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Home My WebLink About218-048MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 29, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. MT6-08 GMTU MT6-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2024 MT6-08 50-103-20772-00-00 218-048-0 G SPT 7949 2180480 1987 3663 3664 3664 3664 300 530 520 500 4YRTST P Sully Sullivan 7/16/2024 4year MIT-IA no issues. OOA - 160/160/160/160 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:GMTU MT6-08 Inspection Date: Tubing OA Packer Depth 1020 2310 2275 2270IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240717100723 BBL Pumped:1.6 BBL Returned:1.6 Thursday, August 29, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 OOA James B. Regg Digitally signed by James B. Regg Date: 2024.08.29 15:45:01 -08'00' TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Mooses Tooth DATE: 12/19/2023 Transmitted: North Slope, Mooses Tooth Unit Via hard drive data drop Moose's Tooth MT6-08 50-103-20772-00 218048_MT6-08_JetCutter_22Apr2022 218048_MT6-08_Puncher_02Feb2022 MT6-09 50-103-20779-00 218134_MT6-09_Puncher_18Feb2022 218134_MT6-09_SBHP_16Feb2022 218134_MT6-09_Tubing Cut_22Feb2022 MT7-01 50-10-320832-00 221052_MT7-01_Perf_29Oct2022 221052_MT7-01_PPROF_03Feb2023 MT7-02 50-103-20840-00 222026_MT7-02_ChemCut_21Dec2022 222026_MT7-02_Plug&Perf_17Apr2023 MT7-03 50-103-20830-00 221024_MT7-03_GR_12Aug23 221024_MT7-03_MechCutter_31Oct23 221024_MT7-03_RBP_1Nov23 MT7-05 50-103-20833-00 221087_MT7-05_PPROF_20Apr2023 221087_MT7-05_SCMT_25Dec2021 MT7-06 50-103-20831-00 221048_MT7-06_IBC-DSLT_04Oct2022 1of 3 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38419 T38420 T38421 T38422 T38423 T38424 T38425 2/29/2024 MT6-08 50-103-20772-00 218048_MT6-08_JetCutter_22Apr2022 218048_MT6-08_Puncher_02Feb2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 10:56:14 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 14, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. MT6-08 GMTU MT6-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/14/2022 MT6-08 50-103-20772-00-00 218-048-0 W SPT 7949 2180480 1987 1052 1060 1053 1051 228 318 316 315 INITAL P Brian Bixby 5/20/2022 Initial MITIA Post RWO as per SUNDRY 321-634 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:GMTU MT6-08 Inspection Date: Tubing OA Packer Depth 480 2200 2160 2150IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220521164119 BBL Pumped:2.9 BBL Returned:2.4 Tuesday, June 14, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9Post RWO SUNDRY 321-634 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 16:30:04 -08'00' From:Hobbs, Greg S To:Loepp, Victoria T (OGC);WSC Rig Advisor Cc:Livingston, Erica J;Regg, James B (OGC);DOA AOGCC Prudhoe Bay Subject:RE: [EXTERNAL]RE: Use on Annular to circulate gas out of MT6-08 Date:Monday, April 25, 2022 7:40:00 AM Victoria, The Annular, Upper and Lower Rams were successfully tested with a 4” joint for the packer fishing operations prior to the next wellbore entry. Thank-you. Greg From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Sunday, April 24, 2022 4:01 PM To: WSC Rig Advisor <wscrigadvisor@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: [EXTERNAL]RE: Use on Annular to circulate gas out of MT6-08 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Please see 20 AAC 25.035(e)(10)(C): “components used must be function pressure-tested before the next wellbore entry” Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: WSC Rig Advisor <wscrigadvisor@conocophillips.com> *07807 37' 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. Sent: Sunday, April 24, 2022 3:33 PM To: AOGCC Web (CED sponsored) <aogcc.web@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com>; Njoku, Johnson <Johnson.Njoku@conocophillips.com>; Buck, Brian R <Brian.R.Buck@conocophillips.com>; Nozaki, Manabu <Manabu.Nozaki@conocophillips.com> Subject: Use on Annular to circulate gas out of MT6-08 All – Please find the attached summary of an event that recently occurred on MT6-08 when the annular was used to circulate gas out of the well. If any questions, please let me know.. Thanks CPAI WSC Rig Advisor wscrigadvisor@conocophillips.com 1-907-263-4546 April 24th, 2022 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Reporting BOPE Use to Circulate Trapped Packer Gas Out of Well Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby reports the use of BOPE equipment to prevent the flow of fluids from a well on April 22nd, 2022 @ 22:30. The well the BOPE has been used on is designated as GMTU MT6-08, a WAG injector currently undergoing workover operations (Sundry Number: 321-634). Doyon 25 was pulling 4-1/2” recompletion tubing at the time of the event with 8.5 ppg sweater brine in the wellbore. The rig had recently conducted a full BOP test on April 19th, 2022. The MT7-08 old upper completion tubing was successfully pulled. While the rig was running the new upper completion tubing at a depth of 5,568 ft MD, the permanent packer prematurely set at 5,468 ft MD (packer depth). The SOV was sheared out to allow the ability to pump into the tubing from the IA. The tubing was then punched below the stuck packer and subsequently cut above the packer at 5,466 ft MD with Eline. The rig was in the process of pulling the cut tubing above the packer when the event occurred. Below is a summary of the sequence of events: 1. POOH L/D 4-1/2" completion string from 5,466' MD to 3,940' MD. Noticed vapor from tubing, checked with handheld and got 20% LEL. 2. Circulate at 3,940' MD at 248 GPM 154 psi. At 100 bbls (589 units gas), shut in well with annular BOP and continue circulating Surface to Surface through the choke. 3. Close in choke and bullhead 320 bbls to have a clean well bore volume of 8.5 ppg fluid at 5 bpm, 840 psi. 4. Shut in pressure decreased to 100 psi. Bled back 4bbls, shut in pressure decreased to 40psi and after 5min decreased to 0psi. 5. Open choke. Open annular. OWFF ~ fluid started dropping in annulus. 6. Pump dry job. Blow down TD and continue L/D 4-1/2" tubing. 7. RU and test annular and ram BOP’s with 4” test joint. If you have any questions or require further information, please contact John Egbejimba or Justin Montague (wscrigadvisor@conocophillips.com) at 907-263-4546. Sincerely, John Egbejimba / Justin Montague WSC Rig Advisor *07807 37' Doyon 25 pulling 4-1/2”recompletion tubing GMTU MT6-08, y p April 22nd,2022 20% LEL. Noticed vapor from tubing, shut in, well with annular BOP Close in choke p yj RU and test annular and ram BOP’s with 4” test joint. From:Brooks, Phoebe L (OGC) To:Rig 25 Cc:Regg, James B (OGC) Subject:RE: Doyon 25 04-19-22 Date:Friday, April 22, 2022 9:19:51 AM Attachments:Doyon 25 04-19-22 Revised.xlsx Attached is a revised report removing the extra 0 from PTD #2180480, changing the CH and ACC Misc. test code fields to "NA" (base on the quantity 0) and adding 2 to the Number of Failures field based on the remarks regarding the choke manifold valves "FPs". Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. -----Original Message----- From: Rig 25 <rig25@doyondrilling.com> Sent: Wednesday, April 20, 2022 12:14 PM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; BLM_AK_AKSO_EnergySection_Notifications@blm.gov Cc: Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com>; Bill Walter <bwalter@doyondrilling.com> Subject: Doyon 25 04-19-22 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. Attached is the test report for 4/19/22 BOPE test Roy Fritts Rig 25 Toolpusher rig25@doyondrilling.com 907-670-4971 *07807 37' 9 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.:25 DATE: 4/19/22 Rig Rep.: Rig Phone: 670-4971 Operator: Op. Phone:670-4970 Rep.: E-Mail Well Name: PTD #22180480 Sundry #321-634 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:3252 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 2P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8"x5000psi P Pit Level Indicators PP #1 Rams 1 2 7/8 x5 1/2 VBR P Flow Indicator PP #2 Rams 1 Blind/Shear P Meth Gas Detector PP #3 Rams 1 2 7/8 x5 1/2 VBR P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3-1/8 x5000psi P Inside Reel valves 0NA HCR Valves 2 3-1/8 x5000psi P Kill Line Valves 2 3-1/8 x5000psi P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1600 P Quantity Test Result 200 psi Attained (sec)13 P No. Valves 15 FP Full Pressure Attained (sec)101 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 6 @ 2033 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:2 Test Time:5.5 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4/18/22 08:01 Waived By Test Start Date/Time:4/19/2022 17:00 (date) (time)Witness Test Finish Date/Time:4/19/2022 22:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Doyon Test Annular, Rams #1 & #3 w/ 4.5" test joint to 250/3500 psi f/ 5/10 min.Test Ram #2 to 250/3500 psi f/ 5/10 min. Test 2ea 4" FOSV & 1ea 4" Dart valve. Function primary & remote BOPE control stations. Test LEL and H2S alarms. BLM witnessed by Quinn Sawyer. FP: Choke manifold valves #7 & 8 - Functioned out of order. Removed air, cycled & greased valves. Retested good. R. Fritts / C. Bali CPAI R. Reinhardt / P.Angelle GMTU MT6-08 Test Pressure (psi): rig25@doyondrilling.com Form 10-424 (Revised 02/2022) 2022-0419_BOP_Doyon25_GMTU_MT6-08 9 99 9 9 9 9 9 9 9 9 9 -5HJJ FP FP: Choke manifold valves #7 & 8 'R\RQ%23(7HVW*0780737' 'R\RQ%23(7HVW*0780737' 9 9 ! 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The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϮϭϴϬϰϴϬͲ^Ğƚ͗ϯϲϭϮϭJRBy Abby Bell at 1:43 pm, Dec 21, 2021 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. 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C:\Users\aebell\Desktop\October Data Drop 2021\CPA Data Drop 10252021\2021-10-21_20180_GMTU_MT6-08_CaliperSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 20180 GMTU MT6-08 50-103-20772-00 Caliper Survey 21-Oct-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 Wayne Svejnoha BLM State Office 222 W. 7th Ave., Suite 13 Anchorage, Ak. 99513 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM ____________________________________________ Signatururuurururururururuurururrruururrruruururuuuuue Abby Bell 37' (6HW By Abby Bell at 9:50 am, Oct 25, 2021 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Tuesday, October 19, 2021 9:07 AM To:AOGCC Records (CED sponsored) Subject:FW: GMTU MT6-08 (PTD#218-048-0) Patch Troubleshooting From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, October 7, 2021 3:58 PM To: Smith, Travis T <Travis.T.Smith@conocophillips.com> Cc: Wallace, Chris D (CED) <chris.wallace@alaska.gov>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: Re: GMTU MT6‐08 (PTD#218‐048‐0) Patch Troubleshooting Travis, Please submit a new sundry(10‐403) for the new scope and close out the previous sundry. Thanx, Victoria Sent from my iPhone On Oct 7, 2021, at 3:00 PM, Smith, Travis T <Travis.T.Smith@conocophillips.com> wrote: Victoria & Chris— Yesterday an acoustic LDL was completed on GMTU well MT6‐08 (PTD#218‐048‐0, Sundry #321‐459), and the well was shut‐in and freeze‐protected today per our email below. This LDL did not identify any leak signature from the patch we recently set. Given that our TxIA issue still persists while on injection, coupled with the strong correlation to injection temperature that this leak demonstrates, we now suspect there could be an issue at the tubing seal assembly. Our proposed path forward is to pull the retrievable patch from over the GLM, then set an expandable patch over the tubing seal assembly (12,314’ MD on the attached schematic), then re‐set the patch over the GLM. Would this best be handled as a revision and continuation of Sundry #321‐459, or would you prefer that we submit a 10‐404 for #321‐459 and an additional 10‐403 for the new path forward? Thank you very much for the help, Travis From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, September 29, 2021 7:39 PM To: Smith, Travis T <Travis.T.Smith@conocophillips.com> 2 Cc: Wallace, Chris D (CED) <chris.wallace@alaska.gov>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: [EXTERNAL]Re: GMTU MT6‐08 (PTD#218‐048‐0) Patch Troubleshooting CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Travis, The LDL should be run within two weeks. Otherwise your plan is acceptable. Thanx, Victoria Sent from my iPhone On Sep 29, 2021, at 4:21 PM, Smith, Travis T <Travis.T.Smith@conocophillips.com> wrote: Chris & Victoria— GMTU well MT6‐08 (PTD#218‐048‐0, Sundry #321‐459) recently had a retrievable patch set in the tubing to address a suspected leak in a gas lift mandrel. During the subsequent monitoring period of water injection the TxIA communication appears to be ongoing. Our plan forward is to run another acoustic LDL with the tubing patch still in the well and attempt to determine if there is a leak signature at the patch. If so, we will pull and replace the tubing patch. E‐line crews are at Alpine currently, but on an uncertain time commitment supporting the drilling rigs. We propose leaving the well on stabilized water injection for the time being such that we can run an acoustic LDL at the first opportunity logistically. After the log is complete we will shut‐in the well. We are not intending to perform the MITIA listed in the Sundry unless we can successfully address what looks like an ongoing issue with the patch at the GLM. Please let me know if you have any questions or disagree with the plan. Thanks, Travis Smith WNS Intervention & Integrity Engineer 907‐670‐4014 Travis.T.Smith@conocophillips.com <MT6‐08.pdf> Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG: MT6-08 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replace DV with new 5/28/2021 MT6-08 claytg Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 36.6 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 94.00 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.40 Top (ftKB) 36.7 Set Depth (ftKB) 2,010.6 Set Depth (TVD) … 1,983.9 Wt/Len (l… 68.00 Grade L-80 Top Thread TXP Casing Description INTERMEDIATE 1 OD (in) 9 5/8 ID (in) 8.84 Top (ftKB) 34.6 Set Depth (ftKB) 10,317.7 Set Depth (TVD) … 7,235.3 Wt/Len (l… 40.00 Grade L-80 Top Thread TXP Casing Description INTERMEDIATE 2 OD (in) 7 ID (in) 6.28 Top (ftKB) 32.2 Set Depth (ftKB) 10,018.4 Set Depth (TVD) … 7,072.0 Wt/Len (l… 26.00 Grade L80 Top Thread BTCM Casing Description SDL LINER OD (in) 7 ID (in) 6.28 Top (ftKB) 10,004.0 Set Depth (ftKB) 12,469.5 Set Depth (TVD) … 7,966.1 Wt/Len (l… 26.00 Grade L-80 Top Thread Tenaris Blue Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,004.0 7,064.2 56.95 PACKER SLZX Liner Hanger Packer 7.375 10,036.6 7,082.0 56.96 SEAL ASSY Latching bullet seals NO-GO (Seals 5.76') 6.160 10,039.5 7,083.5 56.96 SETTING SLEEVE HRD-E Liner Sleeve 6.210 10,048.4 7,088.4 56.96 QUICK CONNECT HP Liner Quick Connect,w/Bullet Seals 7" 32# Tenaris Blue 6.151 12,463.2 7,965.6 85.17 STABILIZER Reamer Shoe Stabilizer w/ Spline Profile, 7" 32# MYS110 Tenaris Blue 6.060 Casing Description PRODUCTION LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 12,320.8 Set Depth (ftKB) 20,350.0 Set Depth (TVD) … 7,865.7 Wt/Len (l… 12.60 Grade L-80 Top Thread TXP Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 12,320.8 7,950.2 82.38 PACKER HRDE ZXP Ext. 5.00" upper (16.11') H521 pin 3.875 12,347.4 7,953.6 82.93 HANGER 4-1/2" x 7" Flex Lock V TXP BxP 3.940 Tubing Strings Tubing Description TUBING GAS INJECTION String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 28.8 Set Depth (ft… 12,328.4 Set Depth (TVD) (… 7,951.2 Wt (lb/ft) 12.60 Grade L-80 Top Connection Tblue Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 28.8 28.8 0.00 HANGER FMC 4-1/2" Tubing Hanger Hydril 563 3.958 2,037.2 2,008.9 20.04 NIPPLE NIPPLE,LANDING,4 1/2",X, 3.813", TSH Blue 3.813 11,540.4 7,809.9 71.17 NIPPLE NIPPLE,LANDING,4 1/2", 3.75" DB, TSH Blue 3.750 12,312.9 7,949.2 82.22 NO-GO LOCATOR Locator No-Go 5.77" OD 3.950 12,314.1 7,949.3 82.24 SEAL ASSY Seal Assembly 3.950 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 11,285.3 7,711.6 64.51 CAMCO KBG-2 1 GAS LIFT DMY BK 1" 5/28/2021 Notes: General & Safety End Date Annotation NOTE: MULTIPLE LATERALS, MT6-08, 5/29/2021 7:26:55 AM Vertical schematic (actual) PRODUCTION LINER; 12,320.8 -20,350.0 SDL LINER; 10,004.0-12,469.5 SEAL ASSY; 12,314.1 NO-GO LOCATOR; 12,312.9 NIPPLE; 11,540.4 GAS LIFT; 11,285.3 INTERMEDIATE 1; 34.6- 10,317.7 INTERMEDIATE 2 ; 32.2- 10,018.4 NIPPLE; 2,037.2 SURFACE; 36.7-2,010.6 CONDUCTOR; 36.5-115.0 HANGER; 28.8 WNS INJ KB-Grd (ft) 36.55 Rig Release Date 9/6/2018 MT6-08 ... TD Act Btm (ftKB) 21,102.0 Well Attributes Field Name LOOKOUT Wellbore API/UWI 501032077200 Wellbore Status INJ Max Angle & MD Incl (°) 98.55 MD (ftKB) 17,740.22 WELLNAME WELLBOREMT6-08 Annotation LAST WO: End DateH2S (ppm) DateComment SSSV: NIPPLE From:Davies, Stephen F (OGC) To:Smith, Travis T Cc:Boyer, David L (OGC); Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]GMTU MT6-08 (PTD 218-048; Sundry 321-4559) - Clarification Date:Tuesday, October 12, 2021 12:37:48 PM Thanks Travis. Your email will be sufficient. I’ll make the correction to the Sundry Application form. Apologies for the incorrect operator name. My mistake. Thanks and stay safe, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Tuesday, October 12, 2021 12:33 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]GMTU MT6-08 (PTD 218-048; Sundry 321-4559) - Clarification Sorry, I missed that on the form. We listed the 7” SDL liner (10,004’MD – 12,469’ MD) incorrectly as the perforated liner. The 7” liner is an intermediate liner string, not the perforated production liner. The perforated liner is correctly listed below as 12,520’ – 20,350’ MD. The well, though, is ConocoPhillips not Hilcorp. Would you like a resubmission of the 10-403, or will this correction suffice? Thanks, Travis From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Tuesday, October 12, 2021 11:42 AM To: Smith, Travis T <Travis.T.Smith@conocophillips.com> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]GMTU MT6-08 (PTD 218-048; Sundry 321-4559) - Clarification CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Travis, I’m reviewing Hilcorp’s Sundry Application to patch this well. On the current application form, the perforated depth is shown as: However, from the Well Completion Report form filed by Hilcorp in 2018: To ensure AOGCC’s records and maps are accurate, which is correct? Thanks and stay safe, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Smith, Travis T To:Davies, Stephen F (OGC) Cc:Boyer, David L (OGC); Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]GMTU MT6-08 (PTD 218-048; Sundry 321-4559) - Clarification Date:Tuesday, October 12, 2021 12:33:15 PM Sorry, I missed that on the form. We listed the 7” SDL liner (10,004’MD – 12,469’ MD) incorrectly as the perforated liner. The 7” liner is an intermediate liner string, not the perforated production liner. The perforated liner is correctly listed below as 12,520’ – 20,350’ MD. The well, though, is ConocoPhillips not Hilcorp. Would you like a resubmission of the 10-403, or will this correction suffice? Thanks, Travis From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Tuesday, October 12, 2021 11:42 AM To: Smith, Travis T <Travis.T.Smith@conocophillips.com> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]GMTU MT6-08 (PTD 218-048; Sundry 321-4559) - Clarification CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Travis, I’m reviewing Hilcorp’s Sundry Application to patch this well. On the current application form, the perforated depth is shown as: However, from the Well Completion Report form filed by Hilcorp in 2018: To ensure AOGCC’s records and maps are accurate, which is correct? Thanks and stay safe, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. ! " # " $ %& ' ()! * '$ +, !- ."!! /, +, 01021*-1 3+ - " ' $ 0104 05614 *6.4 ! % $ 05614 1116470*.47 0/2470504 */254 *1(647**1.47 **(47*/214 8 9 + :77 -6#30; ,#.1 050.48$ */249$ < 9+ '7 - 111648$ 0*.48$ 0/248$ 05048$ !3 *1(649$ **1.49$ **(49$ */2149$ !3 0 =: ' ) + - !3 5 = 2" < $ ' " %& ' $ , ' (" < > "$, % $ > >)!? @ ,@> '!!3 %& ! % : % > % :!$ $ ")!?"> A " #B #B *)' ' '< A A C +/1*-0(2#(.6( ) ) '% , .10/4 < $ ' )D $ AAA A 6#30; 015214 *.((4 , C1116#06(/4 , C*1(6#*/((4 <,EF, G< <)) < <)) < <G $%EF< 9! 6 += 01021*17021*7H020.5- A > #8 24 014 A %,I ,I),!$>!% 9)!88))! ! ! !!!""!!!! !3 2 $ !0 ! ! 6" B"< ! " #!! #! $% &'& ()*+,-. )** <7) B&115(1 7I//21 5 $/! ?