 120.7 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 33151 @ 12906 2748 @ 12767 19316.2 CONNECTION GAS HIGH ETHANE (C-2) 1678 @ 12948 129 @ 12767 1071.3 AVG PROPANE (C-3) 919 @ 13058 20 @ 12739 552.3 CURRENT BUTANE (C-4) 381 @ 13037 11 @ 12768 176.1 CURRENT BACKGROUND/AVG 61u / 121u PENTANE (C-5) 104 @ 13041 0 @ 12739 49.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 90% Tuff Sandstone 10% Tuff Siltstone PRESENT LITHOLOGY 90% Tuff Sandstone 10% Tuff Siltstone DAILY ACTIVITY SUMMARY Drilled from 12753’ to 13104’ as per directional driller. Service top drive, drawworks and repair bad 480 receptacle in MCC room. Continue drilling at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2805.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Marvin Rogers / Rance Pederson DATE Dec 04, 2017 DEPTH 13493' PRESENT OPERATION POOH at TD TIME 23:59 YESTERDAY 13115' 24 HOUR FOOTAGE 378' CASING INFORMATION 9 5/8" @ 8130' TOW SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13461.18 100.32 179.23 10717.8 13493.00 100.32 179.23 10712.10 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5" Baker Kymera HP524 7046452 2x18, 2x14 12450' 13493' 1043' 59.13 NA TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 134.9 @ 13289.00000 2.3 @ 13463.00000 24.9 22.00000 FT/HR SURFACE TORQUE 14631 @ 13416.00000 10248 @ 13333.00000 12684.2 11845.07031 AMPS WEIGHT ON BIT 23 @ 13142.00000 7 @ 13474.00000 19.3 19.23491 KLBS ROTARY RPM 157 @ 13482.00000 135 @ 13132.00000 147.0 157.84000 RPM PUMP PRESSURE 2778 @ 13140.00000 2048 @ 13162.00000 2665.3 2709.75000 PSI DRILLING MUD REPORT DEPTH 13493' MW 9.5 VIS 71 PV 28 YP 14 FL 2.4 Gels 12/28/36 CL- FC 0/2 SOL 10.8 SD .01 OIL 84/16 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 12450' TO 13493' TOOLS Geo-Pilot 7600 XI 25KSI, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 273 @ 13415.00000 35 @ 13474.00000 109.4 TRIP GAS NA CUTTING GAS 0 @ 13493 0 @ 13493 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C-1) 51672 @ 13415.00000 3452 @ 13475.00000 16851.8 CONNECTION GAS HIGH NA ETHANE (C-2) 1861 @ 13415.00000 206 @ 13475.00000 926.3 AVG NA PROPANE (C-3) 960 @ 13254.00000 55 @ 13475.00000 436.1 CURRENT NA BUTANE (C-4) 418 @ 13280.00000 34 @ 13475.00000 197.7 CURRENT BACKGROUND/AVG 10 PENTANE (C-5) 109 @ 13258.00000 14 @ 13474.00000 66.2 HYDROCARBON SHOWS Slight INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 13345'-13410' Sandstone 114 Light straw stain with cut LITHOLOGY 50% Sandstone, 30% Coal, 20% Tuffaceous Siltstone PRESENT LITHOLOGY 60% Sandstone, 40% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Drilled from 13115' to TD at 13493', POOH to test BOPE, handle BHA. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2805 REPORT BY AL Neubert Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Adam Dorr / Rick Brumley DATE Dec 05, 2017 DEPTH 13493 PRESENT OPERATION Test BOPE TIME 24:00 Hours YESTERDAY 13493 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8130' TOW SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13493' 100.32 179.23 10712.1 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5" bAKER kYMERA hp524 7046452 2x18,2X14 12450' 13493' 1043' 59.13 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0 @ 0 0 @ 0 0 0 FT/HR SURFACE TORQUE 0 @ 0 0 @ 0 0 0 AMPS WEIGHT ON BIT 0 @ 0 0 @ 0 0 0 KLBS ROTARY RPM 0 @ 0 0 @ 0 0 0 RPM PUMP PRESSURE 0 @ 0 0 @ 0 0 0 PSI DRILLING MUD REPORT DEPTH 13493' MW 9.63 VIS 183 PV 28 YP 16 FL 2.4 Gels 13/29/38 CL- FC 0/2 SOL 10.8 SD 0.01 OIL 80.3/19.7 MBL pH Ca+ 12.09 CCI MWD SUMMARY INTERVAL 12450' TO 13493' TOOLS Geo-Pilot 7600 XI 25KSI, ADR, DGR, ALD, CTN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 0 @ 0 0 TRIP GAS 60 pulling CUTTING GAS 0 @ 0 0 @ 0 0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C-1) 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH NA ETHANE (C-2) 0 @ 0 0 @ 0 0 AVG NA PROPANE (C-3) 0 @ 0 0 @ 0 0 CURRENT NA BUTANE (C-4) 0 @ 0 0 @ 0 0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS No Drilling INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Last Samples bottoms up 60% Sandstone, 40% Tuffaceous Siltstne PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue trip out of hole, Rig up and test BOPE, Average gas while pulling 20 units w/ 60 units high. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2805 REPORT BY AL Neubert Hilcorp Alaska LLC Granite Point Field DAILY WELLSITE REPORT GP 24-13 RD2 REPORT FOR Adam Dorr / Rick Brumley DATE Dec 06, 2017 DEPTH 13493 PRESENT OPERATION Circulate @ 12994' TIME 24:00 Hours YESTERDAY 13493 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8130' TOW SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13493' 100.32 179.23 10712.1 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5" bAKER kYMERA hp524 7046452 2x18,2X14 12450' 13493' 1043' 59.13 3,2,RO,N,E,IN,WT,TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0 @ 0 0 @ 0 0 0 FT/HR SURFACE TORQUE 0 @ 0 0 @ 0 0 0 AMPS WEIGHT ON BIT 0 @ 0 0 @ 0 0 0 KLBS ROTARY RPM 0 @ 0 0 @ 0 0 0 RPM PUMP PRESSURE 0 @ 0 0 @ 0 0 0 PSI DRILLING MUD REPORT DEPTH 13493' MW 9.62 VIS 104 PV 28 YP 15 FL 2.6 Gels 13/29/38 CL- FC 0/2 SOL 10.8 SD 0.01 OIL 84/16 MBL pH Ca+ 10.0 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 0 @ 0 0 TRIP GAS 396 CUTTING GAS 0 @ 0 0 @ 0 0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C-1) 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH NA ETHANE (C-2) 0 @ 0 0 @ 0 0 AVG NA PROPANE (C-3) 0 @ 0 0 @ 0 0 CURRENT NA BUTANE (C-4) 0 @ 0 0 @ 0 0 CURRENT BACKGROUND/AVG 20 PENTANE (C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS No Drilling INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Last Samples bottoms up 60% Sandstone, 40% Tuffaceous Siltstne PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finish testing BOPE, L/D BHA, unload sources, M/U cleanout BHA and RIH to 13000', circulate and condition mud. CANRIG PERSONNEL ON BOARD 2 DAILY COST $1910 REPORT BY AL Neubert