< !3 0 ( *.4 /*64 )1 ) 01; 5#53.; /#23.; ) 0 $,, 10.54 //.(4 06(24 2%&) 0 3 24 /.64 *0524 *1*04 *; 15.4 11.4 06(/4 */((4 *; 4.& 2**%5& 1#616 13010 " 51' By Samantha Carlisle at 9:22 am, Oct 12, 2021 Travis T. Smith Digitally signed by Travis T. Smith Date: 2021.10.11 15:48:48 -08'00' VTL 01/24/2022 DSR-10/12/21SFD 8/15/2022 RBDMS HEW 10/12/2021 !"#$# # % %&'( !" $ #$ #$%) " *+ , ! "% !"( -./01/..234.5/0/.02/6789/.:8234;7.<523,/99)!=>!)%!) :3?0@>A)% B.5/,/99,71;97</?C37A)?7@DC32.C0234;/02C?C-,7./0 23E/<.2C3;/0.5/:3?0@7;;0C679.0/3?1?:0234.521.2D/?/DC31.07./?.5/ ,/991.29957?F<CDD:32<7.2C3 /<7:1/C-.521.5/,713C. 7../D;./?5/,/995718//315:.)2373?-0//G/;0C./<./?7,72.2347;7.5 -C0,70? )! :82347.<5 :DD70@C-;/07.2C31 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG:MT6-08 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tubing Patch 9/18/2021 MT6-08 praffer Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 36.6 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 94.00 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.40 Top (ftKB) 36.7 Set Depth (ftKB) 2,010.6 Set Depth (TVD) … 1,983.9 Wt/Len (l… 68.00 Grade L-80 Top Thread TXP Casing Description INTERMEDIATE 1 OD (in) 9 5/8 ID (in) 8.84 Top (ftKB) 34.6 Set Depth (ftKB) 10,317.7 Set Depth (TVD) … 7,235.3 Wt/Len (l… 40.00 Grade L-80 Top Thread TXP Casing Description INTERMEDIATE 2 OD (in) 7 ID (in) 6.28 Top (ftKB) 32.2 Set Depth (ftKB) 10,018.4 Set Depth (TVD) … 7,072.0 Wt/Len (l… 26.00 Grade L80 Top Thread BTCM Casing Description SDL LINER OD (in) 7 ID (in) 6.28 Top (ftKB) 10,004.0 Set Depth (ftKB) 12,469.5 Set Depth (TVD) … 7,966.1 Wt/Len (l… 26.00 Grade L-80 Top Thread Tenaris Blue Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,004.0 7,064.2 56.95 PACKER SLZX Liner Hanger Packer 7.375 10,036.6 7,082.0 56.96 SEAL ASSY Latching bullet seals NO-GO (Seals 5.76') 6.160 10,039.5 7,083.5 56.96 SETTING SLEEVE HRD-E Liner Sleeve 6.210 10,048.4 7,088.4 56.96 QUICK CONNECT HP Liner Quick Connect,w/Bullet Seals 7" 32# Tenaris Blue 6.151 12,463.2 7,965.6 85.17 STABILIZER Reamer Shoe Stabilizer w/ Spline Profile, 7" 32# MYS110 Tenaris Blue 6.060 Casing Description PRODUCTION LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 12,320.8 Set Depth (ftKB) 20,350.0 Set Depth (TVD) … 7,865.7 Wt/Len (l… 12.60 Grade L-80 Top Thread TXP Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 12,320.8 7,950.2 82.38 PACKER HRDE ZXP Ext. 5.00" upper (16.11') H521 pin 3.875 12,347.4 7,953.6 82.93 HANGER 4-1/2" x 7" Flex Lock V TXP BxP 3.940 Tubing Strings Tubing Description Tubing – Gas Injection String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 28.8 Set Depth (ft… 12,328.4 Set Depth (TVD) (… 7,951.2 Wt (lb/ft) 12.60 Grade L-80 Top Connection Tblue Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 28.8 28.8 0.00 HANGER FMC 4-1/2" Tubing Hanger Hydril 563 3.958 2,037.2 2,008.9 20.04 X NIPPLE NIPPLE,LANDING,4 1/2",X, 3.813", TSH Blue 3.813 11,540.4 7,809.9 71.17 DB NIPPLE NIPPLE,LANDING,4 1/2", 3.75" DB, TSH Blue 3.750 12,312.9 7,949.2 82.22 NO-GO LOCATOR Locator No-Go 5.77" OD 3.950 12,314.1 7,949.3 82.24 SEAL ASSY Seal Assembly 3.950 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 11,277. 8 7,708.4 64.43 PACKER - PATCH - UPR 4.5" PARAGON II PACKER. MID-ELEMENT DEPTH = 11,280.85. 7200# TO RELEASE. OAL = 4.31'. (SN# ALPP45014) 9/18/2021 2.000 ALPP45014 11,282. 1 7,710.2 64.47 SPACER PIPE 2-3/8" SPACER PIPE. 7000# SHEAR TO RELEASE. OAL = 12.84' (LATCH SEAL ASSY SN# ALPAL45002) 9/18/2021 1.995 ALPAL45002 11,295. 0 7,715.8 64.62 PACKER - PATCH - LWR 4.5" PARAGON II PACKER. MID-ELEMENT DEPTH = 11,298. 7200# TO RELEASE. OAL = 4.89'. (SN# ALPP45013) 9/14/2021 2.000 ALPP45013 12,340. 0 7,952.7 82.78 EVO Plug SET EVO PLUG @ 12,340' SLM, 12,349' RKB (OAL=72.5"), 6/19/21 6/6/2021 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 11,285.3 7,711.6 64.51 CAMCO KBG-2 1 GAS LIFT DMY BK 6/7/2021 EXT PKG Notes: General & Safety End Date Annotation NOTE: MULTIPLE LATERALS, MT6-08, 10/6/2021 11:11:13 AM Vertical schematic (actual) PRODUCTION LINER; 12,320.8 -20,350.0 SDL LINER; 10,004.0-12,469.5 SEAL ASSY; 12,314.1 NO-GO LOCATOR; 12,312.9 DB NIPPLE; 11,540.4 PACKER - PATCH - LWR; 11,295.0 GAS LIFT; 11,285.3 SPACER PIPE; 11,282.1 PACKER - PATCH - UPR; 11,277.8 INTERMEDIATE 1; 34.6- 10,317.7 INTERMEDIATE 2 ; 32.2- 10,018.4 X NIPPLE; 2,037.2 SURFACE; 36.7-2,010.6 CONDUCTOR; 36.5-115.0 HANGER; 28.8 WNS INJ KB-Grd (ft) 36.55 Rig Release Date 9/6/2018 MT6-08 ... TD Act Btm (ftKB) 21,102.0 Well Attributes Field Name LOOKOUT Wellbore API/UWI 501032077200 Wellbore Status INJ Max Angle & MD Incl (°) 98.55 MD (ftKB) 17,740.22 WELLNAME WELLBOREMT6-08 Annotation LAST WO: End DateH2S (ppm) DateComment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y Samantha Carlisle at 9:22 am, Oct 12, 2021 321-534 Travis T. Smith Digitally signed by Travis T. Smith Date: 2021.10.11 16:45:53 -08'00' X VTL 10/13/21 SFD 10/12/2021 SFD 10/12/2021 X 12,520' - 20,350' MD DSR-10/12/21 10-404 7,970' - 7,866' MD JLC 10/14/2021 Jeremy Price Digitally signed by Jeremy Price Date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tate witnessed MIT-IA required after stabilized injection. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG:MT6-08 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tubing Patch 9/18/2021 MT6-08 praffer Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 36.6 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 94.00 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.40 Top (ftKB) 36.7 Set Depth (ftKB) 2,010.6 Set Depth (TVD) … 1,983.9 Wt/Len (l… 68.00 Grade L-80 Top Thread TXP Casing Description INTERMEDIATE 1 OD (in) 9 5/8 ID (in) 8.84 Top (ftKB) 34.6 Set Depth (ftKB) 10,317.7 Set Depth (TVD) … 7,235.3 Wt/Len (l… 40.00 Grade L-80 Top Thread TXP Casing Description INTERMEDIATE 2 OD (in) 7 ID (in) 6.28 Top (ftKB) 32.2 Set Depth (ftKB) 10,018.4 Set Depth (TVD) … 7,072.0 Wt/Len (l… 26.00 Grade L80 Top Thread BTCM Casing Description SDL LINER OD (in) 7 ID (in) 6.28 Top (ftKB) 10,004.0 Set Depth (ftKB) 12,469.5 Set Depth (TVD) … 7,966.1 Wt/Len (l… 26.00 Grade L-80 Top Thread Tenaris Blue Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,004.0 7,064.2 56.95 PACKER SLZX Liner Hanger Packer 7.375 10,036.6 7,082.0 56.96 SEAL ASSY Latching bullet seals NO-GO (Seals 5.76') 6.160 10,039.5 7,083.5 56.96 SETTING SLEEVE HRD-E Liner Sleeve 6.210 10,048.4 7,088.4 56.96 QUICK CONNECT HP Liner Quick Connect,w/Bullet Seals 7" 32# Tenaris Blue 6.151 12,463.2 7,965.6 85.17 STABILIZER Reamer Shoe Stabilizer w/ Spline Profile, 7" 32# MYS110 Tenaris Blue 6.060 Casing Description PRODUCTION LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 12,320.8 Set Depth (ftKB) 20,350.0 Set Depth (TVD) … 7,865.7 Wt/Len (l… 12.60 Grade L-80 Top Thread TXP Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 12,320.8 7,950.2 82.38 PACKER HRDE ZXP Ext. 5.00" upper (16.11') H521 pin 3.875 12,347.4 7,953.6 82.93 HANGER 4-1/2" x 7" Flex Lock V TXP BxP 3.940 Tubing Strings Tubing Description Tubing – Gas Injection String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 28.8 Set Depth (ft… 12,328.4 Set Depth (TVD) (… 7,951.2 Wt (lb/ft) 12.60 Grade L-80 Top Connection Tblue Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 28.8 28.8 0.00 HANGER FMC 4-1/2" Tubing Hanger Hydril 563 3.958 2,037.2 2,008.9 20.04 X NIPPLE NIPPLE,LANDING,4 1/2",X, 3.813", TSH Blue 3.813 11,540.4 7,809.9 71.17 DB NIPPLE NIPPLE,LANDING,4 1/2", 3.75" DB, TSH Blue 3.750 12,312.9 7,949.2 82.22 NO-GO LOCATOR Locator No-Go 5.77" OD 3.950 12,314.1 7,949.3 82.24 SEAL ASSY Seal Assembly 3.950 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 11,277. 8 7,708.4 64.43 PACKER - PATCH - UPR 4.5" PARAGON II PACKER. MID-ELEMENT DEPTH = 11,280.85. 7200# TO RELEASE. OAL = 4.31'. (SN# ALPP45014) 9/18/2021 2.000 ALPP45014 11,282. 1 7,710.2 64.47 SPACER PIPE 2-3/8" SPACER PIPE. 7000# SHEAR TO RELEASE. OAL = 12.84' (LATCH SEAL ASSY SN# ALPAL45002) 9/18/2021 1.995 ALPAL45002 11,295. 0 7,715.8 64.62 PACKER - PATCH - LWR 4.5" PARAGON II PACKER. MID-ELEMENT DEPTH = 11,298. 7200# TO RELEASE. OAL = 4.89'. (SN# ALPP45013) 9/14/2021 2.000 ALPP45013 12,340. 0 7,952.7 82.78 EVO Plug SET EVO PLUG @ 12,340' SLM, 12,349' RKB (OAL=72.5"), 6/19/21 6/6/2021 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 11,285.3 7,711.6 64.51 CAMCO KBG-2 1 GAS LIFT DMY BK 6/7/2021 EXT PKG Notes: General & Safety End Date Annotation NOTE: MULTIPLE LATERALS, MT6-08, 10/6/2021 11:11:13 AM Vertical schematic (actual) PRODUCTION LINER; 12,320.8 -20,350.0 SDL LINER; 10,004.0-12,469.5 SEAL ASSY; 12,314.1 NO-GO LOCATOR; 12,312.9 DB NIPPLE; 11,540.4 PACKER - PATCH - LWR; 11,295.0 GAS LIFT; 11,285.3 SPACER PIPE; 11,282.1 PACKER - PATCH - UPR; 11,277.8 INTERMEDIATE 1; 34.6- 10,317.7 INTERMEDIATE 2 ; 32.2- 10,018.4 X NIPPLE; 2,037.2 SURFACE; 36.7-2,010.6 CONDUCTOR; 36.5-115.0 HANGER; 28.8 WNS INJ KB-Grd (ft) 36.55 Rig Release Date 9/6/2018 MT6-08 ... TD Act Btm (ftKB) 21,102.0 Well Attributes Field Name LOOKOUT Wellbore API/UWI 501032077200 Wellbore Status INJ Max Angle & MD Incl (°) 98.55 MD (ftKB) 17,740.22 WELLNAME WELLBOREMT6-08 Annotation LAST WO: End DateH2S (ppm) DateComment SSSV: NIPPLE gp PRODUCTION LINER p 20,350.0 p( ) 12,320.8 From:Smith, Travis T To:Loepp, Victoria T (OGC); Wallace, Chris D (OGC) Cc:Earhart, Will C Subject:Re: GMTU MT6-08 (PTD#218-048-0) Patch Troubleshooting Date:Thursday, October 7, 2021 3:00:48 PM Attachments:MT6-08.pdf Victoria & Chris— Yesterday an acoustic LDL was completed on GMTU well MT6-08 (PTD#218-048-0, Sundry #321- 459), and the well was shut-in and freeze-protected today per our email below. This LDL did not identify any leak signature from the patch we recently set. Given that our TxIA issue still persists while on injection, coupled with the strong correlation to injection temperature that this leak demonstrates, we now suspect there could be an issue at the tubing seal assembly. Our proposed path forward is to pull the retrievable patch from over the GLM, then set an expandable patch over the tubing seal assembly (12,314’ MD on the attached schematic), then re-set the patch over the GLM. Would this best be handled as a revision and continuation of Sundry #321-459, or would you prefer that we submit a 10-404 for #321-459 and an additional 10-403 for the new path forward? Thank you very much for the help, Travis From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, September 29, 2021 7:39 PM To: Smith, Travis T <Travis.T.Smith@conocophillips.com> Cc: Wallace, Chris D (CED) <chris.wallace@alaska.gov>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: [EXTERNAL]Re: GMTU MT6-08 (PTD#218-048-0) Patch Troubleshooting CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Travis, The LDL should be run within two weeks. Otherwise your plan is acceptable. Thanx, Victoria Sent from my iPhone On Sep 29, 2021, at 4:21 PM, Smith, Travis T <Travis.T.Smith@conocophillips.com> wrote: Chris & Victoria— GMTU well MT6-08 (PTD#218-048-0, Sundry #321-459) recently had a retrievable patch set in the tubing to address a suspected leak in a gas lift mandrel. During the subsequent monitoring period of water injection the TxIA communication appears to be ongoing. Our plan forward is to run another acoustic LDL with the tubing patch still in the well and attempt to determine if there is a leak signature at the patch. If so, we will pull and replace the tubing patch. E-line crews are at Alpine currently, but on an uncertain time commitment supporting the drilling rigs. We propose leaving the well on stabilized water injection for the time being such that we can run an acoustic LDL at the first opportunity logistically. After the log is complete we will shut-in the well. We are not intending to perform the MITIA listed in the Sundry unless we can successfully address what looks like an ongoing issue with the patch at the GLM. Please let me know if you have any questions or disagree with the plan. Thanks, Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG:MT6-08 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replace DV with new 5/28/2021 MT6-08 claytg Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 36.6 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 94.00 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.40 Top (ftKB) 36.7 Set Depth (ftKB) 2,010.6 Set Depth (TVD) … 1,983.9 Wt/Len (l… 68.00 Grade L-80 Top Thread TXP Casing Description INTERMEDIATE 1 OD (in) 9 5/8 ID (in) 8.84 Top (ftKB) 34.6 Set Depth (ftKB) 10,317.7 Set Depth (TVD) … 7,235.3 Wt/Len (l… 40.00 Grade L-80 Top Thread TXP Casing Description INTERMEDIATE 2 OD (in) 7 ID (in) 6.28 Top (ftKB) 32.2 Set Depth (ftKB) 10,018.4 Set Depth (TVD) … 7,072.0 Wt/Len (l… 26.00 Grade L80 Top Thread BTCM Casing Description SDL LINER OD (in) 7 ID (in) 6.28 Top (ftKB) 10,004.0 Set Depth (ftKB) 12,469.5 Set Depth (TVD) … 7,966.1 Wt/Len (l… 26.00 Grade L-80 Top Thread Tenaris Blue Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,004.0 7,064.2 56.95 PACKER SLZX Liner Hanger Packer 7.375 10,036.6 7,082.0 56.96 SEAL ASSY Latching bullet seals NO-GO (Seals 5.76') 6.160 10,039.5 7,083.5 56.96 SETTING SLEEVE HRD-E Liner Sleeve 6.210 10,048.4 7,088.4 56.96 QUICK CONNECT HP Liner Quick Connect,w/Bullet Seals 7" 32# Tenaris Blue 6.151 12,463.2 7,965.6 85.17 STABILIZER Reamer Shoe Stabilizer w/ Spline Profile, 7" 32# MYS110 Tenaris Blue 6.060 Casing Description PRODUCTION LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 12,320.8 Set Depth (ftKB) 20,350.0 Set Depth (TVD) … 7,865.7 Wt/Len (l… 12.60 Grade L-80 Top Thread TXP Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 12,320.8 7,950.2 82.38 PACKER HRDE ZXP Ext. 5.00" upper (16.11') H521 pin 3.875 12,347.4 7,953.6 82.93 HANGER 4-1/2" x 7" Flex Lock V TXP BxP 3.940 Tubing Strings Tubing Description TUBING GAS INJECTION String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 28.8 Set Depth (ft… 12,328.4 Set Depth (TVD) (… 7,951.2 Wt (lb/ft) 12.60 Grade L-80 Top Connection Tblue Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 28.8 28.8 0.00 HANGER FMC 4-1/2" Tubing Hanger Hydril 563 3.958 2,037.2 2,008.9 20.04 NIPPLE NIPPLE,LANDING,4 1/2",X, 3.813", TSH Blue 3.813 11,540.4 7,809.9 71.17 NIPPLE NIPPLE,LANDING,4 1/2", 3.75" DB, TSH Blue 3.750 12,312.9 7,949.2 82.22 NO-GO LOCATOR Locator No-Go 5.77" OD 3.950 12,314.1 7,949.3 82.24 SEAL ASSY Seal Assembly 3.950 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 11,285.3 7,711.6 64.51 CAMCO KBG-2 1 GAS LIFT DMY BK 1" 5/28/2021 Notes: General & Safety End Date Annotation NOTE: MULTIPLE LATERALS, MT6-08, 5/29/2021 7:26:55 AM Vertical schematic (actual) PRODUCTION LINER; 12,320.8 -20,350.0 SDL LINER; 10,004.0-12,469.5 SEAL ASSY; 12,314.1 NO-GO LOCATOR; 12,312.9 NIPPLE; 11,540.4 GAS LIFT; 11,285.3 INTERMEDIATE 1; 34.6- 10,317.7 INTERMEDIATE 2 ; 32.2- 10,018.4 NIPPLE; 2,037.2 SURFACE; 36.7-2,010.6 CONDUCTOR; 36.5-115.0 HANGER; 28.8 WNS INJ KB-Grd (ft) 36.55 Rig Release Date 9/6/2018 MT6-08 ... TD Act Btm (ftKB) 21,102.0 Well Attributes Field Name LOOKOUT Wellbore API/UWI 501032077200 Wellbore Status INJ Max Angle & MD Incl (°) 98.55 MD (ftKB) 17,740.22 WELLNAME WELLBOREMT6-08 Annotation LAST WO: End DateH2S (ppm) DateComment SSSV: NIPPLE C:\Users\aebell\Desktop\October Data Drop 2021\CPA Data Drop 10122021\2021-10-06_21045_GMTU_MT6-08_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 21045 GMTU MT6-08 50-103-20772-00 LeakPoint Survey 06-Oct-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM _______________________________________________ Signatatatatatatatatatataatattattatatatatatattaatatatatattaattatuure Abby Bell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y Samantha Carlisle at 4:21 pm, Sep 08, 2021 321-459 Travis T. Smith Digitally signed by Travis T. Smith Date: 2021.09.08 15:08:47 -08'00' -00 DLB 10-404 VTL 9/9/21 X DLB 09/08/2021 X DSR-9/8/21 X dts 9/9/2021 JLC 9/10/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.10 14:00:22 -08'00' RBDMS HEW 9/13/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 8 September 2021 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well GMTU MT6-08 (PTD# 218-048-0) to set a retrievable patch in the tubing. Please contact me at 670-4014 if you have any questions. Sincerely, Travis Smith WNS Intervention & Integrity Engineer ConocoPhillips Alaska, Inc. GMTU MT6-08 (PTD# 218-048-0) Overview of Proposed Work Background & Objective: GMTU MT6-08 (PTD# 218-048-0) developed TxIA communication while on water injection service. While the well would pass diagnostic MIT-IA’s, trend data while on injection service consistently demonstrated the well has a very low rate TxIA leak. On September 7, 2021 an acoustic leak detect log was run. This acoustic LDL indicated a leak in the gas lift mandrel. The proposal below is to set a retrievable patch across the tubing leak at 11,285’ MD. The well will then be returned to WAG injection service. Overview Steps: 1. Wait for approved Sundry before proceeding to patch installation. 2. Run retrievable lower patch packer. Correlate depth with CCL and set the lower packer just below the tubing leak at 11,285’ MD. Set packer. 3. Run upper patch packer and spacer pipe assembly, made up to cover leak interval. Latch into the lower packer and set the upper packer. 4. Return well to injection service. Perform passing MIT-IA once well has returned to injection service. Leave well on 30-day monitoring period for pressure trend data to indicate the TxIA issue has been resolved. State witnessed MIT-IA required. VTL 9/9/21 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG:MT6-08 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: T/S AnnComm 6/7/2021 MT6-08 claytg Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 36.6 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 94.00 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.40 Top (ftKB) 36.7 Set Depth (ftKB) 2,010.6 Set Depth (TVD) … 1,983.9 Wt/Len (l… 68.00 Grade L-80 Top Thread TXP Casing Description INTERMEDIATE 1 OD (in) 9 5/8 ID (in) 8.84 Top (ftKB) 34.6 Set Depth (ftKB) 10,317.7 Set Depth (TVD) … 7,235.3 Wt/Len (l… 40.00 Grade L-80 Top Thread TXP Casing Description INTERMEDIATE 2 OD (in) 7 ID (in) 6.28 Top (ftKB) 32.2 Set Depth (ftKB) 10,018.4 Set Depth (TVD) … 7,072.0 Wt/Len (l… 26.00 Grade L80 Top Thread BTCM Casing Description SDL LINER OD (in) 7 ID (in) 6.28 Top (ftKB) 10,004.0 Set Depth (ftKB) 12,469.5 Set Depth (TVD) … 7,966.1 Wt/Len (l… 26.00 Grade L-80 Top Thread Tenaris Blue Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,004.0 7,064.2 56.95 PACKER SLZX Liner Hanger Packer 7.375 10,036.6 7,082.0 56.96 SEAL ASSY Latching bullet seals NO-GO (Seals 5.76') 6.160 10,039.5 7,083.5 56.96 SETTING SLEEVE HRD-E Liner Sleeve 6.210 10,048.4 7,088.4 56.96 QUICK CONNECT HP Liner Quick Connect,w/Bullet Seals 7" 32# Tenaris Blue 6.151 12,463.2 7,965.6 85.17 STABILIZER Reamer Shoe Stabilizer w/ Spline Profile, 7" 32# MYS110 Tenaris Blue 6.060 Casing Description PRODUCTION LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 12,320.8 Set Depth (ftKB) 20,350.0 Set Depth (TVD) … 7,865.7 Wt/Len (l… 12.60 Grade L-80 Top Thread TXP Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 12,320.8 7,950.2 82.38 PACKER HRDE ZXP Ext. 5.00" upper (16.11') H521 pin 3.875 12,347.4 7,953.6 82.93 HANGER 4-1/2" x 7" Flex Lock V TXP BxP 3.940 Tubing Strings Tubing Description Tubing – Gas Injection String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 28.8 Set Depth (ft… 12,328.4 Set Depth (TVD) (… 7,951.2 Wt (lb/ft) 12.60 Grade L-80 Top Connection Tblue Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 28.8 28.8 0.00 HANGER FMC 4-1/2" Tubing Hanger Hydril 563 3.958 2,037.2 2,008.9 20.04 X NIPPLE NIPPLE,LANDING,4 1/2",X, 3.813", TSH Blue 3.813 11,540.4 7,809.9 71.17 DB NIPPLE NIPPLE,LANDING,4 1/2", 3.75" DB, TSH Blue 3.750 12,312.9 7,949.2 82.22 NO-GO LOCATOR Locator No-Go 5.77" OD 3.950 12,314.1 7,949.3 82.24 SEAL ASSY Seal Assembly 3.950 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 12,340. 0 7,952.7 82.78 EVO Plug SET EVO PLUG @ 12,340' SLM, 12,349' RKB (OAL=72.5"), 6/19/21 6/6/2021 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 11,285.3 7,711.6 64.51 CAMCO KBG-2 1 GAS LIFT DMY BK 6/7/2021 EXT PKG Notes: General & Safety End Date Annotation NOTE: MULTIPLE LATERALS, MT6-08, 9/8/2021 2:44:47 PM Vertical schematic (actual) PRODUCTION LINER; 12,320.8 -20,350.0 SDL LINER; 10,004.0-12,469.5 DB NIPPLE; 11,540.4 GAS LIFT; 11,285.3 INTERMEDIATE 1; 34.6- 10,317.7 INTERMEDIATE 2 ; 32.2- 10,018.4 X NIPPLE; 2,037.2 SURFACE; 36.7-2,010.6 CONDUCTOR; 36.5-115.0 HANGER; 28.8 WNS INJ KB-Grd (ft) 36.55 Rig Release Date 9/6/2018 MT6-08 ... TD Act Btm (ftKB) 21,102.0 Well Attributes Field Name LOOKOUT Wellbore API/UWI 501032077200 Wellbore Status INJ Max Angle & MD Incl (°) 98.55 MD (ftKB) 17,740.22 WELLNAME WELLBOREMT6-08 Annotation LAST WO: End DateH2S (ppm) DateComment SSSV: NIPPLE C:\Users\aebell\Desktop\September 2021 Data Drop\CPA Data Drop 09142021\2021-09-07_14482_GMTU_MT6-08_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 14482 GMTU MT6-08 50-103-20772-00 LeakPoint Survey 07-Sep-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM 37' (6HW Abby Bell __________________________________ ignaturrrrrrrrrrrrrrrrrrrrrrrrrrreeeeeeeeeeeeeeeeeeeee By Abby Bell at 11:23 am, Sep 14, 2021 From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: GMTU MT6-08 (PTD# 218-048-0) IA Pressurization Date:Wednesday, August 25, 2021 11:23:44 AM From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Monday, August 23, 2021 4:12 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: RE: GMTU MT6-08 (PTD# 218-048-0) IA Pressurization Chris— Another update on the operations described below for GMTU injector MT6-08 (PTD# 218-048-0). Bringing the MT6 drillsite back into injection service took longer than expected following the Alpine facility turnaround. MT6-08 was brought back on injection this past weekend, on August 21. It’s injection rate will be ramped up gradually to target injection pressure over the next several days. Once it is at target rate and stabilized, we will attempt a leak detect log. After logging the well will be shut-in and remain shut-in awaiting a path forward. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis T Sent: Wednesday, July 21, 2021 4:29 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: GMTU MT6-08 (PTD# 218-048-0) IA Pressurization Chris— An update on the operations described below for GMTU injector MT6-08 (PTD# 218-048-0). Pulling the downhole plug became extremely challenged, and we spent several days with both slickline and coiled tubing fishing on the well. We were not able to successfully remove the plug before water injection was offline for the Alpine facility turnaround. We have made positive progress on the fishing operations and believe we can inject into the well again. Shortly after water injection is available again at MT6 (our best estimate is July 24th), we intend to return to the plan described below: bring the well on water injection for a limited basis and attempt a leak detect log. After logging the well will be shut-in and remain shut-in awaiting a path forward. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis T Sent: Wednesday, June 30, 2021 10:44 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: GMTU MT6-08 (PTD# 218-048-0) IA Pressurization Chris— Another update on the status of GMTU injector MT6-08 (PTD# 218-048-0). With the well shut-in and a downhole plug in place we attempted an acoustic LDL that was unable to find a source of TxIA communication. The well simply has a very low IA pressure build rate while shut-in. To attempt another acoustic LDL we intend to bring the well back on injection for a limited basis. Once the injection is stabilized we will run another acoustic LDL while on water injection. Our intent is to bring the well back to water injection as soon as possible, and have the logging complete before the Alpine facility turnaround (which begins on or around July 9). Once the well is shut-in it will remain shut-in awaiting a path forward. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis T Sent: Wednesday, June 16, 2021 3:31 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: GMTU MT6-08 (PTD# 218-048-0) IA Pressurization Chris— I wanted to give an update on the status of GMTU injector MT6-08 (PTD# 218-048-0). Our efforts to address the issue by troubleshooting the circulation mandrel were not successful. Consequently, the well was shut-in and freeze-protected. We have begun to move forward with more diagnostics that will likely include leak detect logging. We will send a Sundry proposal when we have a proposed path forward on a fix for this well. Please let me know if you have any questions or disagree with the plan. Thanks, From: Smith, Travis T Sent: Thursday, May 27, 2021 4:33 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: GMTU MT6-08 (PTD# 218-048-0) IA Pressurization Chris— GMTU injector MT6-08 (PTD# 218-048-0) was observed by Operations with increasing IA pressure while on water injection. The IA approached 2000 psi and was bled last night. Today, DHD was able to perform initial diagnostics on the well including an MIT-IA and wellhead packoff testing. These tests passed. In order to address the IA pressurization, our proposed path forward is to swap the dummy valve in the circulation mandrel at 11,285’ with a new valve with high sealing packing. To determine the efficacy of this new dummy valve, we will put the well on a 30-day monitoring period of water injection and observe annular pressure trends. Because MT6-08 is currently the only water injector at MT6 on water injection service, shutting it in for even a few days would require WAG’ing a gas injector to water service. To avoid this, we propose leaving the well on water injection until slickline can swap the dummy valve. We estimate this will happen in the next 1-2 days. A well schematic and 90-day TIO are attached. Please let me know if you have any questions or disagree with the plan. Thanks, Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com Wallace, Chris D (CED) From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Wednesday, July 21, 2021 4:29 PM To: Wallace, Chris D (CED) Cc: Earhart, Will C Subject: RE: GMTU MT6-08 (PTD# 218-048-0) IA Pressurization Chris— An update on the operations described below for GMTU injector MT6-08 (PTD# 218-048-0). Pulling the downhole plug became extremely challenged, and we spent several days with both slickline and coiled tubing fishing on the well. We were not able to successfully remove the plug before water injection was offline for the Alpine facility turnaround. We have made positive progress on the fishing operations and believe we can inject into the well again. Shortly after water injection is available again at MT6 (our best estimate is July 24th), we intend to return to the plan described below: bring the well on water injection for a limited basis and attempt a leak detect log. After logging the well will be shut-in and remain shut-in awaiting a path forward. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis T Sent: Wednesday, June 30, 202110:44 AM To: 'Wallace, Chris D (DOA)' <chris.waIlace @alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: GMTU MT6-08 (PTD# 218-048-0) IA Pressurization Chris— Another update on the status of GMTU injector MT6-08 (PTD# 218-048-0). With the well shut-in and a downhole plug in place we attempted an acoustic LDL that was unable to find a source of TAA communication. The well simply has a very low IA pressure build rate while shut-in. To attempt another acoustic LDL we intend to bring the well back on injection for a limited basis. Once the injection is stabilized we will run another acoustic LDL while on water injection. Our intent is to bring the well back to water injection as soon as possible, and have the logging complete before the Alpine facility turnaround (which begins on or around July 9). Once the well is shut =in it will remain shut-in awaiting a path forward. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis Sent: Wednesday, June16, 2021 3:31 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alasl<a.gov> Wallace, Chris D (CED) From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Wednesday, June 30, 2021 10:44 AM To: Wallace, Chris D (CED) Cc: Earhart, Will C Subject: RE: GMTU MT6-08 (PTD# 218-048-0) IA Pressurization Chris— Another update on the status of GMTU injector MT6-08 (PTD# 218-048-0). With the well shut-in and a downhole plug in place we attempted an acoustic LDL that was unable to find a source of TxIA communication. The well simply has a very low IA pressure build rate while shut-in. To attempt another acoustic LDL we intend to bring the well back on injection for a limited basis. Once the injection is stabilized we will run another acoustic LDL while on water injection. Our intent is to bring the well back to water injection as soon as possible, and have the logging complete before the Alpine facility turnaround (which begins on or around July 9). Once the well is shut-in it will remain shut-in awaiting a path forward. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis T Sent: Wednesday,, June 16, 20213:31 PM To: 'Wallace, Chris D,(DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: GMTU MT6-08 (PTD# 218-048-0) IA Pressurization Chris— I wanted to give an update on the status of GMTU injector MT6-08 (PTD# 218-048-0). Our efforts to address the issue by troubleshooting the circulation mandrel were not successful. Consequently, the well was shut-in and freeze -protected. We have begun to move forward with more diagnostics that will likely include leak detect logging. We will send a Sundry proposal when we have a proposed path forward on a fix for this well. Please let me know if you have any questions or disagree with the plan. Thanks, From: Smith, Travis T Sent: Thursday, May 27, 20214:33 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C<William.C.Earhart@conocophillips.com> Subject: GMTU MT6-08 (PTD# 218-048-0) IA Pressurization C:\Users\aebell\Desktop\June 2021 Data Drop\CPA Data Drop 06232021\2021-06-21_14469_MT6-08_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 14469 Outlook MT6-08 50-103-20772-00 LeakPoint Survey 21-Jun-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM Abby Bell __________________________________________________ 37' (6HW By Abby Bell at 10:00 am, Jun 28, 2021 Wallace, Chris D (CED) From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Wednesday, June 16, 2021 3:31 PM To: Wallace, Chris D (CED) Cc: Earhart, Will C Subject: RE: GMTU MT6-08 (PTD# 218-048-0) IA Pressurization Chris— I wanted to give an update on the status of GMTU injector MT6-08 (PTD# 218-048-0). Our efforts to address the issue by troubleshooting the circulation mandrel were not successful. Consequently, the well was shut-in and freeze -protected. We have begun to move forward with more diagnostics that will likely include leak detect logging. We will send a Sundry proposal when we have a proposed path forward on a fix for this well. Please let me know if you have any questions or disagree with the plan. Thanks, Fro?n;.Smith, Travis T Sent: Thursday, May 27, 20214:33 PM To:'Wallace, C",D (DOA)' <chris.waIlace @alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: GMTU MT6-08 (FlT-D # 218-048-0) IA Pressurization Chris— GMTU injector MT6-08 (PTD# 218-048-0) was observed by Operations with increasing IA pressure while on water injection. The IA approached 2000 psi and was bled last night. Today, DHD was able to perform initial diagnostics on the well including an MIT -IA and wellhead packoff testing. These tests passed. In order to address the IA pressurization, our proposed path forward is to swap the dummy valve in the circulation mandrel at 11,285' with a new valve with high sealing packing. To determine the efficacy of this new dummy valve, we will put the well on a 30 -day monitoring period of water injection and observe annular pressure trends. Because MT6-08 is currently the only water injector at MT6 on water injection service, shutting it in for even a few days would require WAG'ing a gas injector to water service. To avoid this, we propose leaving the well on water injection until slickline can swap the dummy valve. We estimate this will happen in the next 1-2 days. A well schematic and 90 -day TIO are attached. Please let me know if you have any questions or disagree with the plan. Thanks, Travis Smith MEMORANDUM TO: Jim Regg P.I. Supervisor } 1��3�� FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 10, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhllips Alaslce, Ino. MT6-08 GMTU MT6-08 Sre: Inspector Reviewed By: P.I. Supry .� Comm Well Name GMTU MT6-08 API Well Number 50-103-20772-00-00 Inspector Name: Lou Laubenstein Insp Num: mitLOL200708111954 Permit Number: 218-048-0 Inspection Date: 6/23/2020 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well MTs -os Type Inj w- TVD 7949 Tubing n95 - 2795 - 2795 - z79s PTD SPT Test psi 1987 IA 6so zzao - 2145 - 2140 2180480 - Ty pe Test BBL Pumped:2 BL Returned: 2 OA 370 400 B aoo aoo Interval 4YRTST __— P/F _ P Notes: OOA 100/100/100/100 - - Friday, July 10, 2020 Page i of 1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 10, 2020 Commissioner Jesse Chmielowski Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jesse Chmielowski: RECEIVED Mpl,'Y 13 2020 AOCCC Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement/sand if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement/sand was installed April 215f thru April 24`h, 2020. The corrosion inhibitor/sealant was pumped on April 22°d thru April 25`h, 2020. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerel !, � Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Alpine Field Date 5/10/2020 CD2, 3, 4 & MT6 Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement/Sand top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal CD2 -02 *501032051300 2051090 30" 14 gals 9" 4/24/2020 1.5 4/25/2020 CD2 -73 *501032059000 2081960 11" 1 gal 6" 4/24/2020 0.5 4/2512020 CD2 -468 *501032058700 2081800 11" 1 gal 7" 4/24/2020 0.8 4/25/2020 CD3 -111A *501032052601 2170040 14" 4 gals V. 4/21/2020 1.3 4/22/2020 CD3 -198 *501032063700 2110240 10" 10" 3 4/22!2020 CD4 -215 *501032053900 2061570 40" 28 gals 9" 4/23/2020 1.4 4/23/2020 CD4 -291 *501032067200 2131100 2r 80 gals 6" 4/23/2020 0.5 4/23/2020 CD4 -321 *501032053600 2061420 18.5' 4 gals 6" 4/23/2020 0.5 4/23/2020 MT6-02 *501032079200 2181600 30" 14 gals 8" 4/23/2020 1 4/24/2020 MT6-03 *501032077000 2180160 49" 32 gals 10" 4/23/2020 1.7 4/24/2020 MT6-04 *501032077500 2181080 24" 17 gals 8" 4/23/2020 1 4/24/2020 MT6-05 *501032077100 2180450 30" 10 gals 7" 4/23/2020 1.3 4/24/2020 MT6-06 *501032077300 2180930 25' 7 gals 8" 4/23/2020 1 4/24/2020 MT6-08 *501032077200 2180480 12" 2.5 gals 7" 4/23/2020 1 4/24/2020 MT6-09 *501032077900 2181340 34" 15 gals 9" 4/23/2020 1.5 4/24/2020 WELL LOG TRANSMITTAL #906171702 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile with TMD3D: MT6-08 Run Date: 11/03/2019 and 12/16/2019 2x8048 32 03 8 February 12, 2020 RECEIVED FEB 13 2020 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 MT6-O8 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20772-00 MT6-08 is located in a federal oil and gas unit. Only with respect to the MT6-08 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S. C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025690)(00). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: - �00t v Signed: WELL LOG TRANSMITTAL #906171702 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile with TMD3D: MT6-08 Run Date: 11/03/2019 and 12/16/2019 January 14, 2020 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 MT6-08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20772-00 C, 22 � �o zo SCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com n Date: O � Uj Signed: DATA SUBMITTAL COMPLIANCE REPORT 2/2512019 Permit to Drill 2180480 Well Name/No. GMTU MT6-08 f)31 . Operator CONOCOPHILLIPS ALASKA, INC. MD 21102 TVD 7841 Completion Date 9/5/2018 REQUIRED INFORMATION / Mud Log No V Completion Status WAGIN Current Status WAGIN Samples No V/ DATA INFORMATION List of Logs Obtained: GR/RES/Neu/Den/CBL ( I UoA '34'�� Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval Type Med/Frmt Number Name Scale Media No Start Stop ED C 29719 Digital Data 12318 9921 j ED C 29719 Digital Data ED C 29719 Digital Data Log C 29719 Log Header Scans 0 0 ED C 29795 Digital Data 08_MEMORY SCMT_1SEP2018_PASS_UP_30 ED C 29795 Digital Data Electronic File: MT6- ED C 29795 Digital Data 2180480 GMTU MT6-08 LOG HEADERS ED C 29795 Digital Data Electronic File: MT6-08 EOW - NAD27.bd 10/12/2018 Log C 29795 Log Header Scans 0 0 Log C 29796 Log Header Scans 0 0 ED C 29796 Digital Data 10/12/2018 Electronic File: MT6-08PB1 EOW - NAD83.txt ED C 29796 Digital Data Electronic Data Set, Filename: MT6-08 Drilling ED C 29796 Digital Data ED C 29796 Digital Data Log C 29904 Log Header Scans 0 0 ED C 29904 Digital Data 100 21102 I:T0ZKdR Page] of6 OH/ CH Received API No. 50-103-20772-00-00 UIC Yes Directional Survey Yes (from Master Well Data/Logs) 9/25/2018 Electronic Data Set, Filename: MT6- 08_ MEMORY_SCMT_1SEP2018_PASS_UP_30 FPM_009PUC.las 9/25/2018 Electronic File: MT6- 08_MEMORY SCMT_1SEP2018_PASS_UP_30 FPM_009PUC.DLIS 9/25/2018 Electronic File: MT6- 08 MEMORY_SCMT_1SEP2018_FIELD_PRINT. PDF 2180480 GMTU MT6-08 LOG HEADERS 10/12/2018 Electronic File: MT6-08 EOW - NAD27.pdf 10/12/2018 Electronic File: MT6-08 EOW - NAD27.bd 10/12/2018 Electronic File: MT6-08 EOW - NA083.pdf 10/12/2018 Electronic File: MT6-08 EOW - NAD83.bd 2180480 GMTU MT6-08 LOG HEADERS 2180480 GMTU MT6-08PB1 LOG HEADERS 10/12/2018 Electronic File: MT6.08PB1 EOW - NAD27.pdf 10/12/2018 Electronic File: MT6-08PB1 EOW - NAD27.txt 10/12/2018 Electronic File: MT6-08PB1 EOW - NAD83.pdf 10/12/2018 Electronic File: MT6-08PB1 EOW - NAD83.txt 2180480 GMTU MT6-08 LOG HEADERS 10/26/2018 Electronic Data Set, Filename: MT6-08 Drilling Mechanics Depth Data.las Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill MD 21102 2180480 Well Name/No. GMTU MT6-08 TVD 7841 Completion Date 9/5/2018 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20772-00-00 Completion Status WAGIN Current Status WAGIN UIC Yes ED C 29904 Digital Data 60 21102 10/26/2018 Electronic Data Set, Filename: MT6-08 LTK Memory Drilling Data Composite.las ED C 29904 Digital Data 60 21102 10/26/2018 Electronic Data Set, Filename: MT6-08 LTK Realtime Drilling Data.las ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Depth Log.cgm ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08 LTK 2MD Memory Log.cgm ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08 LTK 5MD Memory Log.cgm ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08 LTK 5TVD Memory Log.cgm ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08 LTK 2MD Realtime Log.cgm ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08 LTK 5MD Realtime Log.cgm ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08 LTK STVD Realtime Log.cgm ED C 29904 Digital Data 10/26/2018 Electronic File: MTB -08 Drilling Mechanics Time Log Runl.cgm ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Time Log Run2.cgm ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Time Log Run3.cgm ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Time Log Run4.cgm ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Time Log Run6.cgm ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Time Log Run6.cgm ED C 29904 Digital Data 10/26/2018 Electronic File: MTB -08 Drilling Mechanics Time Log Run7.cgm ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Time Log Run8.cgm ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08 LTK Memory Drilling Data Composite.dls AOGCC Page 2 of 6 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2180480 Well Name/No. GMTU MT6-08 MD 21102 TVD 7841 ED C 29904 Digital Data ED C 29904 Digital Data ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C 29904 Digital Data 29904 Digital Data 29904 Digital Data 29904 Digital Data 29904 Digital Data 29904 Digital Data 29904 Digital Data 29904 Digital Data 29904 Digital Data 29904 Digital Data 29904 Digital Data 29904 Digital Data 29904 Digital Data 29904 Digital Data 29904 Digital Data 29904 Digital Data 29904 Digital Data Completion Date 9/5/2018 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20772-00-00 Completion Status WAGIN Current Status WAGIN UIC Yes Page 3 of 6 10/26/2018 Electronic File: MT6-08 LTK Realtime Drilling Data.dls 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Depth Log.PDF 10/26/2018 Electronic File: MT6-08 LTK 21VID Memory Log.PDF 10/26/2018 Electronic File: MT6-08 LTK 5MD Memory Log.PDF 10/26/2018 Electronic File: MT6-08 LTK 5TVD Memory Log.PDF 10/26/2018 Electronic File: MT6-08 LTK 2MD Realtime Log.PDF 10/26/2018 Electronic File: MT6-08 LTK 51VID Realtime Log.PDF 10/26/2018 Electronic File: MT6-08 LTK 5TVD Realtime Log.PDF 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Time Log Runl.pdf 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Time Log Run2.pdf 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Time Log Run3.PDF 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Time Log Run4.PDF 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Time Log Run5.PDF 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Time Log Run6.PDF 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Time Log Run7.pdf 10/26/2018 Electronic File: MT6-08 Drilling Mechanics Time Log Run8.pdf 10/26/2018 Electronic File: MT6-08 EOW - NAD27.pdf 10/26/2018 Electronic File: MT6-08 EOW - NAD27.txt 10/26/2018 Electronic File: MT6-08 EOW - NAD83.pdf Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/2 512 01 9 Permitto Drill 2180480 Well Name/No. GMTU MT6.08 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103.20772.00.00 MD 21102 TVD 7841 Completion Date 9/5/2018 Completion Status WAGIN Current Status WAGIN UIC Yes ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08 EOW - NAD83.txt ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08PB1 Surveys for import.txt ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08_FieldSurvey.pdf ED C 29904 Digital Data 10/26/2018 Electronic File: MT6-08_FieldSurvey.txt ED C 29905 Digital Data 150 11551 10/26/2018 Electronic Data Set, Filename: MT6-08PB1 Drilling Mechanics Depth Data.las ED C 29905 Digital Data 50 11555 10/26/2018 Electronic Data Set, Filename: MT6-08PB1 LTK Memory Drilling Data.las ED C 29905 Digital Data 59 11550 10/26/2018 Electronic Data Set, Filename: MT6-08PB1 LTK Realtime Drilling Data.las ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1_BHGE_Mud Resistivity Report.xls ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 Drilling Mechanics Depth Log.cgm ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 LTK 2MD Memory Log.cgm ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 LTK 51VID Memory Log.cgm ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 LTK 5TVD Memory Log.cgm ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 LTK 2MD Realtime Log.cgm ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 LTK 51VID Realtime Log.cgm ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 LTK 5TVD Realtime Log.cgm ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 Drilling Mechanics Time Log Runl.cgm ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 Drilling Mechanics Time Log Run2.cgm ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 Drilling Mechanics Time Log Run3.cgm ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08P81 Drilling Mechanics Time Log Run4.cgm AOGCC Page 4 of 6 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2180480 Well Name/No. GMTV MT6-08 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20772-00-00 MD 21102 TVD 7841 Completion Date 9/5/2018 Completion Status WAGIN Current Status WAGIN UIC Yes ED C 29905 Digital Data 10/26/2018 Electronic File: MT6.08PB1 LTK Memory Composite.dls ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 LTK Realtime Drilling Data.dls ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 Copilot Drilling Mechanics Depth Log Run3.pdf ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08P81 Drilling Mechanics Depth Log.pdf ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 LTK 2MD Memory Log.pdf ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 LTK SMD Memory Log.pdf ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 LTK 5TVD Memory Log.pdf ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 LTK 2MD Realtime Log.pdf ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 LTK 5MD Realtime Log.pdf ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 LTK 5TVD Realtime Log.pdf ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 Copilot Drilling Mechanics Time Log Run3.pdf ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 Copilot Drilling Mechanics Time Log Run4.pdf ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 Drilling Mechanics Time Log Runl.pdf ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 Drilling Mechanics Time Log Run2.pdf ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 Drilling Mechanics Time Log Run3.pdf ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 Drilling Mechanics Time Log Run4..pdf ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 EOW - NAD27.pdf ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 EOW - NAD27.txt ED C 29905 Digital Data 10/26/2018 Electronic File: MT6-08PB1 EOW - NAD83.pdf AOGCC Page 5 of 6 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2180480 Well Name/No. GMTU MT6-08 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20772-00.00 MD 21102 TVD 7841 Completion Date 9/5/2018 ED C 29905 Digital Data ED C 29905 Digital Data ED C 29905 Digital Data Log C 29905 Log Header Scans Well Cores/Samples Information Completion Status WAGIN Current Status WAGIN UIC Yes 10/26/2018 Electronic File: MT6-08PB1 EOW - NAD83.txt 10/26/2018 Electronic File: MT6-08PB1 Final Survey.pdf 10/26/2018 Electronic File: MT6.08PB1 Final Survey.bd 0 0 2180480 GMTU MT6-08 PB1 LOG HEADERS Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED ('� Completion Report la0'.�:� Production Test Information Y / rvA l Geologic Markers/Tops Off/ COMPLIANCE HISTORY Completion Date: 9/5/2018 Release Date: 5/31/2018 Description Comments: Compliance Reviewed By: Directional / Inclination Data Y� Mechanical Integrity Test Information Y / NA Daily Operations Summary Date Comments Mud Logs, Image Files, Digital Data Y /CA) Composite Logs,Image, Data Files Cuttings Samples Y/ NM Date: Core Chips Y LA Core Photographs Y f Laboratory Analyses Y AOGCC Page 6 of 6 Monday, February 25, 2019 MEMORANDUM TO: Jim Regg�i P.I. Supervisor `- l FROM: Austin McLeod Petroleum Inspector Well Name GMTU MT6-08 Insp Num: mitSAM181027124915 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 13, 2018 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. MT6-O8 GMTU MT6-08 Sre: Inspector Reviewed By: P.I. Supry J �2 Comm API Well Number 50-103-20772-00-00 Inspector Name- Austin McLeod Permit Number: 218-048-0 Inspection Date: 10/26/2018 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well MTG O8 Type Inj I w TVD 7949 Tubing -'3I 1 2315 2313 '� 2312 PTD I80480--IType Test sPT Test psi 1987 IA 45O 3000 - 2940 - 1940 j BBL Pumped:3.3 "BBL Returned: ss OA oo 29 — 29 e9 - - - Interval INITAL P/F P - --- Notes: MIT -IA on fresh well. OOA; Pretest -92, Initial -93, 15 min -93, 30 min -93. ✓ Tuesday, November 13, 2018 Page 1 of I Brooks, Phoebe L (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Saturday, November 10, 2018 11:33 AM To: Brooks, Phoebe L (DOA) Subject: RE: [EXTERNAL]RE: GMTU MT6-08 Form 10-426 Attachments: MT6-08.pdf Hi Phoebe, I apologized for the tardy reply. I overlooked your message in our functional inbox. Please see the schematic for MT6-08 attached. Please let me know if you need any additional information. Sincerely, Sara.CarUsZ& (}Ees4*0 / 12ache lKautk Well Integrity Supervisor, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549f@cop.com Cell: 907-331-7514 1 sara e carlisle@cop.com From: Brooks, Phoebe L (DOA) <phoebe.brooks@alaska.gov> Sent: Wednesday, November 7, 2018 4:04 PM To: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Subject: [EXTERNAL]RE: GMTU MT6-08 Form 10-426 Rachel/Sara, Will you send me the well schematic for MT6-08? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 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 Phoebe Brooks at 907-793-1.242 or phoebe.brooks©alaska.¢ov. From: NSK Well Integrity Supv CPF3 and WNS <n2549CcDconocophillips.com> Sent: Sunday, October 28, 2018 10:21 AM To: Regg, James B (DOA) <iim.regg@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe. bay@alaska.gov>; Brooks, Phoebe L (DOA) <phoebe. brooks@alaska.gov> Subject: GMTU MT6-08 Form 10-426 Good morning, Attached is the 10-426 for the witnessed initial MITIA performed on GMTU injector MT6-08. Please let us know if you have any questions. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 I'\ WNS SVC MT6-08 Z l5OY$0 Conoc Phillips Well Attributes Max Angle & MD TD Fkld Name WellEore OPMUWI pfWbam a.. IMI(') Mouxual Pct San Mr.) Alaska.lnc LOOKOUT s010320A200 SVC 98.55 1],]40.22 21.102.0 Comment H351FPm) Di MMhdon FMaaM KBGhiss I Rig R¢IMoe Dale 36.55 91612018 MuJIPLEIATEukL.MT6099R1RO181D:0ri Last Tag Verwal wh i WaKf) M^ofNk^ EndOMa DepNNB(B) Lasl Mod By Mager as, ir Last Rev Reason MnolNlon EM Dtle LastM'dBy ReVReason Set l' DV, Set 3.913'A1 -injection V.N. &24Q018 JM1ansen8 Casing Strings eosin Deecipron Op(in) ID IIN Top MKS) aet OegM1(flKB) aM DepM (ND).. WYlen a-GfaYe Top TMeed 2P conductor 20 19.12 36.8 115.0 115.0 94.00 H G Welded Grid's peurlglm OD IIN ID 9n) Tap MKS) pet Depth MKB) aM OWIM IND)... WIM1en (4.. GrWe Top ihreN 13-318"6urlace 13318 1240 367 2,010.6 1,983.9 saw L-80 TTP WMuuor Cememy 36.5axe '' C..ho peacrlgio^ OD lin) ID 9N Top Made) 3 Dept IMKB) Set Depth IND)". YWL..n U... Grue Top Thnatl 951e'Intermetlialet 9518 8.84 31.8 10,31)) ),235.3 40.00 L-80 TXP 3P nMusmr. x.6ns.D Cube Deserlprort 009N 1D 9n) Top MKS) StDepth MKBI Sed Depth ITVD)... YNLen IL.. Chad Top Thread Intermediate 27"Tie 7 6.28 32.2 10,018.4 7.072.0 2G.00 L80 BTCM Ba sunese CaurO Cemex,b0 Ke ' Cuire Desnlglen OD(in) ID lin) Top 11D(B) pet DeplM1 (XKBI ae[DpM (NDI-,. VMena Grau Tap TM1rmd SOL Liner ] 6.28 10.004.0 12,469.5 7,966.1 26.00 L-80 Tenaris Blue Liner Details a mI I.D.Du Co.Com IInN Top Meet Top(ND)IMKa) Top N41l ) 10,036.6 7,082.0 56.96 Seel Acembly Latching bullet seals NO-GO(Seals 5.76) 6.160 uvc smauas.aao+os 10.039.5 7,083.5 56.96 Setting Sleeve Hao -E Liner Sleeve 6.210 ID, 7.088.4 56.% uick Conned HP Liner Quick Coneact,WIll Seals r 324 6.151 Tenaris Blue haseer, iae Dairy Gmenl; �. 9330.a NNB Isureakare 2 rre eaak; 32e 1 ,463.2 ),9 5. 85.17 Subilizer Reamer Shce Stabilizer wl Saline Picch ,7.32# 6. MY$I10 Ter+aris Blue tO.Otaa Casing Description Oa(IN ID( Tap IMKB) $0 DepP anted Su Do,M(ND)...N'OLen(L. Grade Top Thread Predudlontuter 4112 3.98 12,320.8 20,350.0 .0865.] 12.80 L-ep TXP Liner Details Nn lnal lD Top"'T'Top INDI IMKB) Top 1^al l-1 Nem Des Co. IIN 12.34).4 ),953.6 82 3 Hanger 0.1Y3" x J' F0 LOCk V TX➢ B#a 3.940 gslr lx.m,.Aa+eCA6 10.31]) .: Lou up.n1a.; I.. Cad, Tubing Strings Trend Desaip+im 6UIrrp Ma... ID I1N Top IMKB) SM Dega(M.. pC De p's meaI I... MT11NN Dfeua Top ConnMbn Tubing - Gas Injection 4112 3.98 26.8 12328.4 ),951.2 12.60 L-80 Tblue 115-g- Completion Details Top(ND) Turkel Hamlrwl Top Ma,S) IMKB) r) Item Des Com to (I.) kMMrM: I Takii 28.8 25.8 0.00 Hanger FMC 4-112' Tubing Hanger Hydn1563 3.958 203).2 -2.00as NIPPLE, LANDING.4112', X. 3.813". TSH 61ue Set A1 -Injection 3.813 Valve (HS&1571.25' Orifice) 9/24118 r inn amen: +++...... 1L5404 7,809.9 ]1.D NiDDIe-DB NIPPLE,IANDING,4 la'. 3.75' DB, TSH Blue 3750 Now aeu., 12 ]129 1 .12,9 ],949.2 No -OO Locefor LocafrN o5.7r OD .950 seal fu entir R3+e.+ 12,314.1 ], 93 82.24 Seal Assembly Sae!Assembi 3,950 Mandrel Inserts 9t atl NtoplNDl Top IMKB) IMKB) M>ha Model OO BN Valve )etch Ped. 8ery Type Type IIN TRO Pun halls pan Dat Co. 1 11,285.3 7.)11.8 Cemm KB -2 1 GAS UFT DMY BK 1' 0.000 912412018 VD -Lie, o.aM.6u.asss prudeMon 1-M, +2.320.6 m.3m D BAF�I E ® PRINT DISTRIBUTION LIST a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME MT6-08, MT6-08PB I FIELD Greater Mosses Tooth Unit COUNTY ALPINE BHI DISTRICT Alaska AUTHORIZED BY Paul Canizares EMAIL Paul. CanizaresC_bhoe.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT OELNER TO P.O. BOX) PERSON ATTENTION V I Conocophillips Alaska, Inc. Ricky Elgarico. ATO 3-380. 700'G'Stree1. 2 ;Alpine Wells Supervisor. NSK-33 T.O. Bos 196860 Anchoraee. Alaska. 99519-6860 3 ASRC, Atm: Teresa Into '3900 'C' Street, suite 801 Anchorage. Alaska 99503-5963 4 State Office W. 7th Ave., Suite#13 horn¢. Alaska 99513-7504 'CC ATTN: Natural Resources Tech W. 7th Ave.. Suite 100 horaae. Alaska 99501-3539 21 804 29904 se sign and return one copy of this transmittal form to: ocoPhillips Alaska, Inc. y Elgarico. ATO 3-380. 'G' Street. horage, Alaska 99501 LOG TYPE GR-RES-DEN-NEU LOG DATE August 31, 2018 TODAYS DATE October 24, 2018 Revision Details: Rev. Requested by: -- FIELD IFINAL CD/DVD NAL PRELIM LOGS LOGS (las, dlis. PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES VV V V 0 0 0 1 0 0 1 \ R ` T pGj I 6OrNnGGG 0 0 1 0 0 IMT6-08�i§ located in afederahoil- anrf*ges unit. Only with respect to the JMT6A81 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). TOTALS FOR THIS PAGE: 0 0 4 1 0 BAI WIllir ® PRINT DISTRIBUTION LIST a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME MT6-08, MT6-08PBI FIELD Greater Mosses Tooth Unit COUNTY ALPINE BHI DISTRICT AUTHORIZED BY Paul Canhares EMAIL Paul.Canizares&ilbhoe.com se sign and return one copy of this transmittal form to: ocoPhillips Alaska, Inc. V Elgarico. ATO 3-380. 'G' Street. forage, Alaska 99501 LOG TYPE GR-RES-DEN-NEU LOG DATE August 31, 2018 TODAYS DATE October 24, 2018 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY ADDRESS(FEDEXW NOT DELIVER TO P.O. BOX) PERSON ATTENTION 1 Caneenrhal,Pt Alas ka, tac. :Rieky Elgarico. ATO 3-380. 700'G' Street. :Anchomee, Alaska 99501 2 !Alpine Wells Supervisor.NSK-33 'P.O. Box 196860 :Anchorage, Alaska. 99519-6860 3 !ASRC, Atm: Teresa learn !3900'C' Street, Suite 801 Anchorage, Alaska 99503-5963 4 1 State Office W. 7th Ave., Sufefl13 honge. Alaska 99513-7504 ;CC ATTN: Natural Resources Tech W. 7th Ave, Suite 100 I CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) 11FIELD #OF PRINTS ff ur rruN # OF COPIES I#UFGUPIES # OF COPIES Ni ocj i 6 2o�a )MT6-081 is located in a federal oil anti gas.unit. Only with respect to the (MT6-081 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(t)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). TOTALS FOR THIS PAGE: 0 0 4 1 0 29915 BATER S "1 a GE company To: 21 804 29796 Letter of Transmittal - - ---- ----------------- Date: October 11, 2018 Meredith Guhl AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Michael Soper / Yosha Ragbirsingh Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): KUPARUK RIVER UNIT 3H -31A 3H-31AL1 1H -21A 1H-21AL1 1H-21AL2 1H-21AL2-01 (14) Total prints GREATER MOOSES TOOTH UNIT MT6-03PH MT6-03 MT6-05PB2 RECEIVED MT6-05 OCT ) 2 2018 MT6-051-1 AOGCC MT6-08PB1 MT6-08 Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BHGE.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BHGE.com 21 8048 29796 ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-08PB1 Lower Lat 50-103-20772-70 Baker Hughes INTEQ B''i�`UGHES a GE company Definitive Survey Report 18 September, 2018 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConowPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Project: Western North Slope TVD Reference: Site: GMTt Lookout Pad MD Reference: Well: MT6-08 North Reference: Wellbore: MT6-08P131_Cancelled Survey Calculation Method: Design: C2PBl-wp02 Database: Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Latitude: Map Zone: Alaska Zone 04 000usft Well MT6-08 Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore MT6-08PB1 Lower Let Magnetics Model Name Sample Date BGGM2018 7/1/2018 Design MT6-08PB1 Audit Notes Well MTB -08 Actual MT6-08 @ 88.85usft (Actual Doyanl 9) Actual MT6-08 @ 88.85usft (Actual Doyanl 9) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using geodetic scale factor 5,945,523.29usft Latitude: 317,003.60usft Longitude: 000usft Ground Level: Declination Dip Angle 16.51 8070 Version: 1.0 Phase: ACTUAL Tie On Depth: 36.55 Vertical Section: Depth From (TVD) +N/ -S (usft) (usft) 0.00 0.00 +E/ -W (usft) 0.00 Direction (°) 331.89 70° 15'22.749 N 151' 28'44.556 W 37.20 usft Field Strength (nT) 57,400 9/18/2018 3:50.59PM Page 2 COMPASS 5000.14 Build 85 I ✓ ConocoPhillips Bnlcga 4 ConocoPhillips Definitive Survey Report .1 Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-08 Project: Western North Slope TVD Reference: Actual MTB -08 c@ 88.85usft (Actual Doyanl9) ) Site: GMT1 Lookout Pad MD Reference: Actual MT6-08 @ 88.85usft (Actual Doyanl9) Well: MT6-08 North Reference: True f Wellbore: M76-08PB7 Cancelled Survey Calculation Method: Minimum Curvature p Design: C2PB1-wp02 Database: EDT 14 Alaska Production I Survey Program .. ��., Date From To Survey Survey (usft) (waft) Survey (Wellborn) Tool Name Description Start Date End Date f 60.00 115.00 1. Gyrodata Gyro DMS 16" (MT6-0BP81 GYD-CT-DMS Gyrodata cont.ddllpipe m/s 7/15/2018 7/15/2018 210.38 677.91 2. BHGE MWD+CA+MSA 16"(MT6-0BPB MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 7/16/2018 7/16/2018 1 771.90 924.00 3. Gyrodata Gyro DMS 16" (MT6-08PB1 GYD-GC-MS Gyrodata gyrocompassing m/s 7/25/2018 960.17 2,048.15 4. BHGE MWD+CA+MSA 16"(MT6-OBPB MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 7/16/2018 7/17/2018 2,084.30 10,283.06 S. BHGE MWD+CA+MSA 121/4"(MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 7/19/2018 7/23/2018 i 10,387.04 11,430.59 S. BHGE MWD+CA+MSA 6x 83/4"SDL MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/23/2018 7/31/2018 1 `. Survey __.._.__.. ........-..,...�- ...-.-.... .. _. Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section cti (usft) V) (1) (usft) (usft) (usft) (usft) (°/100') Surve Tool Name Y ADDOt8ti0D (ft) (ft) Q 36.55 II 0.00 0.00 36.55 -52.30 0.00 0.00 5,945,523.29 317,003.60 0.00 0.00 UNDEFINED 60.00 0.55 72.88 60.00 -28.85 0.03 0.11 5,945,523.32 317,00371 2.35 -0.02 GYD-CT-DMS(1) 115.00 0.61 68.68 115.00 26.15 0.22 0.63 5,945,52349 317,004.24 0.13 -0.11 GYD-CT.DMS(1) S 115.35 0.61 68.68 115.35 26.50 0.22 0.64 5,945,52350 317,004.24 0.00 -0.11 MWD+IFR-AK-CAZ-SC (2) 29' ) 210.36 Ole 8].34 21037 721.52 0.43 1.75 5,945,52368 317,005.37 0.30 -0.45 MWD+IFR-AK-CAZ-SC (2) ^ 301.40 0.79 84.73 301.38 212.53 0.52 3.00 5,945,523.74 317,006.61 0.04 -0.96 MM+IFR-AK-CAZ-SC (2) !!!i 393.91 0.42 82.05 39389 305.04 0.62 3.97 5,945,523.82 317,007.58 0.40 A,32 MWD+FR-AK-CAZ-SC(2) I 489.21 0.37 282.55 489.19 400.34 0.74 4.01 5,945,523.93 31],00]63 0.82 -1.24 MWD+IFR-AK-CAZ-SC(2) i 583.84 0.51 27265 563.81 494.96 0.82 3.30 5,945,52404 317,006.92 0.17 -0.83 MWD+IFR-AK-CAZ-SC(2) 9 677.91 1.34 32348 67787 589.02 1.73 2.22 5,945,524.97 317,005.86 1.16 048 MWD+IFR-AK-CAZSC(2) 1 771.90 1.35 32329 771.83 682.98 3.50 0.91 5,945,526.77 317,004.59 0.01 2.66 GYD.GC-MS(3) 831.00 1.97 322.36 830.91 742.06 4.86 -0.13 5,945,528.16 317,003.59 1.05 4.35 GYD-GC-MS (3) 924.00 2.75 329.74 923.83 834.98 8.05 -2.23 5,945,531.40 317,001.57 0.90 8.16 GYD-GC-MS (3) 960.17 3.29 328.86 959.95 871.10 9.69 -3.20 5,945,533.06 317,000.63 1.50 10.06 MWD+IFR-AK-CAZSC(4) 1055.06 4.75 333.42 1,054.60 965.75 15.54 -6.37 5,945,538.96 316,997.61 1.57 1671 MWD+IFR-AK-CAZSC(4) I 1,149.35 6.33 335.43 1,148.45 1,059.60 23.76 -10.28 5,945,547.29 316,993.90 1.69 25.80 MWD+IFR-AK-CAZSC(4) 1,24345 786 33792 1,24163 1,152.98 3444 -14.85 5,945,558.08 316,989.59 1.66 3737 MWD+IPR-AK-CAZSC(4) 1,336.74 905 330.92 1334.10 124525 4676 -20.82 5,945,570.54 316.98393 1.68 5105 MWD+IFR-AK-CAZ-SC(4) 9/182018 3:50:59PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips9""N FS ConocoPhillips Definitive Survey Report 9 Company: ConowPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: �mmTM��µP ^ ��,m.,„._,._._,....♦�-._ -- __,_.... Well MT6-08 project: Western North Slope TVD Reference: Actual MT6-08 @ 88.85usft (Actual Doyan19) Site: GMT7 Lookout Pad MD Reference: Actual MT6-08 @ 88.85usft (Actual Doyanl9) i Well: MT6-08 North Reference: True Wellbore: MT6-OSPB1_Cancelled Survey Calculation Method: Minimum Curvature Design: C2PB1-wp02 Database: EDT 14 Alaska Production s Survey 9/182018 3:50:59PM Page 4 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azl TVD TVDSS +Nl-S +E/ -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 1,431.33 10.59 328.44 1,42731 1,33846 6067 -2898 5,945,584.64 316,976.10 169 67.17 MWD+IFR-AK-CAZ-SC(4) 1,52576 12.70 33041 1,519.79 1,430.94 77.09 58.65 5,945,601.30 316,966.84 2.27 86.21 MWD+IFR-AK-CAZ-So(4) 1,61964 14.31 331.05 1,611.07 1,522.22 96.22 -49.37 5,945,620.68 316,956.59 1.72 108.13 MWD+IFR-AK-CAZSC(4) 1,714.01 15.74 330.77 1,702.21 1,613.36 117.60 -61.26 5,94.5,642.33 316,945.22 1.52 132.59 MW0+1FR-AK-CAZ-SC(4) 1,80787 1754 330.52 1,792,14 1,703,29 141.02 -74.44 5,945,666.07 316,932.61 1.92 159.46 MWD+IFR-AK-CAZ-SC (4) 1,901.92 18.98 329.99 1,881.45 1,792.60 166.60 59.05 5,945,692.00 316,918.62 1.54 188.91 MWD+IFR-AK-CAZSC(4) 1955.79 1948 330.04 1,932.31 1,843.46 181.97 -97.93 5,945,707,58 316,910.13 0.93 206.65 MWD+IFR-AK-CAZSC(4) 2,011.35 19.86 329.92 1,984.63 1,895.78 198.16 -107.29 5,945,723.99 316,901.17 0.70 225.34 MWD+IFR-AK-CAZSC (4) 13-3/8" x 16" i 2,048.15 20.12 329.85 2,019.21 1,930.36 209.05 -113.60 5,945,735.03 316,895.12 0.70 237.91 MWD+IFR-AK-CAZSC(4) 2,084.30 2062 329.79 2,053.10 1,964.25 219.93 -119.93 5,945,746.05 316,889.06 1.38 25049 MWD+IFR-AK-CAZSC(5) 2,179.09 21.58 329.09 2,141.53 2,052.66 249.31 -137.28 5,945,775.84 316,872.43 1.05 284.58 MWD+IFR-AK-CAZSC(5) �) 2,273.41 22.25 328.51 2,229.04 2,140.19 279.42 -155.52 5,945,806.39 316,854.93 0,75 319.73 MWD+IFR-AK-CAZSC(5) " 2,366.75 23.11 328.60 2,315.16 2,226.31 310.72 -174.29 5,945,837.54 316,836.90 0.92 355.66 MWD+IFR-AK-CAZ-$C(5) 2,460.97 24.18 329.13 2,401.47 2,312.62 342.47 -19383 5,945,870.35 316,818.16 1.16 39340 MWD+IFR-AK-CPZSC(5) 1 2,552.55 26.11 329.50 2,484.37 2,395.52 375.93 -213.68 5,945,904.28 316,799.13 2.11 432.27 MWD+IFR-AK-CAZSC(5) 1 2,645.74 27.45 329.78 2,567.56 2,478.71 412.16 -234.90 5,945,941.02 316,778.80 1.44 474.22 MWD+IFR-AK-CAZSC(5) 2,73980 27.47 329.35 2,651.02 2,562.17 449.56 -256.87 5,945,978.93 316,757.74 0.21 517.56 MWD+IFR-AK-CAZ-SC(5) 2,832.23 27.53 329.74 2,733.01 2,644.16 486.35 -278.50 5,946,016.24 316,737.01 0.21 560.21 MWD+IFR-AK-CAZSC(5) _ j 2,927.36 27.61 329.32 2,817.34 2,728.49 524.30 -300.83 5,946,05431 316,715.61 022 604.20 MWD+IFR-AK-CAZSC(5) 1 3,021.63 27.69 329.97 2,900.84 2,811.99 55205 522.94 5,946,092.99 316,694.43 0.33 64291 MWD+IFR-AK-CAZSC(5) s 3,116.47 27.68 329.26 2,964.82 2,895.97 600.06 -345.23 5,946,131.53 316,673.08 0.35 691.94 MWD+IFR-AK-CAZSC(5) 3,211.13 2].6] 328.83 3,06865 2,979.80 63].76 -367.84 5,946,16976 316,651.39 0.21 735.85 MWD+IFR-AK-CAZ-SC(5) 3,304.68 27.69 328.61 3,151.50 3,06265 674.90 -39040 5,946,20744 316,62973 0.11 779.24 MWD+IFR-AK-CAZ-SC(5) 3,399.21 27.66 328.89 3,235.20 3,146.35 71245 413.19 5,946,245.53 316,607.87 0.14 823.09 MWD+IFR-AK-CAZ-SC (5) 3,493.50 27.83 328.52 3,318.65 3,229.80 749.97 436.00 5,946,28359 316,585.98 0.24 866.94 MWD+IFR-AK-CAZ-SC (5) 3,588.10 29.05 329.23 3,401.83 3,312.98 788.54 459.28 5,946,322.71 316,56364 1.34 911.92 MWD+IFR-AK-CAZ-SC(5) 3,682.63 32.13 329.36 3,483.19 3,394.34 829.90 483.84 5,946,364.65 316,540.10 3.26 95997 MWD+IFR-AK-CAZ-SC(5) 3,776.78 33.78 329.06 3,552.19 3,473.34 87389 -510.06 5,946,40926 316,514.96 1.76 1,011.13 MWD+IFR-AK-CAZ-SC(5) i 3,870.99 36.86 329.15 3,639.05 3,550.20 920.62 -538.02 5,946,45666 316,488.14 3.27 1,065.53 MWD+IFR-AK-CAZ-SC(5) 3,964.95 3979 330.08 3,71276 3,623.91 970.89 -567.47 5,946,50762 316,459.92 3.18 1,123.74 MWD+IFR-AK-CAZSC(5) 4,059.60 43.21 330.76 3,783.63 369478 1835.43 -59842 5946,56289 316,430.31 364 1,186.43 MWD+IFR-AK-CAZ-SC(5) 9/182018 3:50:59PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhilli s D`"H� p Definitive Survey Report i Company: ^ ConocoPhillips(Alaska)Inc -WNS ` Project: Western North Slope SRO: GMT1 Lookout Pad 3 Well: MT6-08 t Wellbore: MTB-08PB7_Cancelled Design: C2PB1-wp02 Survey Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-08 .. __..._e._._.._.,.._..�,. Actual MT6-08 @ 88.85usft (Actual Doyan19) Actual MT6-08 @ 88.85usft (Actual Doyanl9) True Minimum Curvatura EDT 14 Alaska Production Annotation - 9/182018 3:50:59PM Page 5 COMPASS 5000.14 Build 85 Map Map vertical MD Inc Azi TVD TVDSS +N/.S +EI -W DLS Northing Easting Section Survey Tool Name (asft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) 4,154.32 46.15 33005 3,850.98 3,762.13 1083.33 53131 5,94662157 316,398.83 3.15 125300 MWD+IFR-AK-CAZSC(5) 4,246.89 48.67 330.74 3,913.62 3,824.77 1,14258 £64.97 5,946681.62 316,366.62 2.78 1,321.12 MWD+IFR-AK-CAZSC(5) 4,341.08 51.62 330.64 3,973.97 3,885.12 1,205.63 -700.37 5,946,74550 316,332.77 3.13 1,393.40 MWD+IFR-AK-CAZSC(5) 4,435.15 54.34 330.20 4,030.61 3,941.76 1,270.94 -737.44 5,946,81169 316,297.30 292 1,468.48 10WD+IFR-AK-CAZ-SC(5) 4,529.18 56.40 330.95 4,084.04 3,995.19 1,338.32 -775.45 5,946,879.98 316,260.94 2.29 1,545.83 MWD+IFR-AK-CAZ-SC (5) 4,624.11 56.94 331.53 4,136.20 4,047.35 1,40786 513.61 5,946,95041 316,224.49 0.76 1,625.14 MM+IFR-AK-CAZ-SC(5) 4,718.84 56.94 331.69 4,187.88 4,09903 1477.70 -851.36 5,947,021.15 316,188.45 0.14 1,704.53 MWD+IFR-AK-CAZ-SC(5) 4,813.63 57.12 331.64 4,239.46 4,150.61 1,547.70 -889.10 5,947,092.04 316,152.42 0.19 1,784.05 MWD+IFR-AK-CAZ-SC(5) 4,907.63 57.13 33186 4,290.49 4,201.64 1,617.24 -926.47 5,947,162.46 316,116.75 0.20 1,863.00 MWD+IFR-AK-CAZ-SC(5) 5,000.42 57.12 331.32 4,340.85 4,252.00 1,685.79 -963.55 5,947,231.88 316,081.35 049 1,940.93 MWD+IFR-AK-CAZ-SC(5) 5,095.24 57.19 330.86 4,392.28 4,303.43 1,755.52 -1,00206 5,947,302.53 316,044.55 0.41 2,020.58 MWD+IFR-AK-CAZ-SC(5) 5,189.45 57.16 330.09 4443.35 4,354.50 1,824.41 -1,041.07 5,947,372.34 316,00.22 069 2,099.72 MWD+IFR-AK-CAZ-SC(6) 5,282.09 57.13 32947 4,493.61 4,404.76 1,891.65 -1,08024 5,947,440.51 315,969]0 0.56 2,177.49 MWD+IFR-AK-CAZ-SC(5) 5,375.89 5721 329.58 4,544.46 4,455.61 1,959.58 -1,120.21 5,947,509.39 315,931.39 0.13 2,25524 MWD+1FR-AK-CAZSC(5) 5,47041 57.14 329.55 4,595.70 4,506.85 2,028.05 -1,160.45 5,947,578.82 315,892.84 0.08 2,335.61 MWD+IFR-AK-CAZSC(5) 5,56462 57.11 329.93 4,646.84 4,557.99 2,096.41 -1,200.32 5,947,648.11 315,854.64 0.34 2,414.67 MWD+IFR-AK-CAZSC(5) 5,658.93 57.17 329.66 4,698.01 4,609.16 2,164.87 -1,240.18 5,947.717.52 315,816.46 0.25 2,493.84 MWD+IFR-AK-CAZSC(5) 5,753.21 57.11 329.94 4,749.17 4,660.32 2,233.32 -1,280.01 5,947,786.91 315,778.30 0.26 2,572.98 MWD+IFR-AK-CAZSC(5) 5,84743 57.19 330.16 4,800.27 4,711.42 2,301,90 -1,319.53 5,947,856.43 315,740.47 0.21 2,652.10 MWD+IFR-AK-CAZSC(5) 5,884.36 57.15 330.06 4,820.30 4,731.45 2,328.80 -1,334.99 5,947,883.70 315,725.66 0.25 2,683.11 MWD+IFR-AK-CAZ-SC(5) 5,94900 57.18 330.54 4,855.35 4,766.50 2,37598 -1,361,90 5,947,931.51 315,699.91 0.63 2,737.40 MWD+IFR-AK-CAZ-SC(5) 6,043.31 57.09 331.22 4,906.52 4,81767 2,445.18 -1,400.45 5,948,001.63 315,663.05 0.61 2,816.61 MWD+IFR-AK.CAZ-SC(5) 6,136.75 56.99 331.33 4,957.36 4,86851 2,513.94 -1,438.13 5,948,071.27 315,627.06 0.15 2,895.00 MWD+IFR-AK-CAZ-SC(5) 6,23163 56.99 331.99 5,00905 4,920.20 2,583.96 -1,475.90 5,948,142.19 315,591.00 0.58 2,974.57 MWD+IFR-AK-CAZ-SC(5) 6,326.37 56.97 331.33 5,06068 4,971.83 2,653.88 -1,51361 5,948,213.00 315,55500 0.58 3,054.00 MWD+IFR-AK-CAZ-SC(5) 6,420.60 56.93 33143 5,112.07 5,023.22 2,723.21 -1,55144 5,948,283.22 315,518.87 0.10 3,132.98 MWD+IFR-AK-CAZ-SC(5) 6,515.51 55.95 330.76 5,163.84 5,074.99 2,792.85 -1,589.89 5,948,353.77 315,482.13 0.59 3,212.52 MWD+IFR-AK-CAZ-SC(5) 6,60945 WA5 33023 5,215.08 5,126.23 2,86137 4,628.67 5,948,42321 315,445.03 0.47 3,291.23 MWD+IFR-AK-CAZSC(5) 6,703.16 56.94 329.91 5,266.19 5,177.34 2,929.44 -1,667,86 5,948,492.21 315,407.51 029 3,36974 MWD+IFR-AK-CAZSC(5) 6,798.37 55.96 329% 5,318.11 5,22926 2,998.19 -1708.38 5,948,561.92 315,368.67 0.75 3,44947 MWD+IFR-AK-CAZSC(5) 6,89276 woo 328.81 5,36962 5,28077 3.06595 -1,749.20 5,948,630.64 315,329.51 023 3,52846 MWD+IFR-AK-CAZSC(5) Annotation - 9/182018 3:50:59PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips 9 S ConocoPhillips Definitive Survey Report 9 Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MTB -OS Project: Western North Slope TVD Reference: Actual MT6-OB @ 88.85usft (Actual Doyan19) Site: GMT1 Lookout Pad MD Reference: Actual MTB -OB @ 88.85usft (Actual Doyanl9) Well: MT6-OB North Reference: True Wellbore: MT6-08PB7_Cancelled Survey Calculation Method: Minimum Curvature Design: C21 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azl TVD TVDSS +N/ -S +E/ -W Di (usft) (°) (°) (usft) (usft) (ueft) (usft) Northing Easting (°/1 Od) Section Survey Tool Name Annotation (ft) (ft) (ft) 6,985.81 56.94 328.66 5,420.41 5,331.56 3,132.59 -1,789.66 5,948.698 24 315,290.68 0.14 3,606.31 MW)+IFR-AK-GAZ-SC(5) 7,080.26 56.92 328.97 5,471.95 5,383.10 3,200.30 -1,830.64 5,948,76693 315,251.36 0.28 3,685.35 MWD+IFR-AK-CAZ-SC(5) 7,174.26 56.91 329.22 5,523.26 5,434.41 3,267.88 -1,871.10 5,948,83546 315,212.56 0.22 3,764.01 MWD+IFR-AK-CAZ-SC(5) 7,268.18 56.95 330.23 5,574.51 5,485.66 3,335.85 -1,910.77 5,948,90437 315,174.55 0.90 3,842.66 MWD+IFR-AK-CAZ-SC(5) I 7,362.87 56.97 330.11 5,626.14 5,537.29 3,404.71 -1,95.26 5,948,974.17 315,136.75 0.11 3,922.00 MWD+IFR-AK-CAZ-SC(5) 7,456.58 56.91 330.58 5,677.26 5,58841 3,472.96 -1,98912 5,949,04334 315,099.57 043 4,000.51 MWD+IFR-AK-CAZ-SC(5) Y 7,55.93 56.98 33030 5,728.72 5,639.87 3,541.75 -2,028.13 5,949,11305 315,062.24 026 4,079.57 MWD+IFR-AK-CAZ-SC(5) I 7,644.74 56.96 330.41 5,779.85 5,691.00 3,610.10 -2,067.03 5,949,182.32 315,025.01 0.10 4,158.19 MWD+IFR-AK-CAZ-SC (5) 7,739.64 56.96 330.17 5,831.59 5,742.74 3,67920 -2,106.46 5,949,252.35 314,98728 0.21 4,237.71 MW0+IFR-AK-CAZ-SC(5) i 7,834.36 56.94 33020 5,883.25 5,794.40 3,748.08 -2,145.93 5,949,322.17 314,949.49 0.03 4,317.07 MWD+IFR-AK-CAZ-SC (5) 7,928.38 56.99 MOSS 5,934.51 5,845.66 3,816.71 -2,184.71 5,949,391.71 314,912.39 0.59 4,395.87 MWD+IFR-AK-CAZ-SC(5) - 8,023.11 56.93 331.18 5,986.16 5,897.31 3,886.17 -2,223.19 5,949,46209 314,875.62 0.29 4,475.27 MWD+IFR-AK-CAZ-SC(5) 8,117.48 56.96 331.57 6,037.63 5,948.78 3,955.5 -2,261.08 5,949,532.41 314,839.43 0.35 4,554.36 MWD+IFR-AK-CAZ-SC (5) s 8,212.28 56.94 331.55 6,089.33 6,000.48 4,025.47 -2,298.92 5,949,603.18 314803.30 0.03 4,633.82 MWD+IFR-AK-CAZ-SC(5) i 8,306.14 56.95 331.34 6,140.53 6,051.68 4,094.57 -2,336.53 5,949,673.17 314,767.38 0.19 4,712.49 MWD+IFR-AK-CAZ-SC(5) 8,400.35 56.96 331.59 6,191.90 6,103.05 4,163.95 -2,37425 5,949,743.44 314,731.36 0.22 4,791.45 MWD+IFR-AK-CAZ-SC(5) 8,494.58 56.90 330.79 6,243.32 6,154.47 4,233.14 -2,41230 5,949,813.53 314,695.5 0.71 4,870.41 MWD+IFR-AK-CAZ-SC(5) 858863 57.11 330.34 6,294.53 6,205.68 4,301.84 -2,451.07 5,949,883.14 314,657.92 0.46 4,949.27 MWD+IFR-AK-CAZ-SC(5) 8,151 5707 331.02 6,345.78 6,256.93 4,370.87 -2,489.84 5,949,953.09 314,620.84 0.61 5,028.43 MWD+IFR-AK-CAZ-SC(5) 8,77778 57.15 33028 6,397.28 6,308.43 4,440.29 -2,528.87 5,950,023.43 314,583.5 0.66 5,108.05 MWD+IFR-AK-CAZ-SC(5) i 8,87143 57.17 329.94 6,448.05 6,359.21 4,508.5 -2,568.08 5,950,092.57 314,545.96 0.31 5,186.69 MWD+IFR-AK-CAZ-SC(5) 8,96540 57.17 329.44 6,499.01 6,410.16 4,57667 -2,607.93 5,950,161.69 314,507.78 0.45 5,265.60 Mi! -SC (5) } 9059.33 57.12 329.39 6,549.97 6,461.12 4,644.5 -2,64808 5,95,230.56 314,469.30 0.07 6,344.43 MWD+IFR-AK-CAZSC (5) 9,154.97 57.14 329.73 6,51.87 6,513.02 4,713.85 -2,68878 5,950,300.78 314,430.30 0.30 5,42469 MWD+11FR-AK-CAZ-SC(5) 9,24757 57.21 329.57 6,652.07 6,563.22 4,781.01 -2,728.10 5,950,368.87 314,392.63 O.16 5,5245 MWD+IFR-AK-CAZSC(5) j 9,34364 57.06 329.84 6,704.20 6,615.35 4,85.68 2,768.5 5,950,439.5 314,353.63 0.28 5,583.08 MWD+IFR-AK-CAZSC(5) Y 9,434.44 56.94 330.13 6,753.66 6,664.81 4,916.62 -2,806.90 5,95,506.35 314,317.15 0.30 5,659.19 MWD+IFR-AK-CAZSC(5) 9,529.36 5701 330.58 6,55.39 6,716.54 4,985.79 -2,846.26 5,950,576.44 314,279.48 0.40 5,738.75 MWD+IFR-AK-CAZSC(5) 1 9,623.53 5694 330.55 6,856.71 6,767,86 5,054.55 -2,885.06 5,950,646.13 314,242.36 0.08 5,817.68 MWD+IFR-AK-CAZSC(5) 1 9,718.83 56.94 330.83 6,908.70 6,819.85 5,124.19 -2.924.16 5,95.716.70 314,204.97 0.25 5,89753 MWD+IFR-AK-CAZSC(5) I 9,813.79 5.98 33100 6,96047 6,87162 5,193.76 -2.962.85 5,950.787.18 314,167.98 0.16 5,977.13 MWD+IFR-AK-GAZ-SC(5) 9/182018 3: 50:59PM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report 7 4) Company: ConocoPhillips(Alaska) Inc. -WNS G Project: Western North Slope 4' Site: GMT1 Lookout Pad Well: MT6-08 Wellbore: MT6-08P81_Cancelled i Design: C2P81-wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6 08 Actual MT6-08 @ 88.85usft (Actual Doyanl9) Actual MT6-08 Q 88.85usft (Actual Doyan19) True Minimum Curvature EDT 14 Alaska Production i Map Map Vertical MD Inc Azi TVD TVDSS +N/.S +E/ -W Northing E DLS Section (usft) (') V) (usft) (usft) (usft) (usft ating (0)100') Survey Tool Name Annotation (R) () (ft) (ft) 9,90 .91 56% 330.66 7,011.23 6,922.38 5262.00 5,000.79 5,950,856.31 314,131.72 0.13 6,055.19 MWD+IFR-AK-CAZ-SC(5) 10,000.80 56.95 330.68 7,02.43 6,973.58 5,33068 5,039.22 5,950,92590 314,094.97 0.16 6,133.87 1AWD+IFR-AK-CAZSC(5) I 10,094.80 5697 330.81 7,113.68 7,024.83 5,399.43 5,077.73 5,950,995.56 314,058.14 0.12 6,212.66 MWD+IFR-AK-CAZSC(5) I 10,189.24 1 56.94 330.86 7,165.18 7,07633 5,468.55 -3,116.31 5,951065.60 314,021,26 0.05 6,291.81 MWD+IFR-AK-CAZSC(5) 10,283.0 56.96 330.38 7,216.35 7,127.50 5,537.08 3,154.89 5,951,135:04 313,984.36 0.43 6,370.43 MWD+IFR-AK-CAZSC(5) i 10,318.35 56.74 330.68 7,23564 7,146.79 5,562.80 3,169.42 5,951,161.11 313,970.45 0.95 6,399.96 MvU+IFR-AK-CAZSC(6) 9-5/8"X12-1/4" 10,387.04 56.32 331.28 7,273.53 7,164.68 5,612.91 3,197.22 5,951,21187 313,943.88 0.95 6,457.26 MWD+IFR-AK-CAZ.SC(6) I 10,395.31 56.27 330.92 7,278.11 7,189.26 5,618.93 3,200.55 5,951,217,97 313,940.70 3.67 6,464.14 MWD+IFR-AK-CAZ-SC(6) 10,487.80 56.77 329.91 7,329.14 7,24029 5,686.02 -3,23863 5,951,28596 313,904.26 1.06 6,541.25 MWD+1FR-AK-CAZSC(6) 10,583.20 56.72 331.18 7,381.45 7,292.60 5,755.48 5,277.86 5,951,355.35 313,866.73 1.11 6,621.00 MWD+IFR-AK-CAZ-SC (6) 10,676.98 56.72 331.09 7,432.91 7,344.06 5,824.14 3,315.71 5,951,425.90 313,830.57 0.08 6,693.40 MWD+IFR-AK-CA7-SC(6) 10,771.46 57,20 33058 7,484.43 7,395.58 5,893.30 3,354.31 5,951,495.97 313,793.66 068 6,778.59 MWD+IFR-AK-CAZ-SC(6) 10,86519 57.30 330.53 7,535.46 7,446.61 5,962.38 -3,393.31 5,951,565.98 313,756:36 0.12 6,857.90 MWD+IFR-AK-CAZ-SC(6) 10,960.47 57.52 330.55 7,58645 7,497.60 6,031.84 -3,432.54 5,951,636.37 313,718.82 0.23 6,937.65 MWD+IFR-AK-CA7-SC(6) 11,054.40 58.38 329.71 7,636.30 7,54745 6,100.88 -3,472.19 5,951,706.34 313,680.86 1.19 7,017.22 MWD+IFR-AK-CAZ-SC(6) 11,148.79 6146 332.14 7,683.61 7,594.76 6,172.26 5,511.85 5,951,77866 313,642.95 3.95 7,098.87 MWD+1FR-AK-CAZ-SC(6) 11,244.22 64.58 332.11 7,726.90 7,638.05 6,247.43 -3,551.61 5,951,854.77 313,605.04 3.27 7,183.90 MWD+IFR-AK-CAZ.SC(6) 11,335.83 67.57 33269 7,764.04 7,675.19 6,321.63 5,590.39 5,951,929.89 313,568.07 3.31 7,267.63 MWD+IFR-AK-CAZ-SC(6) 11,430.59 70.53 333.25 7,79792 7,703.07 6,400.45 -3,630.60 5,952,009.66 313,52919 3.17 7,356.10 MWD+IFR-AK-CAZ-SC(6) j 11,551.00 70.53 33325 7,8360 7,749.21 6,50183 -3,681.70 5,952,112.24 313,481.17 0.00 7469.59 PRDJECTEDto TD 9/182018 3:50:59PM Page 7 COMPASS 5000.14 Build 85 To: 218048 29795 Letter of Transmittal Date: -- -------- ER V October 11, 2018 I aGfcompany Meredith Guhl AOGCC 333 West 711 Ave, Suite 100 Anchorage, Alaska 99501 From: Michael Soper/ Yosha Ragbirsingh Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): KUPARUK RIVER UNIT 3H -31A 3H-31AL1 1H -21A 1H-21AL1 1H-21AL2 1H-21AL2-01 (14) Total prints GREATER MOOSES TOOTH UNIT MT6-03PH MT6-03 MT6-05PB1 RECEIVED MT6-OSP62 MT6-05 OCT 12 2018 MT6-OSLl AOGCC MT6-08PB1 MT6-08 Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BHGE.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BHGE.com ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-08 Lower Lat RilbGI�bT�yif�Z�>• Baker Hughes INTEQ Definitive Survey Report 18 September, 2018 BAT(ER UGHES aGEcompany 218048 29795 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Project: Western North Slope TVD Reference: Site: GMT1 Lookout Pad MD Reference: Well: MT6-08 North Reference: Wellbore: MT6.08PB7_Cancelled Survey Calculation Method: Design: C2PB1.wp02 Database: Project Western North Slope, North Slope Alaska, United States Well MT6-08 Actual MT6-08 @ 88.85usft (Actual Doyan19) Actual MT6-OB @ 88.85usft (Actual Doyan19) True Minimum Curvature EDT 14 Alaska Production BiH Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well MT6-08 Well Position -NI-S 0.00 usft Northing: 5,945,523.29usft Latitude: 70° 15'22.749 N -E/-W 0.00 usft Easting: 317,003.60usft Longitude: 151"28'44.556 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00usit Ground Level: 37.20 usft Wellbore MT6-08 Lower Let Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2018 7/1/2018 16.51 80.70 57,400 Design MT6-08 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,283.41 Vertical Section: Depth From (TVD) +Nl-S +EI -W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 331.96 9/182018 3:52:08PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips SA ER ConocoPhillips Definitive Survey Report ruHEws Company: ConDWPhiilips(Alaska) Inc.-WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-08 Wellbore: MT6-08P131_Cancelled Design: C2PB7-wp02 Survey Program From To _ (usft) (usft) 60.00 i 115.00 210.38 I 677.91 3 771.90 S 924.00 960.17 2,048.15 2,084.30 10,283.06 ft I 10,328.00 10,435.64 E 10,513.25 12,522.70 I 12,596.03 21,073.17 MWD+IFR AK CAZ SCC Survey Date Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-08 _-.__._......_.a.r._ Actual MT6-08 @ 88.85usft (Actual Doyanl9) Actual MT6-08 @ 88.85usft (Actual Doyanl9) True Minimum Curvature EDT 14 Alaska Production 9/18/2016 3:52:08PM Page 3 1 t Survey End Date 7115/2018 i 7/16/2018 € 7/17/2018 7/23/2018 8/9/2018 8/14/2018 8/29/2018 COMPASS 5000.14 Build 85 Survey Survey (Wellbore) Tool Name Description Start Date 1. Gyrodata Gyro DMS 16" (MT6-08PB1 GYD-CT-DMS Gyrodata cont.drilipipe m/s 7/15/2018 2. BHGE MWD+CA+MSA 16"(MT6-08PB MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7116/2018 3. Gyrodata Gyro DMS 16" (MT6-08PB7 GYD-GC-MS Gyrodata gyrocompassing m/s 7/25/2018 4. BHGE MWD+CA+MSA 16"(MT6-08PB MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/16/2018 S. BHGE MWD+CA+MSA 121/4"(MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/19/2018 BHGE MWD+CA+MSA 6" (MT6-08 Lowe MWD MWD -Standard 8/9/2018 BHGE MWD+CA+MSA 6 x 8 3/4" (MT6-0 MWD+IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC 8/11/2018 BHGE MWD+CA+MSA41/2"(MT6-08L MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/21/2018 9/18/2016 3:52:08PM Page 3 1 t Survey End Date 7115/2018 i 7/16/2018 € 7/17/2018 7/23/2018 8/9/2018 8/14/2018 8/29/2018 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S •EI -W DLS Northing Easting Section Survey Tool Name (usft) (1) (°) (usft) (usft) (usft) (usft) (ft) (ft) (0)100) (ft) 36.55 0.00 0.00 36.55 -52.30 0.00 0.00 5,945,523.29 317,00360 0.00 0.00 UNDEFINED 6900 0.55 72.88 60.0) -28.85 0.03 0.11 5,945523.32 317,003.71 2.35 -0.02 GYD-CT-DMS(1) 115.00 0.61 68.68 115.00 26.15 0.22 0.63 5,945,523.49 317,004.24 0.13 -0.11 GYD-CT-DMS(1) 115.35 0.61 68.68 115.35 26.50 0.22 0.64 5,945,523.50 317,004.24 0.00 -0.11 MWD+IFR-AK-CAZ-SC(2) 210.38 0.78 87.34 210.37 121.52 0.43 1.75 5,945,523.68 317,005.37 0.30 -0.44 MWD+IFR-AK-CAZ-SC(2) 301.40 0.79 8473 301.38 212.53 0.52 3.00 5,945523.74 317,006.61 0.04 -0.95 MWD+IFR-AK-CA7-SC(2) 393.91 0.42 8205 393.89 305.04 062 3.97 5,945,523.82 317,007.58 0.40 -1.31 MWD+IFR-AK-CAZ-SC(2) 48921 0.37 282.55 489.19 400.34 0.74 4.01 5,945,523.93 317,007.63 0.82 -1.23 MWD+IFR-AK-CAZ-SC(2) 583.84 0.51 272.65 51KI31 494.96 0.82 3.30 5,945,524.04 317,006.92 0.17 482 MWD+IFR-AK-CAZ-SC(2) 677.91 1.34 32348 677.87 589.02 1.73 2.22 5,945,524.97 317,005.86 1.16 0.48 MWD+IFR-AK-CAZSC(2) 77190 1.35 323.29 771.83 682.98 3.50 0.91 5,945,526.77 317,004.59 0.01 266 GYD-GC-MS(3) 831.00 1.97 322.36 830.91 742.06 4.86 -0.13 5,945,528.16 317,003.59 1.05 4.35 GYD-GC-MS (3) 924.00 2.75 329.74 923.83 834.98 8.05 -2.23 5,945,531.40 317,001.57 0.90 8.16 GYD-GC-MS (3) 960.17 3.29 328.86 959.95 871.10 9.69 -3.20 5,945,533.06 317,000.63 150 10.06 MWD+IFR-AK-CAZSC(4) 1,055.06 475 333.42 1,054.60 96575 15.54 -6.37 5,945,538.98 316,997.61 157 16.71 MWD+IFR-AK-CAZ-SC(4) 9/18/2016 3:52:08PM Page 3 1 t Survey End Date 7115/2018 i 7/16/2018 € 7/17/2018 7/23/2018 8/9/2018 8/14/2018 8/29/2018 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhilli s `ucREs (� Definitive Survey Report Company: ConocoPhillips(Alaske) Inc. -WNS Local Co-ordinate Reference: Well MT6-08 Project: Western North Slope TVD Reference: Actual MT6-08 @ 88.85usft (Actual Doyan19) Site: GMT1 Lookout Pad MD Reference: Actual MT6-08 @ 88.85usft (Actual Doyan19) Well: MT6-08 North Reference: True Wellbore: MT6-08PB1_Cancelled Survey Calculation Method: Minimum Curvature Design: C2PB1-wp02 Database: EDT 14 Alaska Production Survey 9/18/1018 3:52.08PM Page 4 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azl TVD TVDSS +NbS +E/ -W DLS (usft) V) (1) (usft) (usft) (usft) (usft) Northing Easting ('1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 1,149.35 6.33 335.43 1,148.45 1,059.60 23.76 -10.28 5,945,547.29 316,993.90 169 25.80 MWD+IFR-AK-CAZ-SC(4) 1,243.45 786 337.92 1,241.83 1,152.98 3444 -14.85 5,945,558.08 316,969.59 1.66 37.38 MWD+IFR-AK-CAZSC(4) 1,336.74 9.05 330.92 1,334.10 1,245.25 46.76 -20.82 5,945,57054 316,983.93 1.613 5166 MWD+IFR-AK-CAZ-SC(4) 1,431.33 10.59 32644 1,427.31 1,338.46 60.67 -28.98 5,945,584.64 316,976.10 1.69 67.17 MM+IFR-AK-CAZSC (4) 1,525.76 12.70 330.41 1,519.79 1,430.94 77.09 -38.65 5,945,60130 316,966.84 2.27 86.21 MWD+IFR-AK-CAZSC(4) 1,619.64 1431 331.05 1,611,07 1,522.22 96.22 -49.37 5,945,620.68 316,956.59 1.72 108.13 MWD+IFR-AK-CAZSC(4) 1,714.01 15.74 330.77 1,702.21 1,613.36 117.60 81.26 5,945,642.33 316,945.22 1.52 132.59 MWD+IFR-AK-CAZSC (4) 1,807.87 17.54 330.52 1,792.14 1,703.29 141.02 -74.44 5,945,666.07 316,932.61 1.92 15946 MWD+IFR-AK-CAZSC(4) 1,901.92 18.98 329.99 1,881,45 1,792.60 166.60 -89.06 5,945,692.00 316,918.62 1.54 188.91 MM+IFR-AK-CAZSC (4) 1,955.79 19.48 330.04 1,932.31 1,843.46 181.97 -9793 5,945,707.58 316,910.13 0.93 206.65 MWD+IFR-AK-CAZSC(4) 2,011.35 1986. 329.92 1,984.63 1,895.78 198.16 -107.29 5,945,723.99 316,901.17 0.70 225.34 MWD+IFR-AK-CAZSC (4) 13-3/8" x 16" E 2,048.15 20.12 329.85 2,019.21 1,930.36 209.05 -113.60 5,945,735.03 316,895.12 0.70 237.91 MWD+1FR-AK-CAZSC(4) 2,084.30 20.62 329.79 2,053.10 1,964.25 219.93 -119.93 5,945,74605 316,869.06 1.38 25049 MWD+IFR-AK-CAZ-SC(5) i 2,179.09 21.58 329.09 2,141.53 2,052.68 249.31 -137.28 5,945,77584 316,872.43 1.05 284.58 MWD+IFR-AK-CAZ-SC(5) 2.273.41 22.25 328.51 2,229.04 2,140.19 279.42 -155.52 5,945,80639 316,854.93 075 319.73 MWD+IFR-AK-CAZ-SC(5) 2,366.75 23.11 328.60 2,315.16 2,226.31 310.12 -174.29 5,945,83754 316,836.90 092 355.65 MWD+IFR-AK-CAZ-SC(5) 2,460.97 24.18 329.13 2,401.47 2,312.62 342.47 -193.83 5,945,870.35 316,818.16 1.16 393.38 MWD+1FR-AK-CAZ-SC (5) i 2,552.55 26.11 32960 2,484,37 2,395.52 375.93 -21368 5,945,904.28 316,799.13 2.11 432.25 MWD+IFR-AK-CAZ-SC (5) 2,645]4 27.45 329.78 2,567.56 2,478.71 412.16 -234.90 5,945,94162 316,778.80 1 44 474.21 MWD+IFR-AK-CAZ-SC (5) G 2,739.80 2747 329.35 2,651.02 2,562.17 449.56 -256.87 5,945,97893 316,757.74 0.21 517.54 MWD+IFR-AK-CAZ-SC(5) 2,832.23 27.53 32974 2,733.01 2,644.16 486.35 -278.50 5,946,016.24 316,737.01 0.21 560.18 MWD+IFR-AK-CAZ-SC(5) 2,927.36 2761 329.32 2,817.34 2,728.49 524.30 -300.83 5,946,05471 316,715.61 0.22 604.17 MWD+IFR-AK-CAZ-SC(5) 3,02163 2769 329.97 2,900.84 2,811.99 562.05 -322.94 5,946,092.99 316,694.43 0.33 647.89 MWD+1FR-AK-CAZSC(5) 3,11647 2768 329.26 2,984.82 2,895.97 600.05 -345.23 5,946,131.53 316,673.08 0.35 691.91 MWD+IFR-AK-CAZSC(5) E 3,211.13 S- 2767 328.83 3,068.65 2,979.80 637.76 567.84 5,946,169]6 316,651.39 0.21 735.82 MWD+IFR-AK-CAZSC(5) 3,30468 27.69 328.61 3,151.50 3,062.65 674.90 590.40 5,946,207.44 316,629.73 0.11 779.21 MWD+IFR-AK-CAZSC(5) 3,393.21 2768 32889 3,235.20 3,146.35 712.45 113.19 5,946,245.53 316,607.87 0.14 82396 MWD+IFR-AK-CAZSC(5) 3,493.50 27.83 328.52 3,318.65 3,229.80 749.97 436.00 5,946,283.59 316,585.98 0.24 866.90 MW +1FR-AK-CAZ-SC(5) 3,566.10 29.05 329.23 3,40163 3,312.98 788.54 A59.28 5,946,322]1 316,563.64 1.34 911.88 M0D+IFR-AK-CAZ-SC(5) 3,682.63 32.13 329.36 3,483.19 3,394.34 629.90 -483.84 5,946,36965 316,540.10 3.26 959.93 MWD+IFR-AK-CAZ-3C(5) 3.77678 3378 329.06 3,562.19 3,473.34 873.89 -510.06 5.946409.26 316.514.96 1.76 1,011.08 MWD+IFR-AK-CAZ-SC(5) 9/18/1018 3:52.08PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc.-WNS Local Co-ordinate Reference: Project: Western North Slope TVD Reference: SRO: GMT1 Lookout Pad MD Reference: Well: MT6-08 North Reference: Wellbore: MT6-08PB1_Cancelled Survey Calculation Method: Design: C2PB1-wp02 Database: Survey Well MT6-08 Actual MT6-08 @ 88.85usft (Actual Doyani9) Actual MTS -08 @ 88.85usft (Actual Doyani9) True Minimum Curvature EDT 14 Alaska Production DA (ER M UGH ES 9/18/2018 3:52.08PM Page 5 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc AZI TVD TVDSS *NI -S +E1 -W DLg (usft) (°) (°) Waft)Waft) (usft) (usft) Northing Easting (°1168') Section Survey Tool Name Annotation (ft) (ft) (ft) 3,870.99 36.86 329.15 3,639,05 3,550.20 920.62 -538.02 5,946,456.66 316,488.14 3.27 1,06548 MWD+IFR-AK-CAZSC(5) 3,964.95 39.79 330.08 3,712.76 3,623.91 970.89 567.47 5,946,507.62 316,459.92 3.18 1,12369 MWD+IFR-AK-CAZSC(5) 4,059.60 43.21 3M.76 3,783.63 3,694.78 1,025.43 598,42 5,946,562.89 316,430.31 3.64 1,186.37 MWD+IFR-AK-CAZSC(5) 4,154.32 46.15 330.05 3,850.98 3,762.13 1,083.33 53131 5,946,621.57 316,398.83 3.15 1,252.94 MWD+IFR-AK-CAZSC(5) 4,246.89 48.67 330.74 3,913.62 3,82477 1,142.58 564.97 5,946,681.62 316,366.62 2.78 1,321.06 MWD+IFR-AK-CAZSC(5) 4,341.08 51.62 330.64 3,973.97 3,885.12 1,20563 -700.37 5,946,745.50 316,332.77 3.13 1,393.34 MWD+11FR-AK-CAZSC(5) 4,435.15 54.34 330.20 4,030.61 3,941.76 1,270.94 -73744 5,946,811.69 316,297.30 2.92 1,468.42 MWD+IFR-AK-CAZ-SC(5) 4,529.18 56.40 330.95 4,094.04 3,995.19 1,338.32 -775.45 5,946,879.98 316,260.94 2.29 1,545.76 M1MD+IFR-AK-CAZ-SC(5) 4,624.11 5694 331.53 4,136.20 4,047.35 1,407.86 57361 5.W.950A1 316,224.49 0.76 1,625.07 MWD+IFR-AK-CAZ-$C(5) 4,718.84 56.94 331.69 4,187.88 4,099.03 1,477.70 -851.36 5,947,021.15 316,18845 0.14 1,704.46 MWD+IFR-AK-CAZ-SC(5) j 4,613.63 57.12 331.64 4,239.46 4,150.61 1,547.70 -889.10 5,947,092.04 316,152.42 0.19 1,783.98 MWD+IFR-AK-CAZ-SC (5) 4,907.63 57.13 331.86 4,290.49 4,201 64 1,617.24 -926.47 5,947,16246 316,11675 0.20 1,862.93 MWD+IFR-AK-CAZ-SC(5) 5,000.42 57.12 331.32 4,340.85 4,252.00 1,685.79 -963.55 5,947,23188 316,081.35 049 1,940.86 MWD+IFR-AK-CAZ-SC(5) 5,095.24 57.19 330.85 4,392.28 4,30343 1,755.52 -1,002. D6 5,947,302.53 316,044.55 041 2,020.51 MW1)+IFR-AK-CAZ-SC(5) 5,189.45 57.16 33009 4,443.35 4,354.50 1,824.41 -1,041.07 5,947,372.34 316,007.22 0.69 2,099.65 MWD+FR-AK-CAZ-SC (5) 5,282.09 57.13 32947 4,493.61 4,404.76 1,891.65 -1,08024 5.947,44051 315,96970 0.56 2,177.42 MWD+IFR-AK-CAZ-SC (5) 5,37589 57.21 329.58 4,544.46 4,45561 1,959.58 -1,120.21 5,947,509.39 315,931.39 0.13 2,256.16 MWD+IFR-AK-CAZ-SC(5) 5,470.41 57.14 329.55 4,59570 4,506.85 2,028.06 -1,16045 5,947,578.82 315,892.84 0.08 2,335.52 MWD+IFR-AK-CAZ-SC(5) 5,564.62 57.11 329.93 4,646.84 4,557.99 2,096.41 -1,200.32 5,947,648.11 315,854.64 0.34 2,414.59 MWD+IFR-AK-CAZ-SG(5) 5,658.93 57.17 32966 4,698.01 4,609.16 2,164.87 -1,240.18 5,947,717.52 315,816.46 0.25 2,493.75 MWD+IFR-AK-CAZ-SC(5) 5,753.21 57.11 329.94 4,749.17 4,660.32 2,233.32 -1,280.01 5,947,786.91 315,778.30 0.26 2,572.89 MWD+IFR-AK-CAZ-SC(5) 5,847.43 5719 330.16 4,800.27 4,711.42 2,301.90 -1,319.53 5,947,85643 315,740.47 0.21 2,652.00 MWD+IFR-AK-CAZ-SC(5) 5,884.36 57.15 330.06 4,820.30 4,731.45 2,328.80 -1,334.99 5,947,883]0 315,725.66 0.25 2,683.01 MWD+11FR-AK-CAZSC(5) 5,949.00 57.18 330.54 4,855.35 4,766.50 2,37598 -136190 5,947,931.51 315,699.91 0.63 2,737.30 MWD+IFR-AK-CAZSC(5) 6,043.31 5709 331.22 4,906.52 4,817.67 2,445.18 -1,400.45 5,948,001.63 315,663.05 0.61 2,816.50 MWD+IFR-AK-CAZSC(5) 6,136.75 56.99 331.33 4,957.36 4,866.51 2,513.94 -1,438.13 5,948,07127 315,627.06 0.15 2,899.90 MWD+IFR-AK-CAZSC (5) 6,231.63 56.99 331.99 5,009.05 4,920.20 2,583.96 -1,475.90 5,948,142.19 315,591.00 0.58 2,97446 MWD+IFR-AK-CAZSC(5) 6,326.37 56.97 331.33 5,060.68 4,971.83 2,653.88 -1513.61 5,948,213.00 315,555.00 0.58 3,053.90 MWD+11FR-AK-CAZSC (5) 6,42060 56.93 331.43 5,112.07 5,023.22 2,723.21 -1,551.44 5,948,283.22 315,51887 0.10 3,132.88 MWD+IFR-AK-CAZSC(5) 6,515.51 56.95 3W,76 5,163.84 5,074.99 2,792.85 -158989 5,948,353.77 315,482.13 0.59 3,212.41 MWD+IFR-AK-CAZSC(5) 6,609.45 5695 33023 5,215.08 6126.23 2861.37 -1628.67 5,948,423.21 315,445.03 0.47 3,291.12 MM+IFR-AK-CAZ-SC(5) DA (ER M UGH ES 9/18/2018 3:52.08PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhilli s p Definitive Survey Report Company: ConocePhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-08 Project: Western North Slope TVD Reference: Actual MT6-OB @ 88.85usft (Actual Doyan19) Site: GMT1 Lookout Pad MD Reference: Actual MT6-OB @ 88.85usft (Actual Doyan19) Well: MT6-08 North Reference: True Wellbore: MT6-08PB1_Cancelled Survey Calculation Method: Minimum Curvature Design: C2PB1-wp02 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El -W DLS (usft) (1) (') (usft) (usft) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 6,703.16 56.94 329.91 5,266.19 5,177.34 2,929.44 -1,667.66 5,948,492.21 315,407.51 0.29 3,369.62 MWD+IFR-AK-CAZSC(5) 6,798.37 56% 32905 5,318.11 5,229.26 2,998.19 -1,708.38 5,948,561.92 315,368.67 0.75 3,449.35 MWD+1FR-AK-CAZSC(5) I 6,89216 56.90 328.81 5,35962 5,280.77 3,065.95 -1,749.20 5,948,63064 315,329.51 0.23 3,528.34 MWD+IFR-AK-CAZSC(5) i i 6,985.81 56.94 328.65 5,42041 5,331.56 3,132.59 -1,789.66 5,948,698.24 315,290.68 0.14 3,608.19 MWD+1FR-AK-CPZSC(5) 7,080.26 56.92 328.97 5,471.95 5,383.10 3,200.30 -1,830.64 5,948,765.93 315,251.36 0.28 3,685.22 MWD+IFR-AK-CAZSC(5) 7,174.26 56.91 329.22 5,52326 5,434.41 3,267.88 -1,871.10 5,948,83546 315,212.56 0.22 3,763.88 MWD+IFR-AK-CAZ-SC(5) t 7,268.18 56.95 33023 5,574.51 5,485.66 3,335.85 -1,910.77 5,948,904.37 315,174.55 0.90 3,842.52 MWD+1FR-AK-CAZ-SC(5) 7,362.87 56.97 330.11 5,626.14 5,53729 3,404.71 -1,950.26 5,948,974.17 315,135.75 0.11 3,921.86 MWD+IFR-AK-CAZ-SC(5) { 1 f 7,456.58 56.91 33058 5,677.26 5,58841 3,472.96 -1,989.12 5,949,04334 315,099.57 0.43 4,000.37 MWD+IFR-AK-CA7-SC(5) 7,550.93 �I 56.98 33030 5,72812 5,639.87 3,541.75 -2,028.13 5,949,113.05 315,062.24 0.26 4,079.42 MWD+IFR-AK-CAZ-SC(5) j 7,644.74 56.96 33041 5,779.85 5,691.00 3,610.10 -2,067D3 5,949,182.32 315,025.01 0.10 4,158.03 MWD+IFR-AK-CAZ-SC(5) f 7,739.64 56.96 330.17 5,831.59 5,742.74 3,679.20 -2,10646 5.949,252.35 314,987.28 021 4,237.55 MWD+IFR-AK-CA7-SC(5) I ip 7,834.36 56.94 33020 5,883.25 5,79440 3,748.08 -2,145.93 5,949,322.17 314,94949 0.03 4,316.91 MWD+IFR-AK-CAZ-SC(5) 7,928.38 56.99 330.86 5,934.51 5,84566 3,816.71 -2,184.71 5,949,391.71 314,912.39 0.59 4,395.71 MWD+IFR-AK-CAZ-SC (5) 8,023.11 56.93 331.18 5,986.16 5,897.31 3,886.1] -2,223.19 5,949,462.09 314,875.62 0.29 4,475.11 MWD+IFR-AK- AZ - C SC (5) 8,117.48 56.96 331.57 6,037.63 5,94878 3,955.60 -2,261.08 5,949,532.41 314,839.43 0.35 4,554.20 MWD+IFR-AK-CAZ-SC(5) 8,212.28 55.94 331.55 6,089.33 6,000.48 4,025.47 -2,298.92 5,949,603.18 314,803.30 0.03 4,633.65 MWD+IFR-AK-CAZ-SC (5) 8,306.14 56.95 331.34 6,140.53 6,05168 4,094.57 -2,336.53 5,949,673.17 314,767.38 0.19 4,712.32 MWD+IFR-AK-CAZ-SC (5) v 8,400.35 56.96 331.59 6,191.90 6,103.05 4,163.95 -2,374.25 5,949,743.44 314,731.36 0.22 4,791.29 MWD+1FR-AK-CAZ-SC (5) g 8,494.58 5690 330.79 6,243.32 6,154.47 4,233.14 -2,412.30 5,949,813.53 314,695.00 0.71 4,870.25 MWD+IFR-AK-CAZ-SC(5) Ii 8,588.63 57.11 330.34 6,294.53 6,205.68 4,301.84 -2,451.07 5,949,883.14 314,657.92 0.46 4,949.10 MWD+IFR-AK-CAZ-SC(5) 8,682.94 57.07 331.02 6,345]8 6,256.93 4,370.87 -2,489.84 5949,953.09 314,620.84 0.61 5,028.26 MWD+1FR-AK-CAZSC(5) y 8,777.78 57.15 330.28 6,397.28 6,308.43 4,440.29 -2,528.87 5,950,023.43 314,583.50 0.66 5,107.88 MWD+1FR-AK-CAZSC(5) I 8,87143 57.17 329.94 6,448.06 6,359.21 4,508.50 -2,568.08 5,950,092.57 314,545.96 0.31 5,186.52 MWD+IFR-AK-CAZSC(5) i j 8,96540 57.17 329.44 6,499.01 6,410.16 4,576.67 -2,607.93 5,950161.69 314,507.78 045 5,26542 MWD+IFR-AK-CAZSC(5) 9,059.33 57.12 329.39 6,549.97 6,461.12 4,644.60 -2,648.08 5,950,230.56 314,469.30 0.07 5,344.25 MWD+1FR-AK-CAZSC(5) 9,154.97 57.14 329.73 6,601. B7 6,513.02 4,713.86 -2,688]8 5,950,300.78 314,430.30 0.30 5,424.50 MWD+11FR-AK-CAZSC(5) P 9,247.57 f 57.21 329.57 6,652.07 6,563.22 4,781.01 -2,728.10 5,950,368.87 314,392.63 0.16 5,50225 MWD+1FR-AK-CAZSC(5) I 9,343.64 57.06 329.89 6,704.20 6,615.35 4,850.68 -2,768.80 5,950,439.50 314,353.63 0.28 5,582.89 MWO+IFR-AK-CAZSC(5) ' 9,434.44 56.94 330.13 6.753.66 6,664.81 4,916.62 -2,806.90 5,950,50.35 314,31].15 0.30 5,658.99 MWD+1FR-AK-CAZ-SC(5) 9,529.36 57.01 330.58 6,605.39 6716.54 4985.79 -2.84626 5,950.57644 314,27948 040 5,738.54 MWD+1FR-AK-CAZ-SC(5) 9/182018 3:52:08PM Page 6 COMPASS 5000.14 Build 85 9/18/2018 3:52:06PM Page 7 Annotation COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report Map Company: ConocoPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MT6-08 Project: Western North Slope TVD Reference: Actual MT6-08 @ 88.85usft (Actual Doyan19) Site: GMT1 Lookout Pad MD Reference: Actual MT6-08 @ 88.85usft (Actual Doyan19) Well: MT6-08 North Reference: True Wellbore: MTB -081'67 Cancelled Survey Calculation Method: Minimum Curvature Design: C2PB1-wp02 Database: EDT 14 Alaska Production Survey (usft) (usft) 9/18/2018 3:52:06PM Page 7 Annotation COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Eating DLS Section (usft) V) (1) (usft) (usft) (usft) (usft) (01100, Survey Tool Name 9,623.53 56.94 330.55 6,85691 6,767.86 5,054.55 -2,885.06 5,950,646.13 314,242.36 0.08 5,817,48 MWD+IFR-AK-CAZSC(5) 9,718.83 56.94 330.83 6,908.70 6,819.85 5,124.19 -2,924.16 5,95,716.70 314,204.97 0.25 5,897.33 MWD+IFR-AK-CAZSC(5) 9,813.79 56.98 331.00 6,960.47 6,871.62 5,193.76 -2,962.86 5,950,787.18 314,167.98 0.16 5,976.92 MWD+IFR-AK-CAZSC(5) 9,906.91 56.96 330.86 7,011.23 6,922.38 5,262.00 5,000.79 5,950,856.31 314,131.72 0.13 6,054.98 MWD+IFR-AK-CAZSC(5) 10,000.80 5695 330.68 7,062.43 6,973.58 5,330.68 5,039.22 5,950,925.90 314,094.97 0.16 6,13366 MWD+IFR-AK-CAZSC(5) 10,094.80 56.97 330.81 7,11368 7,024.83 5,399.43 -3,077.73 5,950,995.56 314,058.14 0.12 6,212.44 MWD+IFR-AK-CAZSC(5) 10,189.24 56.94 330.86 7,165.18 7,076.33 5,468.55 5,116.31 5,951,065.60 314,021.26 0.05 6,291.59 MWD+IFR-AK-CAZSC(5) 10,283.06 56.96 330.38 7,216.35 7,127.50 5,537.08 5,154.89 5,951,135.04 313,984.36 0.43 6,370.21 14WD+IFR-AK-CAZSC(5) 10,328.00 56.68 330.77 7,240.94 7,152.09 5,569.84 5,173.37 5,951,168.24 313,966.68 0.96 6,407.81 MM (6) 10,371.87 55.69 329.03 7,265.36 7,176.51 5,601.37 -3,191.64 5,951,200.20 313,949.18 3.99 6,444.23 MWD (6) 10,435.64 53.52 327.42 7,302.29 7,213.44 5,645.56 5,219.01 5,951.245.04 313,922.90 3.98 6,496.10 MWD (6) 10,513.25 52.96 326.04 7,348.74 7,259.89 5,69255 -3,253.11 5,951,297.84 313,890.07 1.60 6,558.02 MWD+IFR-AK-CAZ-SC(7) 10,607.78 56.47 325.64 7,403.34 7,314.49 5,761.39 -3,296.44 5,951,362.70 313,848.31 3.73 6,634.73 MWD+IFR-AK-CAZSC(7) 10,702.52 60.35 320.34 7,452.96 7,36413 5,825.73 5,345.04 5,951,42821 313,801.28 6.28 6,714.37 MWD+1FR-AK-CAZ-SC(7) 10,796.51 63.47 322.54 7,497.24 7,408.39 5,890.57 5,396.70 5,951,49428 313,751.22 3.91 6,795.88 MWD+IFR-AK-CAZ-SC(7) 10,890.50 63.63 322.45 7,539.10 7,450.25 5,957.33 3,447.93 5,951,562.26 313,701.63 0.19 6,878.89 MWD+IFR-AK-CAZ-SC(7) 10,984.62 63.44 32558 7,581.05 7,492.20 6,025.50 5,497.43 5,951,631.60 313,653.80 298 6,962.32 MWD+1FR-AK-CAZ-SC(7) 11,078.98 64.49 328.54 7,62248 7,533.63 6,096.65 3,543.52 5,951,70385 313,609.46 3.03 7,046.78 MWD+IFR-AK-CAZ-SC(7) 11,173.33 64.42 334.34 7,663.19 7,574.34 6,171.37 5,584.19 5,951,77953 313,570.61 5,55 7,131.86 MWD+IFR-AK-CAZ-SC(7) 11,267.75 64.31 335.12 7,704.04 7,615.19 6,248.35 5,620.53 5,951,85237 313,53646 0.75 7,216.88 MWD+IFR-AK-CAZ-SC (7) 11,362.75 65.40 336.47 7,744.41 7,655.56 6,326.78 5,655.79 5,951,93663 313,602.82 112 7,302.68 MWD+IFR-AK-CAZ-SC(7) 11,454.96 68.55 336.87 7,780.47 7,69162 6,404.70 3,68939 5,952,015.33 313,471.13 3.44 7,387.25 MWD+IFR-AK-CAZ-SC(7) 11,509.07 71.44 3M.74 7,812.66 7,723.81 6,485.97 x724.21 5,952,09]43 313,43829 307 7,475.36 MWD+IFR-AK-CAZ-SC(7) 11,643.25 74.15 335.46 7,840.52 7,751.67 6,568.21 5,760.67 5,952,18052 313,403.85 3.16 7,565.08 MWD+IFR-AK-CAZ-SC(7) 11,737.72 77.54 334.60 7,863.62 7,774.77 6,651.24 -3,799.33 5,952,264.46 313,367.21 370 7,656.53 MWD+IFR-AK-CAZ-SC(7) 11,831.11 80.13 334.70 7,881.70 7,792.85 6,734.03 -3,836.56 5,952,348.17 313,330.01 2.78 7,748.05 MWD+IFR-AK-CAZ-SC(7) 11,924.79 82.12 335.25 7,896.15 7,807.30 6,817.90 3,87711 5,952,432.96 313,292.91 2.20 7,840.47 MWD+IFR-AK-CAZSC(7) 12,019.14 8220 334.92 7,909.02 7,820.17 6,902.67 3,917.08 5952,518.65 313,255.61 0.36 7,93380 MWD+IFR-AK-CAZSC(7) 12,113.12 82.26 33540 7,921.73 7,832.88 6,987.17 3956.20 5,952,604.08 313,218.56 0.51 8,026.77 MWD+IFR-AK-CAZSC(7) 12,208.05 82.07 335.17 7,934.67 7,845.82 7,072.60 5,995.52 5,952,690.43 313,181.33 0.31 8,120.66 MWD+IFR-AK-CAZ-SC(7) 12,302.56 8201. 334.97 794776 7,85891 7.15748 -0074.97 5,952,776.24 313,14395 822 8,214.12 MWD+IFR-AK-CA2-SC(7) 9/18/2018 3:52:06PM Page 7 Annotation COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report BAFWHE$ Q Company: Project: Site: Well: Wellbore: Design: ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-08 MTB-08PB1_Cancelled C2PB1-wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-08 Actual MT6-08 @ 88.85usft (Actual Doyanl9) Actual MT6-O8 @ 88.85usft (Actual Doyanl9) True Minimum Curvature EDT 14 Alaska Production j survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E1 -W DLS (") C) (usft) (usft) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name Annotation(usft) (ft) (ft) (ft) 12,397.01 83.94 33501 795931 7,87046 724242 4,07460 5,952,862.12 313106.40 204 8,30773 MWD+IFR-AK-CAZSC(7) 12,489.53 8566 333.10 7,967.69 7,878.84 7,325.27 4.11491 5,952,945.91 313,060.12 2.77 8,399.80 MWD+IFR-AK-CA7SC(7) 12,522.70 86.78 331.97 7,969.88 7,881.03 7,354.63 4,130.18 5,952,975.64 313,053.57 4.79 8,43289 M1ND+IFR-AK-CAZSC(7) 12,59603 88.02 332.25 7,973.21 7,884.36 7,419.38 4,164.44 5,953.041.19 313,020.89 1.73 8,506.14 MWD+IFR-AK-CAZSC(8) 12,691.13 88.11 332.13 7,976.42 7,887.57 7,50345 4.208.79 5,953,126.31 312,978.60 0.16 8,601.19 MWD+IFR-AK-CAZSC(8) I 12,786.52 88.02 332.69 7,979.64 7,890.79 7,587.94 4.252.94 5,953,211,84 312,936.52 0.59 8,696.52 MWD+IFR-AK-CAZ-SC(8) ) 12,882.36 87.92 333.77 7,983.03 7,894.18 7,673.45 4,296.08 5,953,298.37 312,895.47 1.13 8,792.28 MWD+IFR-AK-CAZSC(8) } 12,978.02 88.02 333.62 7,986.42 7,897.57 7,759.15 -0,338.44 5,953,385.07 312,855.21 0.19 8,887.83 MWD+IFR-AK-CAZSC(8) 13,073.29 88.11 333.09 7,989.64 7,900.79 7,84426 4,381.15 5,953,471.18 312,814.59 0.56 8,983.02 MWD+IFR-AK-CAZ-SC(8) 13,168.85 91.10 333.10 7,990.30 7,901.45 7,929.46 4.424.38 5,953,557.41 312,773.44 3.13 9,078.55 MWD+IFR-AK-CAZSC(8) i 13,263]7 89.33 333.41 7,989.94 7,901.09 8,01422 1,467.10 5,953,643.18 312,732.80 1,89 9,173.44 MWD+11FR-AK-CAZ-SC(8) I 13,359.60 89.89 334.86 7,990.59 7,90174 8,10045 4,508.90 5,953,730.39 312,693.10 1.62 9,269.19 MWD+IFR-AK-CAZ-SC(8) 13,455.69 93.34 334.02 7,987.89 7,89904 8,187.09 4,550,33 5,953,818.00 312,653.79 3.70 9,365.14 MWD+IFR-AK-CAZ-SC(8) 1 i 13,550.40 94.63 334.41 7,9B1.30 7,89245 8,272.16 4,591.43 5,953,904.04 312,614.77 1.42 9,459.55 MWD+IFR-AK-0AZ-SC(8) I 13,645.99 93.23 333.27 7,974.75 7,885.90 8,357.75 4,63348 5,953,990.62 312,574.82 1.89 9,554.86 MWD+IFR-AK-CAZ-SC(8) i 13,740.88 92.80 332.60 7,969.76 7,880.91 8,442.13 4,676.59 5,954,076.02 312,533.77 0.84 9,649.60 MWD+IFR-AK-CAZ-SC(8) 13,836.28 91.48 331,95 7,966.20 7,87235 8,526.52 4,720.94 5,95816146 312,491.49 1.54 9,744.93 MWD+IFR-AK-CAZ-SC (8) 13,931.15 9007 33098 7,964.92 7,87607 8,609.85 4,766.25 5,954,245.86 312,448.21 1.80 9,839.78 MWD+IFR-AK-CAZ-SC(8) 14,026.05 92.76 33167 7,962.57 7,873.72 8,693.08 4.811.77 5,954,330.16 312,404.73 2.93 9,934.64 MWD+IFR-AK-CAZ-SC(8) 14,121.49 9327 33205 7,957.55 7,868.70 8,777.12 4,856.72 5,954,415.27 312,36184 0.67 10,029.95 MWD+IFR-AK-CAZ-SC(8) 14,216.54 93.55 33266 7,951.90 7,863.05 8,861.17 4,900.75 5,954,500.36 312,319.88 0.71 10,124.83 MWD+IFR-AK-CAZ-SC(8) 14,312.37 93.58 332.87 7,945.94 7,857.09 8,946.21 4,944.52 5,954,586.43 312,278.19 0.22 10,220.46 MWD+IFR-AK-CAZSC(8) 14,401.47 92.59 332.95 7,940.82 7,851.97 9,030.76 4,987]8 5,954,671.99 312,237.01 1.04 10,31541 MWD+IFR-AK-CAZSC(8) I 14,50245 92.31 333.18 7,936.76 7,84791 9,115.35 -5,030.75 5,954,757.61 312,196.10 0.38 10,410.28 MWD+IFR-AK-CAZSC(8) 3 14,597.91 92.22 333.81 7,932.99 7,844.14 9,20011 -5,073.32 5,954,843.97 312,155.62 067 10,505.64 MWD+IFR-AK-CAZSC(8) i 14,693.76 92.38 334.34 7,92914 7,840.29 9,28685 -5,115.19 59K93109 312,115.85 0.58 10,601.34 MWD+IFR-AK-CAZ-SC(8) 14,789.44 92.16 334.37 7,925.35 7,836.50 9,373.04 5,15656 5,955,018.25 312,076.59 023 10,696.86 MWD+IFR-AK-CAZ-SC(8) 14,88436 92.57 334.62 7,92144 ],832.59 9,45863 5,197.40 5,955,10981 312,037.84 0.51 10,791.61 MWD+IFR-AK-CAZ-SC(8) 14,979.91 89.61 334.88 7,919.62 7,830.77 9,545.03 5,238.15 5,955,192.17 31199921 3.11 10,887.02 MWD+11FR-AK-CAZ-SC(8) 15,074.55 8902 33185 7,92075 7,83190 9,62962 -5,280.57 5,955,277,76 311,958.86 3.26 10,981.62 MWD+IFR-AK-CAZ-SC(8) 15,169.75 89.25 331.74 7,922.19 7833.34 9,71350 -5,325.55 5,955,362.70 311,915.93 0.27 11,076.80 MWD+IFR-AK-CAZ-SC (8) 9/18/2018 3: 52 08P Page 8 COMPASS 5000.14 Build 85 ✓ ConocoPhilli s Company: Con000Phllllps(Alaska) Inc. -WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-08 Wellbore: MT6-08PB1_Cancelled Design: C2PB7-wp02 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-08 Actual MT6-08 @ 88.85usft (Actual Doyam19) Actual MT6-08 @ 88.85usft (Actual Doyan19) True Minimum Curvature EDT 14 Alaska Production -� S j Survey i Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100') Surve Tool Name Y Annotation (ft) (ft) (ft) 15,265.02 88.93 332.67 7,923.70 7,834.85 9,79776 -5,369.97 5,955,448.01 311,873.57 1.03 11,172.06 MWD+IFR-AK-CAZ-SC(8) 15,359.99 90.29 332.90 7,924.35 7,835.50 9,882.21 -5,413.40 5,955,533.49 311,83221 1.45 11267.01 MWD+IFR-AK-CAZ-SC(8) 15,455.68 90.07 332.46 7,924.05 7,83520 9,967.23 -5,457.32 5,955,61954 311,790.37 0.51 11,362.69 MWD+1FR-AK-CAZ-SC(8) 15,551.63 90.23 332.25 7,92379 7,834.94 10,052.23 -5,501.84 5,955,70559 311,74293 028 11,458.64 MWD+IFR-AK-CAZ-SC(8) y 15.646.10 90.60 333.23 7,923.11 7,83426 10,136.20 5,545.11 5,955,790.58 311,706.72 1.11 11,553.10 MWD+IFR-AK-CAZ-SC(8) 15,741.49 94.87 333.54 7,918.56 7,829.71 10,221.37 -5,587.79 5,955,876.76 311,656.13 4.49 11,648.33 MWO+IFR-AK-CAZ-SC (8) ) 15,836.21 96.20 334.04 7,909.42 7,820:57 10,305.95 -5,629.42 5,955,962.32 311,626.56 1.50 11,742.56 MWD+IFR-AK-CAZ-SC (8) 15,931.25 9505 334.77 7,900.11 7,811.26 10,391.25 -5,670.28 5,956,048.58 311,58].79 1.43 11,837.05 MWD+IFR-AK-CAZ-SC(8) 16,025.87 92.06 33286 7,894.24 7,805.39 10,475.98 5,711.95 5,956,134.29 311,548.19 3.75 11,931.42 MWD+IFR-AK-CAZ-SC(8) 16,122.00 90.25 33290 7,892.30 7,80345 10,561.52 -5,755.76 5,956,220.87 311,508.47 1.88 12,027.52 MWD+IFR-AK-CAZ-SC(8) 16,216.24 89.09 333.45 7,892,85 7,80400 10,645.61 -5,798.29 5,956,305.97 311,466.01 1.36 12,121.73 MWD+IFR-AK-CAZ-SC(8) ' 16,311.34 88.16 333.31 7,895.13 7,806.28 10,73061 -5,840.89 5,9K391.97 311,425.49 0.99 12,216.78 MWD+IFR-AK-CAz-SC (8) 16,406.11 88.91 33373 7,897.55 7,808.70 10,815.41 -5,883.13 5,956,477.76 311,385.32 0.91 12,311.48 MWD+IFR-AK-CAZ-SC(a) 16,501.84 89.31 33452 7,899.04 7,810.19 10,901.53 -5,924.90 5,956,56487 311,345.66 0.92 12,407.13 MWD+IFR-AK-CAZ-SC(8) j 16,598.15 87.76 333.89 7,901.50 7,812.65 10,998.21 -5,966.80 5,956,652.54 311,305.88 1.74 12,503.33 MWD+IFR-AK-CAZ-SC(8) i 16,692.77 88.82 33393 7,904.32 7,815.47 11,073.15 5,008.39 5,956,738.45 311,266.37 1.12 12,597.85 MWD+IFR-AK-CAZ-SC(8) j 16,787.70 88.63 336.37 7,906.44 7,817.59 11,159.26 5,048.27 5,956,825.51 311,228.59 2.58 12,692.60 MWD+IFR-AK-CAZ-SC(8) 16,882.87 88.23 33461 7,909.04 7,820.19 11,245.82 -6,087.73 5,956,912.99 311,191.24 1.90 12,787.55 MWD+IFR-AK-CAZSC(e) 16,977.13 89.00 332.01 7,911.32 7,82247 11,330.00 5,130.06 5,956,998.17 311,150.98 2.68 12,881.75 MWD+IFR-AK-CAZ-SC(8) 17,072.90 89.06 331.71 7,912.94 7,824.09 11414.44 5,175.22 5,957,083.68 311,107.89 0.32 12,977.51 MWD+IFR-AK-CAZ-SC(8) 17,168.45 88.50 331.24 7,914.98 7,826.13 11,498.37 5,220.84 5,957,168.69 311,064.33 0.77 13,073.03 MWD+IFR-AK-CAZSC(8) 17,262.95 8863 331.33 7,91].35 7,828.50 11,581.23 5,266.22 5,957,25261 311,020.97 0,17 13,167.49 MWD+IFR-AK-CA7SC(8) 17,359.07 88.63 331.43 7,919.64 7,830.79 11,665.58 5,312.25 5,957,338.05 310,977.00 0.10 13,263.58 MWD+IFR-AK-CAZSC(8) 17,454.64 88.60 33202 7,921.95 7,833.10 11,749.72 5,357.51 5,957,423.26 310,933.81 0.62 13,359.12 MWD+IFR-AK-CAZSC(a) 17,54963 9008 33162 7,923.05 7,834.20 11,833.44 5,402.37 5,957,508.05 310,891.00 1.61 13,454.10 MWD+IFR-AK-CAZSC(8) 3. 3 17,645.21 93.44 332.75 7,920.11 7,831.26 11,917.93 5,446.94 5,957,593.58 310,848.50 3.71 13,54962 MWD+IFR-AK-CAZSC(8) 17,74022 98.55 333.98 7,910.19 7,821.34 12,002.36 5,489.29 5,957,679.01 310,808.21 5.53 13,644.05 MWD+IFR-AK-CAZSC(8) 17,835.53 96.22 334.51 ],89].94 7,809.09 12,087.48 5,530.35 5,957,765.10 310,769.23 2.51 13,738.49 MWD+IFR-AK-CAZ-SC(8) 17,93122 92.96 334.24 7.890.29 7,801.44 12,173.47 5,571.60 5,957,852.06 310,730.09 3.42 13,833.77 MWD+IFR-AK-CAZSC(8) 1, 18,025.31 93.03 334.01 7,885.37 7,796.52 12,258.01 5,612.61 5,957,93].5] 310,691.15 0.26 13927.67 MWD+IFR-AK-CAZ-SC (8) i-- 18,120.8] 93.12 334.74 7,880.24 7791.39 12,344.05 565387 5,958,024.58 310651.99 077 14,023.00 MWD+IFR-AK-CAZ-SC(8) 3 9/182018 3:52:08PM Page 9 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-08 Project: Western North Slope TVD Reference: Actual MTB -08 @ 88.85usft (Actual Doyanl9) Site: GMT1 Lookout Pad MD Reference: Actual MTB -08 @ 88.85usft (Actual Doyan19) Well: MT6-08 North Reference: True Wellbore: MT6-08PB1_Cancelled Survey Calculation Method: Minimum Curvature Design: C2PB1-wp02 Database: EDT 14 Alaska Production Survey IlAq(�GHFS Annotation _ 9/18/2018 3:52:08PM Page 10 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°/100 ) Section Survey Tool Name (R) (R) (ft) 18,216.56 92.83 332.51 7,87528 7,78643 12,429.66 -,696.32 5, 958,111 A9 310,61163 2.35 14,118.52 MWD+IFR-AK-CAZ-SC(8) 18,311.17 91.82 331.91 7,871.44 7,78259 12,513.28 5,740.40 5,958,195.86 310,569.61 1.24 14,213.05 MWD+IFR-AK-CAZ-SC(8) 18,40757 89.12 332.65 7,870.65 7,781.80 12,598.61 -6,78523 5,958,28224 310,526.86 2.90 14,309.43 MWD+IFR-AK-CAZ-SC(8) 18,502.80 89.06 334.78 7,872.16 7,783.31 12,683.98 5,82740 5,958,36860 310,486.79 2.24 14,404.60 MWD+IFR-AK-CAZ-SC(8) 18,599.02 87.24 334.92 7,875.27 7,786.42 12,771.03 5,868.26 5,958,456.61 310,448.05 1.90 14500.65 MWD+IFR-AK-CAZ-SC(8) 18,693.50 87.58 33347 7,879.54 7,790.69 12,856.00 -,909.35 5,958,542.55 310,409.04 1.57 14,59496 MWD+IFR-AK-CAZ-SC(8) 18,78902 88.54 331.78 7,882.77 7,793.92 12,940.77 -5,953.24 5,958,628.36 310,367.22 2.03 14,690.41 MWD+IFR-AK-CAZSC(8) 18,883.37 88.94 332.85 7,884.84 7,795.99 13,024.29 5,997.07 5,958,712.92 310,325.44 1.21 14,784.73 MWD+IFR-AK-CAZSC(8) 18,97863 90.08 33175 7,885.66 7,796.81 13,108.63 -7,041.35 5,958,798.30 310,283.23 1.66 14,87998 MWD+IFR-AK-CAZ-SC(8) 19,07424 90.38 330.99 7,885.28 7,796.43 13,192.55 -7,087.16 5,958,883.30 310,239.47 0.85 14,975.59 MWD+IFR-AK-CAZSC(8) 19,169.37 9644 331.23 7,884.59 7,7%.74 13,275.84 -7,133.12 5,958,967.68 310,195.55 0.26 15,070.71 MWD+IFR-AK-CAZSC(8) 19,264.21 90.22 333.01 7,884.05 7,795.20 13,359.66 -7,177.46 5,959,052.55 310,153.26 1.89 15,165.54 MWD+IFR-AK-CAZSC(8) 19,359.50 90.25 333.95 7,883.66 7,794.81 13,444.93 -7,220.01 5,959,138.82 310,112.80 0.99 15,26679 MWD+IFR-AK-CAZSC(8) 19,454.77 90.01 3W78 7,883.44 7,794.59 13,530.45 -7,261.98 5,959,225.34 310,072.93 0.31 15,35601 MWD+IFR-AK-CAZSC(a) 19,550.10 89.18 332.51 7,884.12 7,795.27 13,615.50 -7,305.04 5,959,311.40 310,031.95 1.59 15,451.32 MWD+IFR-AK-CAZSC(8) 19,645.88 88.90 333.02 7,885.72 7,796.87 13,700.65 -7,348.86 5,959,397.58 309,990.20 0.61 15,547.07 MWD+IFR-AK-CAZSC(8) 19,740.87 91.55 334.94 7,885.35 7,796.50 13,786.00 -7,390.53 5,959,483.91 39,950.63 3.44 15,647.99 MWD+IFR-AK-CAZSC(8) 19,835.53 93.00 335.81 7,881.59 7,792.74 13,871.98 -7,429.94 5,959,570.82 309,913.32 179 15,736.40 MWD+IFR-AK-CAZSC(8) 19,93077 9176 33667 7,877.63 7,788.78 13,959.07 -7,468,28 5,959,658.81 309,8T, 11 1.58 15,831.29 MWD+IFR-AK-CAZSC(8) 20,026.26 91.11 333.47 7,875.24 7,786.39 14,045.62 -7,59,51 5,959,746.31 309,839.00 3.42 15,92660 MWD+IFR-AK-CAZSC(8) 20,12067 91.98 331.69 7,872.70 7,783.85 14,129.39 -7,551.97 5,959,831.10 309,797.59 2.10 16,020.97 MWD+IFR-AK-CAZSC(8) 20,215.87 92.09 328.61 7,869.32 7,780.47 14,211.90 -7,599.32 5,959,914.73 309,752.26 3.24 16,116.05 MWD+IFR-AK-CAZSC(8) 20,311.82 91.48 332.94 7,866.33 7,777.48 14,295.57 -7,646.13 5,959,999.51 309,707.50 4.56 16,211.91 MWD+IFR-AK-CAZSC(8) 20,406.66 89.14 335.23 7,865.81 7,776.96 14,380.86 -7,687.57 5,960,085.78 309,668.14 3.45 16,30667 MWD+IFR-AK-CAZ-SC(8) 20,502.36 87.58 333.77 7,868.55 7,779.70 14,467.20 -7,728.75 5,960,173.9 309,629.07 2.23 16,402.23 MWD+IFR-AK-CAZSC(8) 20,597.52 87.36 333.12 7,872.75 7,783.90 14,55224 4,771.25 5,960,259.13 309,588.66 0.72 16,497.26 MWD+IFR-AK-CAZ-SC(8) 20,692.42 91.9 332.59 7,87408 7,785.23 14,63666 -7,814.54 5,960,344.57 309,54744 3.91 16,592.12 MWD+IFR-AK-CAZ-SC(8) 20,78746 95.9 333.59 7,869.06 7,780.21 14,721.27 -7,857.48 5,96.43020 39,59.56 4.34 16,686.99 MWD+IFR-AK-CAZ-SC(8) 20,882.89 95.9 333.55 7,86068 7,771.83 14, 803A0 -7,899.79 5,960,516.32 39,466.33 0.05 16,782.02 MWD+IFR-AK-CAZ-SC(8) 20,978.65 95.20 331.99 7,852.12 7,763.27 14,1391 20 -794343 5,960,602.16 309,42477 1,63 16,877.38 MWD+IFR-AK-CAZ-SC(8) 21.073.17 95.23 332.58 7,843.53 7,75468 14974.53 -7,987.21 5,960,686.52 309,383.03 0.62 16,97151 MWD+IFR-AK-CAZ-SG(8) IlAq(�GHFS Annotation _ 9/18/2018 3:52:08PM Page 10 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Project: Western North Slope TVD Reference: Site: GMT1 Lookout Pad MD Reference: Well: MT6-08 North Reference: Wellbore: MT6-08PB1_Cancelled Survey Calculation Method: Design: C2PB7-Wp02 Database: Survey RA (Eft JUGHES Well MT6-08 Actual MT6-08 @ 88.85usft (Actual Doyan19) Actual MT6-08 @ 88.85usft (Actual Doyanl9) True Minimum Curvature EDT 14 Alaska Production Map Vertical Easting DLS Section Survey Tool Name Annotation (ft) (°/100') (ft) 309,370.43 0.00 17,00022 PROJECTEDIOTD Projection to TD 9/1WO18 3:52:08PM Page 11 COMPASS 5000.14 Build 85 Map MD Inc Azi TVD TVDSS -NI-S •E/ -W Northing (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) 21,102.00 95.23 332.58 ],840.90 7,752.05 15,000.02 A00043 5960 71231 RA (Eft JUGHES Well MT6-08 Actual MT6-08 @ 88.85usft (Actual Doyan19) Actual MT6-08 @ 88.85usft (Actual Doyanl9) True Minimum Curvature EDT 14 Alaska Production Map Vertical Easting DLS Section Survey Tool Name Annotation (ft) (°/100') (ft) 309,370.43 0.00 17,00022 PROJECTEDIOTD Projection to TD 9/1WO18 3:52:08PM Page 11 COMPASS 5000.14 Build 85 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVE® OU U 5 2018 WELL COMPLETION OR RECOMPLETION REPORTAM,4PLIG 1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ ib. 20Anc 25.105 20AAc 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE • WDSPL ❑ No. of Completions: Service ❑Q Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 9/5/2018 14. Permit to Drill Number/ Sundry: - 218-0481318-317 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 7/16/2018 15. API Number: 50.103-20772-00-00 ' 4a. Location of Waaegllll3(Governmeital Section): Surface: � 318' FNL,33941' FEL, Sec 6, T19N, R3E, UM Top of Productive Interval: 3749' FNL, 2217' FEL, Sec 25, T1 IN, R2E, UM Total Depth: 1127' FNL, 934' FEL, Sec 23, T11N, R2E, UM 8. Date TD Reached: 8/29/2018 16. Well Name and Number: - MT6-08/MT6.08PB1 9. Ref Elevations: KB:88.85 GL:37.20 BF: 17. Field / Pool(s): Greater Mooses Tooth Unit/Lookout ' 10. Plug Back Depth MD/TVD: 1165117838 18. Property Designation:A&7TT-f: • AA0081818, AA0881819 -,b r3 FJ 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 317004 y- 5945523 Zone- 4 TPI: x- 313172 y- 5952712 Zone- 4 Total Depth: x- 309370 y- 5960712 Zone- 4 11. Total Depth MD1TVD: 2110217841 19. DNR Approval Number: 932553, 340760, 932533, 932554 12. SSSV Depth MD/TVD: NONE 20. Thickness of Permafrost MD7f VD: 126 ObIll /t (•i 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 1 N/A (ft MSL)1 21. Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res/Neu/Den/CBL(Inc�$Cµ7- 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD FT TOP BOTTOM SETTING DEPTH TVD HOLE SIZE TOP BOTTOM CEMENTING RECORD AMOUNT PULLED 20 94 H-40 37 115 37 115 42 yr"- Existing, cement to surface 13318 45.5 L-80 37 2111 37 1984 ` 1040 sx 11.0ppg UteCrete 95/8 29.7 L-80 35 10318 35 7235 9.875 100 sx 12.2 ppg Class G 222 sx 15.8 7 26 L-80 32 10018 32 7072 8.75 Tie Back ,r 7 32 L-80 10004 12469 7064 7966 8.75 301 sx 15.8 ppg Class G D� •' '"^` 4.5 12.6 1 L-80 1 12321 120350 17950 17866 16 Liner 24. Open to production or injection? Yes E, No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Perforated Liner@: 12520.20350 MD and 7970-7866 TVD ... 911/2018 JOIv1PLETlOIv ATE VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 41/2 10819 1232117950 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): INJECTION ONLY - NOT PRE -PRODUCED Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing P Casing Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (torr): Form 10-407 Revised 5/2017 ��."j(.�O CObLTINUW ON PAGE2RBDMrj 1^6 OCT 052010 Submit ORIGINAL y f' ` .r'^ F% 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No E If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� , If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1190 1189 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 12231 7938 information, including reports, per 20 AAC 25.071. Formation @ TPI -Alpine C C-30 2117 2084 C-10 2509 2445 K-3 3593 3406 K-2 3912 3671 Albian 96 4684 4169 HRZ 10277 7212 Kalubik 10531 7360 LCU 10682 7443 Top Alpine C 12231 7938 TO MT6-06PB1 TO 11551 7838 Formation at total depth: Alpine 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core clysis, naleontoloo cal report, in orwll test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L. Alvord Contact Name: Tom Polasek Authorized Title: Alaska Drilling Manager Contact Email: tom.q.polasek(ricop.com Authorized Contact Phone: 263-3740 Signature: Date: (.o(4'�L�(Li INSTRUCTIONS General: This forth and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item tb: 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 MT6-08 Multi -Lateral Ire, actor wp08 DRAFT Comple,,jn Schematic as of 09-01-18 10,318' MD / 7236' TVD TO C of 9 5/8 - 9,235 ft MD S C Top of 4-1/2" TXP Liner - 12,321' MD / 0 7" 26 ppf L-80 Tenaris Blue Liner to 12,469' MD / 7966' TVD @ 83 deg 4-1/2" 12.6# L-80 TXP Liner With PerfPups 20,350' MD 6" Hole, TD at at 21,102' MD / 7839' TVD 20" 79 ppf H-40 Insulated Conductor 79 feet, cemented to surface Tubing / Liner Completion: 1) 4!/z' X Landing Nipple (3.813" ID) @ 2037' '0 2) Liner Top Packer l Hanger w/ Tie Back sleeve 3) 4-%" x 1" GLM w1DCK2 SOV @11,285' 13-3/8" 68 ppf L-80 TXP Surface Casing 4) 4-%" DB Landing Nipple w1RHC Plug 2,011' MD / 1,984' TVD Body Installed (3.75" ID) @11,540' cemented to surface 5) Liner Top Packer/ Hanger w/ Tie Back Sleeve PLANNED: 4-112" 12.6 ppf L-80 TSH Blue to - 12, 328' MD 7" 26 ppf L-80 BTC Tieback to 10,018' MD / 7062' TVD @ 57° Top of 7" Tenaris Blue Liner 004' MD / 7062' MD 9 518" 40 ppf L-80 H563 (Surface to 1,381 MD') 9 518" 40 ppf L-80 TXP (1381' MD to 8192' MD) 9 5/8" 40 ppf TN-80HS (8192' MD to TD) 10,318' MD / 7236' TVD TO C of 9 5/8 - 9,235 ft MD S C Top of 4-1/2" TXP Liner - 12,321' MD / 0 7" 26 ppf L-80 Tenaris Blue Liner to 12,469' MD / 7966' TVD @ 83 deg 4-1/2" 12.6# L-80 TXP Liner With PerfPups 20,350' MD 6" Hole, TD at at 21,102' MD / 7839' TVD WNS SVC_ Well AttrihutE COIIOCOP%ll��lp5 :ie10 Nama yne'r' Alaska. mi LOOKOUT MT6-08 MULTIPLE IATERALS- MIBM.&]VA182AW PM Last Tag vs'M1al eMinna&(aoOW) Annotation EMDah oss"PK81 M_81 Last Rev Reason Annotation am"la Mao By ................... . .. . - ---- 9n;ale Rev Reason'. Post Rig Weliwork 9/812018 boebmbh Casing Strings ............................................ ........... casino Descrvpfron o0 20 conductor 20 fel tote! Top lMKel set OepN!enol Set 0 Tom... widen ll... 1912 366 115.0 115.0 94.00 H40Imad H-00 WeldedTop e Welded Casing Oescnpnon OO lin) ID lint Top an" verb. Was Bet am"(TVD)... WNan h... 13-39'Surfatt 1339 1240 367 2,010.6 1983.9 68.00 Create L-80 Top illr»tl TXP CVAId G 38.51!(0 Casing assumption Cabin, Ibllnl Top 611(81 Sat bePln (nKBI SM DeMn f1VD1... WBbn p... 9518' IntennMiate l 958 884 306 10,31].] ],235.3 4000 Ease L40 Top We TXP m owwn: as CT 158 Casing 0exoptbn Op Intermediate 2 J' Tie ] lin) IO 6n) Top Mal SN DeathJKe1 SM Cape 11VD)... vve an 6... 828 3T2 10,0184 7,0720 26.00 Grace 1.80 TBp TM1rW BTCM Back sumv<caang amain Ye nKa^ Caaing Oecnption OD(in) SOL Liner 7 10(In) Top(WE) SN Depth Will Set Cape TTVM) M'ULen 6... 6.28 10,0040 12,469.5 7,966.1 26.00 Grace L-80 Top Tnreao Tenons Blue Liner Details . F Na(in) l0 TapMO Top (ND)mKB)082.0 TOP 156,9 Item Deo Com (l6. 10,036.6 ],0820 58.96 Seal Assembly latching bullet sealsNPGO (Seals 5.76') 6.160 13a'4'sonso,38.7-20105 10,039.5 7.0835 56.96 Setting Sleeve RA Elmer Sleeve 6.21 10,048.4 ],088.4 56.96 Quick Conned No Lima Quick ConneCt,wlBullet Seas 71324 6.151 Tenari5 Blue nlMmneae C, a. ...aID..a 12,463.2 ].9656 85.17 Sebilizer Reamer hoe Stabilizer va Spline roe, 6060 umrnmm� x rrn Bat azo MYS110 Tanana Blue Y.m8a c»Ire Oepnpson oD(inl mel ioPMKaI sM cape 6Mal sal Delae(VER pMtan ll...loops PrOtludion Liner 4 V2 396 123208 20.350.0 7,865.) 12.60 L-80 Toy TSr»o UP Liner Details Nominal 1p To h 13) T6a Mto inner Topincl(' Item Des Cam (int (2,34]4 1,9536 82.93 Hanger4-112"x1" Flex Luck TTI B.1 3.940 asa leem.aaMt as Tubing Strings 0.3RJ L6MCpa xoa, +op Turbine Dasviplion 51nnp MI 1100r) Top!5X10 Set DenteA at De" IND)(._mpars) Grace Toptonnmlion Tubing -Gas Injection 41/2 396 28.8 12,3284 7,9512 1260 L-80 Tblue Completion Details Top moi Top and Telmer Val r) Inm Oes Com No. M.1 mOn) MWrM. 11.ID53 20.0 288 000 Hanger FMC 4-112' Tubing Hanger Hydni 563 3956 20322 2,0089 20.04Nipple-X NIPPLE,LAND(N p 1 ',X,3.013', TSH Blue 3.813 Ca+M:ll".. -� r1.w ws 1 1540.4 ],8099 ]1.17 Nipple -DB NIPPLE,LANDING,4 la ",3.75"OB, TSM Blue 375 12,312.9 7,9492 8222 No -Go Locator Locator No -Go 53r OD 3950 NOW Loa .1Z.2e s.assann1r. 123141 12, 14.1 J,9493 8224 Seal Assembly Seal Assembly 3950 Mandrel Inserts M an Top(..) op (IIKM HII TopMD) Me) Maka MMeI O011p Value Sery Type Latch Type PMS. Ont TRO (pall Run Run Dale Com 1 11,285.3 ),]116 Cemco KEG -2 1 GAS LIFT OV BK 1" 0.313 9182018 SDL(iar, 10.. 612aaga FWucen,.: 12aala a1.�0 Davies, Stephen F (DOA) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Friday, February 15, 2019 7:13 AM To: Davies, Stephen F (DOA) Subject: RE: (EXTERNAL]MT6-08 (PTD218-048) - Completion Report Question Attachments: GMT1 Conductor As -Built CE-MT60-1007_Rev1 .pdf Hi Steve, The Governmental surface location coordinates on the MT6-08 Completions Report are wrong. The correct MT6-08 governmental surface coordinates are 283' FNL, 3227' FEL, Sec 6, T10N, R3E. LIM as stated on the Permit to Drill and which match the GMT Conductor As Built (attached). We did not switch conductor locations for MT6-08 from original plan or Permit To Drill. To check, I mapped the Completions Report location vs AS Built vs mapped imagery overlay, below (first screen capture, image overlay is slightly off). Coordinates in first screen capture are marked with yellow diamond -red outline. Second screen capture has coordinate conversions from NAD83 State Plane to NAD27 Governmental and NAD27 State Plane coordinates. I apologize for the mistake on the completions report. I didn't catch it on my sign off. Thanks and let me know if ConocoPhillips needs to do anything further to fix the error or if you have any other questions, tom From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Wednesday, February 13, 20194:32 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]MT6-08 (PTD218-048) - Completion Report Question Tom, CPAI's Completion Report for MT6-08 shows a surface location of 216' FNL and 3171' FEL, but the Permit to Drill gave those coordinates as 283 FNL and 3227' FEL. The X,Y coordinates on the Completion Report are 317004, 5945523, which match the original 283 FNL and 3227' FEL coordinates. Which are correct? Was the surface location subsequently moved after the Permit to Drill was issued? Note that under regulation 20 AAC 25.015, any change in the surface location of the well requires a new Permit to Drill application. Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e- mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.eov. REVI DATE BY CK APP DESCRIPTION REV DATE BY APP DESCRIPTION 1 02/24/18 RR CZ GH I UPDATED PER K180003ACS ALPINE SATELLITE DEVELOPMENT \GMT1 N TO ALPINE ACCESS ROAD LOCATION OF J CT THIS SURVEY D LL IT gi� 1 GMT1 T 1 p\P VICINITY MAP NOT TO SCALE LEGEND: O PROPOSED CONDUCTOR • EXISTING CONDUCTOR SECTION 31 T.11 N. R. 3 E. U.M. I N .. .. U. . Q P� O F U�QER SNO OES\GN o o�P SS GMT 1 PAD ti PLANT N o 05 N GMjp\PE�'�N� 20.0 '00' LCMF KUUKPIK UMIAQ ALPINE SURVEY OFFICE PRONE: 9W-6766]39 ALPINE MODULE:MT60 UNIT: MT ConocoPhillips ALPINE PROJECT. GMT1 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CARD FlLE NO. 18-02-01-1 02 23 2018 DRAWING NO: CE—MT60-1007 PART: 1 of 3 REV: 1 REVI DATE !BYICKIAPPI DESCRIPTION I REV I DATE IBY APP DESCRIPTION 1 102/24/181 RR I CZ I GH I UPDATED PER K180003ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC. 06, T 10 N, R 3 E, U.M. SFNLINEF /S EXIST. WELL Y X' LAT.(N) LONG.(W) L GND PAD MT6-01 51945,316.08 1,457,169.59 70'15'22.007" 151'28'52.032" 232' 19220' 44.8 52.1 MT6-02 5,945,309.25 1,457,150.88 70'15 21.935 151'28 52.571 239 1902 44.4 52.1 MT6-03 5,945,302.35 1,457,132.05 70-15'21.863"51'2853.114' 247 1883' 44.3 52.2 MT6-04 5,945,295.47 1,457113.24 70'15'21.791" 151'28'53.656" 254' 1864' 44.7 52.2 MT6-05 5,945,288.65 1 457 094.47 70'15'21.719" 151'28'54.197" 261' 1846' 44.8 52.2 MT6-06 5,945,281.78 1 457 075.68 70'15'21.647" 151'28'54.739" 269' 1827' 44.9 52.2 MT6-07 5,945,275.02 1 457 056.87 70'15'21.576" 151'28'55.281" 276' 1809' 44.8 52.4 MT6-O8 5 945 268.15 1 457 038.09 70'15'21.504" 151'28'55.822" 283' 1790' 44.3 52.3 MT6-0 5 945 261.33 1 457 01 .34 70'15'21.433" 151' 8'56.363" 290' 1772' 45.0 52.3 NOTES 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE KUUKPIK U TVI I A 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL Q (B.P.M.S.L.) ALPINE SURVEY OFFICE PHONE: 907-61 739 ALPINE MODULE:MT60 UNIT: MT ConocoPhillips ALPINE PROJECT GMT1 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CAD D RLE NO. 18-02-01-1 02/23/2018 DRAWING NO: 1 CE-MT60-1007 PART: 1 2 of 3 REV: 1 102/24/181 RR I CZ I GH I UPDATED PER K180003ACS NOTES: 1. ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE TOPOGRAPHICAL DESIGN SURVEY DATED 09/09/2015. 3. BASIS OF COORDINATES: GMT1 PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK/UMIAQ, OCTOBER 2017. 4. DATES OF AS -BUILT SURVEYS: WELL CONDUCTORS MT6-01 THRU MT6-09, 02/23/18, FB.2018-05 ,PG.1. .♦♦��P,�E OF ACgs 41 e 49th 1� I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED 1� TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS Pr, : Donald G. Bruce 8 a �'s�%• No. LS -5077 •��• SJ AV'qp Q �AA?..... .....a O�♦♦FESSIONPI � AS -BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. DATE: REGISTRATION NO KUUKPIK UMIAQ ALPINE SURVEY OFFICE PHONE : 907-6704739 ALPINE MODULE:MT60 UNIT: MT ConocoPhillips ALPINE PROJECT GMT1 WELL CONDUCTORS Alaska, Inc. AS—BUILT LOCATIONS CADD FILE N0. DRAWING N0: PART: REV: 18-02-01-1 02/23/2018 CE-MT60-1007 3 OF 3 1 ? Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Amity Coda Time P-T-X Operation (fikB) End Depth (US) 7/14/2018 7114/2018 6.00 MIRU MOVE MOB P Cont. to move pits/motors complexes 0.0 0.0 12:00 18:00 away from well. Raise support feet & skid floor. P/U mats that were underneath pitstmotors complexes. Back sub away from MT6-05. (ACS inspect pad from diesel spill from 5/12/18. No issues) 7/14/2018 711512018 6.00 MIRU MOVE MOB P Grade pad in front of well and prep 0.0 0.0 18:00 00:00 pad. Lay out herculite. SIMOPS - Perform BWM on BOPE. Spot MPD equipment in cellar. NOV install soft speed software on top drive. NIU 4" valves & conductor manifold. Work on MP2's 7/15/2018 7115/2018 8.00 MIRU MOVE MOB P Set herculite & mats for sub. Spot sub 0.0 0.0 00:00 08:00 over well. Move pits/motorscomplex into position. Prep pad for pipe shed. Work on rig acceptance check list. Spot ball mill into position. Connect steam & service lines. Rig accepted 08:00 Hrs. 7/15/2018 7/15/2018 6.00 MIRU MOVE RURD P RIU & hudro test new mud line to 0.0 0.0 08:00 14:00 7500 psi. N/U surface riser, flow line, hole fill & bleeder lines. Load pits w/9.5 ppg Dn Plex spud mud. Install mouse hole. Test gas alarms. NOV continue to work on Soft Speed for top drive. 7/15/2018 7/15/2018 2.00 MIRU MOVE RURD P Finalize pre-spud check list. Bring 0.0 0.0 14:00 16:00 BHA tools & equipment to dg floor. PJSM on BHA. NOV continue to work on Soft Speed for top drive. 7/15/2018 7/15/2018 0.50 MIRU MOVE SFTY P Pre-spud meeting. 0.0 0.0 16:00 16:30 7/15/2018 7/15/2018 1.50 MIRU MOVE RURD P NOV continue to work on Soft Speed 0.0 0.0 16:30 18:00 for top drive. Work on compatibility with new software & lop drive. SIMOPS - clean dg & put back tools & equipment from dg move. 7/15/2018 7/15/2018 0.25 MIRU MOVE SFTY P Rig evacuation drill. All personnel 0.0 0.0 18:00 18:15 accounted for. 7/15/2018 7/15/2018 2.75 MIRU MOVE BHAH P M/U 16" mud motor BHA as per Baker 0.0 93.0 18:15 21:00 reps. MWD offset 68.5° 7/15/2018 7115/2018 0.25 MIRU MOVE BHAH P M/U 2 its HWDP & tag fill @ 100'. 93.0 100.0 21:00 21:15 Attempt to screw into HWDP with top drive. 7/15/2018 7115/2018 2.00 MIRU MOVE RURD T Top drive won't achive desired torque 100.0 100.0 21:15 23:15 and faulting out. Mobilze electrician & NOV tech to dg. Work on compatibility with new software & top drive. SIMOPS - Clean rig 7/15/2018 7/1512018 0.50 MIRU MOVE RURD T Fill hole w/mud. Check for leaks. fluid 100.0 100.0 23:15 23:45 leaking out of riser flange. Tighten flange bolts. Still leaking. 7/15/2018 7/16/2018 0.25 MIRU MOVE RURD T Set HWDP in mouse hole. Pull BHA 100.0 0.0 23:45 00:00 out of hole. Pull bushings 7/16/2018 7/16/2018 1.25 MIRU MOVE RURD T Lift riser & replace gasket & silicone. 0.0 0.0 00:00 01:15 Fill conductor & check for leaks. (good) 7/16/2018 7/16/2018 0.50 MIRU MOVE REAM P PIU stand of HWDP & RIH w/BHA to 0.0 115.0 01:15 01:45 93'. Break circ w/450 gpm, 500 psi, 40 rpm, 4 k trq & clean out to bottom of conductor @ 115' Page 1137 ReportPrinted: 917/2018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Shim Depth Siert Time Emi Time our (hp Phase Op Code Activity Cone Time P-T-X Operaibn (NCB) End Depth (ftKB) 7/16/2018 7/16/2018 0.50 SURFAC DRILL DDRL P Drill ahead f/115'to 132' 115.0 132.0 01:45 02:15 7/16/2018 7/16/2018 0.25 SURFAC DRILL RGRP T Replace belts on ball mill drag chain. 132.0 132.0 02:15 02:30 7/162018 7/16/2018 0.75 SURFAC DRILL DDRL P Drill ahead f/132' to 185' 132.0 185.0 02:30 03:15 7/1612018 7/16/2018 0.75 SURFAC DRILL BHAH P POOH f/132'to 185'. UD HWDP & 185.0 185.0 03:15 04:00 1 1 1 P/U NMFC's. RIH t0 185' 7/16/2018 7/1612018 6.50 SURFAC DRILL DDRL P Drill ahead f/185'to 785' 185.0 785.0 04:00 10:30 7/16/2018 7/16/2018 1.00 SURFAC DRILL CLEN T Clay Attackl!! Flow line & polution pan 785.0 785.0 10:30 11:30 packed off with clay. Stop drilling & clean out packed off clay. 7/16/2018 7/16/2018 0.50 SURFAC DRILL DDRL P Drill ahead f/785' to 836' MD / 836' 785.0 836.0 11:30 12:00 TVD, ADT 5.7 Ars, 650 gpm, 1300 psi, PU wt 92 k, SO wt 92 k, ROT wt 92 k, 60 rpm, 4 / 1.5 k ftAbs trq. 7/1612018 7/16/2018 0.75 SURFAC DRILL DDRL P Drill ahead f/836'to 920' 836.0 920.0 12:00 12:45 7/16/2018 7/1612018 1.25 SURFAC DRILL CLEN T Clay Attack!!! Flow line & polution pan 920.0 920.0 12:45 14:00 packed off with clay. Slop drilling & clean out packed off clay. Re-shoot survey 7/162018 7/16/2018 0.50 SURFAC DRILL SRVY P Shoot MWD survey 920.0 920.0 14:00 14:30 7/16/2018 7/16/2018 0.25 SURFAC DRILL DDRL P Drill ahead f/920'to 932' 920.0 932.0 14:30 14.45 7/16/2018 7/16/2018 1.25 SURFAC DRILL SRW P R/U Gyro & shoot survey., 932.0 932.0 14:45 16:00 7/1612018 7/172018 8.00 SURFAC DRILL DDRL P Drill ahead f1932'to 1,620' MD 11,612' 932.0 1,620.0 16:00 00:00 TVD, ADT 5.2 Hrs (3.1 Rotate / 2.1 Slide), 850 gpm, 2350 psi, PU wt 105 k, SO wt 105 k, ROT wt 105 k, 70 rpm, 5 / 2 k flAbs trq. (Slight flow line pack off @ 1,412') Pumping nut plug sweeps to aid in clay attacks & bit balling. 7/17/2018 7/17/2018 4.00 SURFAC DRILL DDRL P Drill ahead f/1,620" to TO of 2,021' 1,620.0 2,021.0 00:00 04:00 MD / 1,993' TVD, ADT 3.0 Hrs (1.6 Rotate / 1.4 Slide), 850 gpm, 2450 psi, PU wt 122 k, SO wt 120 k, ROT wt 121 k, 70 rpm, 5.5 / 2.5 k ft/lbs trq. Pumping nut plug sweeps to aid in clay attacks & bit balling. 7/17/2018 7/17/2018 2.00 SURFAC CASING CIRC P Pump nut plug sweeps & circ hole 2,021.0 1,872.0 04:00 06:00 clean w/900 gpm, 2400 psi, 80 rpm, 2.5 k trq. Increase mud wt to 9.9 ppg. Racked back 2 stands f12,021' to 1,872' 7/17/2018 7/17/2018 0.25 SURFAC CASING OWFF P F/C(static) 1,872.0 1,872.0 06:00 06:15 7/17/2018 7/17/2018 1.75 SURFAC CASING TRIP P POOH f/1,872'to 369' 1,872.0 369.0 06:15 08:00 711712018 7/17/2018 0.25 SURFAC CASING OWFF P F/C (static) 369.0 369.0 08:00 08:15 7/17/2018 7/172018 0.75 SURFAC CASING TRIP P Rack back HWDP, Jars, & NMFC 369.0 93.0 08:15 09:00 7/17/2018 7/17/2018 0.25 SURFAC CASING CIRC P Pump nut plug sweep & circ BHA 93.0 93.0 09:00 09:15 clean w/875 gpm, 1540 psi, 50 rpm, 1 k trq. 7/17/2018 7/1712018 1.75 SURFAC CASING BHAH P UD BHA as per Baker reps 93.0 0.0 09:15 11:00 Page 2137 Report Printed: 9/7/2018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Deph SWM Time Eod Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End oePth (ftKB) 7/17/2018 7/17/2018 0.75 SURFAC CASING BHAH P Clean & Gear floor of BHA tools & 0.0 0.0 11:00 11:45 equipment. SIMOPS - Clean suction & discharge on both mud pumps. 7/1712018 7117/2018 1.25 SURFAC CASING RURD P R/U to run rasing. M/U Volanl. R/U 0.0 0.0 11:45 13:00 bale extensions & spiders. Bring up power tongs via beaver slide & floor hand had incident with tugger line. 7/17/2018 7/17/2018 0.25 SURFAC CASING SFTY P Safety shut down & re-focus from 0.0 0.0 13:00 13:15 1 tugger incident 7/17/2018 7/1712018 1.75 SURFAC CASING RURD P R/U power tongs, strap tongs, & safety 0.0 0.0 13:15 15:00 valves. 7/17/2018 7/1712018 0.25 SURFAC CASING SFTY P PJSM on running casing 0.0 0.0 15:00 15:15 7/17/2018 7/1712018 7.00 SURFAC CASING PUTB P M/U shoe track & check floats (good). 0.0 1,301.0 15:15 22:15 RIH w/13-318" 68# L-80 TXP casing to 1,301' 7/17/2018 7/1712018 1.00 SURFAC CASING CIRC P Break circ & stage pumps to 8 bpm / 1,301.0 1,301.0 22:15 23:15 150 psi. Circ surface to surface. PU wt 135 k I SO wt 125k 7117/2018 7/1812018 0.75 SURFAC CASING PUTB P Cont to RIH w/13-3/8" 68# L-80 TXP 1,301.0 1,425.0 23:15 00:00 casing f/1,301'to 1,425'. PU wt 160 k / SO wt 100 k 7/18/2018 7/18/2018 1.75 SURFAC CASING PUTB P RIH w/13-3/8" 68# L-80 TXP & Hyd 1,425.0 1,971.0 563 casing f/1,425'to 1,971'. PU wt 00:00 01:45 160k/SO wt 150k 7/18/2018 7/18/2018 0.75 SURFAC CASING HOSO P M/U hanger & landing it. Land casing 1,971.0 2,010.0 01:45 02:30 ion hanger @ 2,010.6 7/18/2018 7/18/2018 2.50 SURFAC CEMENT CIRC P Circ& Gond mud for cement job. 2,010.0 2,010.0 02:30 05:00 Stage pumps up to 8 bpm 1180 psi. Reciprocate pipe. PU wt 165 k / SO wt 152 k. SIMOPS - RID casing running tools & equipment. 7/18/2018 7/18/2018 0.25 SURFAC CEMENT RURD P B/D top drive. R/U cement lines to 2,010.0 2,010.0 05:00 05:15 Volant. 7/18/2018 7/18/2018 2.00 SURFAC CEMENT CIRC P Cont. to circ & cond mud for cement 2,010.0 2,010.0 05:15 07:15 job thru cement linesw/ 8 bpm 1370 psi. Reciprocate pipe. PU wt 165 k / SO wt 152 k. PJSM on cementing. 7/18/2018 7/18/2018 3.75 SURFAC CEMENT CMNT P Rig load 42.5 bola nut plug marker in 2,010.0 0.0 07:15 11:00 pipe. Dowell pump 1 bbls H2O & PT to 3500 psi (good). Dowell pump 105.7 We 10.3 poo mud oush w/4 5 bpm / 110 psi. Shut down & drop bottom ✓ " plug. Dowell pump 324.8 bbls pop 1.92 ft3/sx yield LiteCRETE lead cement 72.7 bbls 15.8 ppa 1.16 ft3/sx yield tail cement @ 4 - 5 bpm. Drop top plug. Dowell pump 20 bbls H2O. P' Rig displace w/268.8 We / 2667 stks 9.8 ppg DrillPlex w/8 bpm 1670 psi. Observe hole trying to pack off. Reduce pumps to 4 bpm 1440 psi. Bump plug, pressure 500 psi over to 1000 psi for 5 min. Check floats / F/C good. CIP @ 11:00 Hrs. Calculate 55 bbls good cement to surface 8 145 bbis cement lost down hole. 7/18/2018 7118/2016 0.50 SURFAC CEMENT W W WH P Flush riser & annular with black water. 0.0 0.0 11:00 11:30 1 I I Function annular & flush second time. 7/18/2018 7/18/2018 1.00 SURFAC CEMENT RURD P RID cement lines. B/D same. RID 0.0 0.0 11:30 12:30 1 1 I I volant & UD same. B/0 landing it & UD same. Page 3/37 Report Printed: 9/712018 Operations Summary (with Timelog Depths) MT6-08 • Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Tone Dur riul Phase Op cove A ity Code Time P -T -X Opennon (WB) End Depth(ftl(a) 7/18/2018 7/18/2018 2.75 SURFAC CEMENT NUND P Remove hole fill & bleeder lines. Drain 0.0 0.0 12:30 15:15 lines. Disconnect Koomy lines. N/D diverter annular & remove from cellar. 7/18/2018 7/1812018 2.50 SURFAC WHDBOP NUND P Bring well head into cellar. NIU well 0.0 0.0 15:15 17:45 head & test void U1000 psi f/10 min good. 7/18/2018 7/18/2018 4.75 SURFAC WHDBOP NUND P N/U BOPE. Tighten speed head. NIU 0.0 0.0 17:45 22:30 choke & kill lines under rig floor. BWM on blind rams. Tighten BOPE rams doors. SIMOPS - Clean pits. Load pipe shed w/9-5/8" casing. M/U floor valves & rocket launcher. 7/18/2018 7/19/2016 1.50 SURFAC WHDBOP MPDA P M/U MPD equipment. NIU MPD 0.0 0.0 22:30 00:00 clamp, orbit valve, flow box. 7/19/2018 7/19/2018 2.25 SURFAC WHDBOP MPDA P NIL MPD lines, Katch Kan, & 1502 0.0 0.0 00:00 02:15 lines. Install test plug. Fill stack w/H20. Energize accumulator unit. Test MPD system to 250 psi for 5 min & 1200 psi for 10 min on chart (good). Remove MPD test plug & install trip nipple. 7/19/2018 7/19/2018 1.00 SURFAC WHDBOP RURD P Install 5" lest joint. R/U BOPE test 0.0 0.0 02:15 03:15 equipment. Fill trip nipple & lines w/H20. Perform shell test. Good) 7/19/2018 7/1912018 0.50 SURFAC WHDBOP SHAH P P/U & bring to floor BHA tools & 0.0 0.0 03:15 03:45 equipment while wait on ELM rep to arrive at dg. 7/19/2018 7/19/2018 6.00 SURFAC WHDBOP BOPE P Test BOPE 250/3500 for 5/10 min's 0.0 0.0 03:45 09:45 w/5 test joints. Annular, 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper/lower 3-1/2" X 6" VBR's & blind rams, 5" DarUFOSV, HCR / Man choke/kill, Accumulator test, Initial 3050 psi, final 1550 psi, 1st 200 psi recharge = 26 sec's, full recharge = 137 second. Gas alarms, PVT alarms and flow indicated tested. Draw down on chokes U1100 psi. AOGCC Adam Earl waived witness, BLM Quinn Sawyer witness test. (F/P on 5" FOSV) 7/19/2018 7/19/2018 1.00 SURFAC WHDBOP RURD P RID testing equipment. B/D lines. Pull 0.0 0.0 09:45 10:45 test plug & set 12.375" ID wear ring. 7/1912018 7/19/2018 1.00 SURFAC CEMENT SFTY P PJSM on BHA 0.0 0.0 10:45 11:45 7/19/2018 7/19/2018 1.75 SURFAC CEMENT BHAH P M/U 12-1/4" BHA#2 as per Baker rep 0.0 619.0 11:45 13:30 to 60'. Plug in and down -load MWD. Cont. to M/U BHA to 619' 7/19/2018 7/19/2018 0.25 SURFAC CEMENT RURD P M/U Baker PBA 619.0 619.0 13:30 13:45 7/19/2018 711912018 0.75 SURFAC CEMENT TRIP P RIH w/BHA#2 f/619'to 1747' 619.0 1,747.0 13:45 14:30 7/19/2018 7119/2018 0.25 SURFAC CEMENT DHEA P Shallow hole lest MWD tools w/650 1,747.0 1,747.0 14:30 14:45 gpm 11480 psi. Circ B/U & cond for casing test. 711912018 7/19/2018 0.50 SURFAC CEMENT RURD P B/D top drive. R/U testing equipment. 1,747.0 1,747.0 14:45 15:15 7/19/2018 7/19/2018 0.75 SURFAC CEMENT PRTS P Pressure test casing to 2500 psi & 1,747.0 1,747.0 15:15 16:00 chart for 30 min (good). 7/19/2018 7/19/2018 0.25 SURFAC CEMENT RURD PR/D testing equipment. 1,747.0 1,747.0 16:00 16:15 Page 4137 Report Printed: 9/7/2018 - Operations Summary (with Timelog Depths) MT6-O8 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKa) 7/19/2018 7/19/2018 3.50 SURFAC CEMENT DRLG P Wash down & tag TOC @ 1,928'. Drill 1,747.0 2,021.0 16:15 19:45 out shoe track & rat hole from 1,928' to 2,021'w/500 gpm / 930 psi, 50 rpm / 3 - 6 k trq. (Float collar & shoe on depth) 7/19/2018 7/19/2018 0.50 SURFAC CEMENT DDRL P Drill 20' new hole f/2,021'to 2,041' 2,021.0 2,041.0 19:45 20:15 MD / 2,012' TVD, ADT .3 His. 7/19/2018 7/19/2018 1.00 SURFAC CEMENT DISP P Pump 36 bbl spacer & displace to new 2,041.0 2,041.0 20:15 21:15 9.4 ppg LSND w/700 - 420 gpm / 1620 - 520 psi, 50 rpm 2.5 k trq 7/1912018 7/19/2018 0.25 SURFAC CEMENT TRIP P POOH f/2,041'to 1,998' 2,041.0 1,998.0 21:15 21:30 7/19/2018 7/19/2018 0.75 SURFAC CEMENT FIT P R/U testing equipment. FIT to 18.0 1,998.0 1,998.0 21:30 22:15 ppg (890 psi w/9.45 ppg mud wt). R/D testing equipment. 7/19/2018 711912018 0.25 INTRM1 DRILL REAM P Attempt to RIH on elevators. Take wt 1,998.0 2,041.0 22:15 22:30 inside shoe. W&R f/1,998'to 2,041' 500 gpm / 900 psi, 40 rpm 12 k trq 7/19/2018 7/20/2018 1.50 INTRMI DRILL DDRL P Drill ahead f/2,041'to 2,124'MD/ 2,041.0 2,124.0 22:30 00:00 2,090' TVD, ADT .9 Hrs, ECD 9.66 ppg, 800 gpm, 1760 psi, PU wt 120 it, SO wt 115 k, ROT wt 115 k, 50 rpm, 4.512 k ft/lbs trq 7/20/2018 7/20/2018 3.75 INTRMI DRILL DDRL P Drill ahead f/2,124'to 2,475'. Pumping 2,124.0 2,475.0 00:00 03:45 nut plug sweeps mto aid in bit balling. Having issues with MWD detection. 7/20/2018 7/20/2018 1.00 INTRMI DRILL CIRC T Trouble shoot MWD w/900-800 gpm/ 2,475.0 2,475.0 03:45 04:45 1890 - 1470 psi, 120 rpm / 2 k trq 7/20/2018 7/20/2018 0.25 INTRMI DRILL DDRL P Drill ahead f/2,475'to 2,487'. MWD not 2,475.0 2,487.0 04:45 05:00 pulsing 7/20/2018 7/20/2018 1.25 INTRMI DRILL BKRM T BROOH f/2,487'to 2,215'w/900 gpm / 2,487.0 2,215.0 05:00 06:15 1710 psi, 150 rpm / 2.5 k trq. MWD started working again. Test MWD & send commands (good) 7/20/2018 7/20/2018 0.25 INTRMI DRILL TRIP T RIH f/2,215'to 2,405' 2,215.0 2,405.0 06:15 06:30 7/20/2018 7/2012018 0.25 INTRMI DRILL REAM T W&R f/2,405'to /2,487'w/900 gpm / 2,405.0 2,487.0 06:30 06:45 1900 psi, 150 rpm / 2.5 k trq. 7/20/2018 7/20/2018 5.25 INTRMI DRILL DDRL P Drill ahead f/2,487'to 2,922' MD! 2,487.0 2,922.0 06:45 12:00 2,813' TVD, ADT 6.9 Hrs, ECD 9.61 ppg, 900 gpm, 2150 psi, PU wt 127 k, SO wt 120 k, ROT wt 122 k, 150 rpm, 5/2.5 k ft/lbs trq 7/20/2018 7/21/2018 12.00 INTRMI DRILL DDRL P Drill ahead fl2,922'to 4,046' MD / 2,922.0 4,046.0 12:00 00:00 3,774' TVD, ADT 9.6 Hrs, ECD 9.76 ppg, 900 gpm, 2410 psi, PU wt 150 k, SO wt 140 k, ROT wt 140 k, 150 rpm, 7/3 k Mbs trq 7/21/2018 7/21/2018 12.00 INTRMI DRILL DDRL P Drill ahead f/4,046'to 5,300' MD / 4,046.0 5,300.0 00:00 12:00 4,503' TVD, ADT 10.0 Hrs, ECD 10.08 ppg, 900 gpm, 2450 psi, PU wt 165 k, SO wt 145 k, ROT wt 152 k, 150 rpm, 9/3.5 k ft/lbs trq 7/21/2018 7/22/2018 12.00 INTRMI DRILL DDRL P Drill ahead f/5,300'to 6,415' MD / 5,300.0 6,415.0 12:00 00:00 5,109' TVD, ADT 9.0 Hrs, ECD 10.05 ppg, 900 gpm, 2540 psi, PU wt 175 k, SO wl 150 k, ROT wt 160 k, 150 rpm, 10.5!4 k ft/Ibs trq 7122/2018 7/22/2018 12.00 INTRMI DRILL DDRL P Drill ahead f/6,415'to 7,684' MD / 6,415.0 7,684.0 00:00 12:00 5,801' TVD, ADT 10.0 His, ECD 10.42 ppg, 900 gpm, 2710 psi, PU wt 210 k, SO wt 160 k, ROT wt 180 k, 150 rpm, 1317 k ff/Ibs trq Page 5/37 Report Printed: 9/7/2018 Uperations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Start True End Time our (m) Phase Op Code Activity CMe Time P -T -X Operatmn (ftKB) End DePMtW) 7/22/2018 7/23/2018 12.00 INTRMI DRILL DDRL P Drill ahead f/7,684' to 9,008' MD / 7,684.0 9,008.0 12:00 00:00 6,520' TVD, ADT 9.5 Hrs, ECD 10.51 ppg, 900 gpm, 2850 psi, PU wt 220 k, SO wt 170 k, ROT wt 185 k, 150 rpm, 15.5/8 k ft/lbs trq 7/23/2018 7/23/2018 12.00 INTRMI DRILL DDRL P Drill ahead f/9,008' to 10,280' MD / 9,008.0 10,280.0 00:00 12:00 7,215' TVD, ADT 9.7 Hrs, ECD 10.62 ppg, 900 gpm, 3050 psi, PU wt 260 k, SO wt 175 k, ROT wt 195 k, 150 rpm, 16.5/10.5 k ft/lbs trq 7/23/2018 7/2312018 0.75 INTRMI DRILL DDRL P Drill ahead f/10,280'to TO 10,330' 10,280.0 10,330.0 12:00 12:45 MD / 7,215' TVD, ADT 9.7 Hrs, ECD 10.62 ppg, 900 gpm, 3050 psi, PU wt 260 k, SO wt 175 k, ROT wt 195 k, 150 rpm, 16.5/10.5 k ft/Ibs trq 7/23/2018 7/23/2018 5.25 INTRMI CASING CIRC P Circ hole clean for a total of 5 B/U 10,330.0 10,132-0- 12:45 18:00 w/950 gpm 13230 psi, 120 rpm / 11 k trq. Racked back 1 stand after each 2 B/U. 7/23/2018 7/23/2018 0.50 INTRMI CASING OWFF P FIC w/5 rpm 7 k trq. Slight drop of 8" 10,132.0 10,132.0 18:00 18:30 7/23/2018 7/24/2018 5.50 INTRMI CASING TRIP P POOH on elevators f/10, 132'to 6,277'. 10,132.0 6,277.0 18:30 00:00 Calc Fill 27 bbls /Act Fill 33 bbis 7/24/2018 7/24/2018 0.25 INTRMI CASING TRIP P Continue pulling out of hole on trip 6,277.0 6,082.0 00:00 00:15 tank from 6,277' MD to 6,082' MD. Correct hole fill. 7/24/2018 7/24/2018 1.00 INTRMI CASING CIRC P Planned circulation, pumped 39.5 bbl 6,082.0 5,987.0 00:15 01:15 HV NP sweep around @ 950 gpm, 3130-2820 psi, adjust rotary RPM from 80-180 as needed for shock/vibratiuon, 6.5-5.5k Tq. P/U=200k, S/0=150k, ROT=160k. Considerable cuttings returns on shakers. 7/24/2018 7/24/2018 1.25 INTRMI CASING TRIP P Continue POOH on trip tank from 5,987.0 4,662.0 01:15 02:30 5,987' MD (laying down 12-5/8" Ghost Reamer) to 4,662' MD. Start pulling tight @ 5,388' MD, wiped OK. Observe swabbing. 7/24/2018 7/24/2018 0.75 INTRMI CASING CIRC P Circulate bottoms up @ 900 gpm, 4,662.0 4,567.0 0230 03:15 2480 psi, 120 rpm, 5k Tq. No gas at bottom up. Moderate cuttings returns on shakers. 7/24/2018 7/24/2018 8.75 INTRMI CASING BKRM P Backream out of hole from 4,567' MD 4,567.0 2,140.0 03:15 12:00 to 2,140' MD @ 900-950 gpm, 2480- 2310 psi, 2k -5.5k Tq. Observe minor packing o0 and pressure torque events, slow pulling speed to 600 fph. Pumped 2 ppg over weighted sweep @ 2,750' MD while back reaming, some larger blocks up to 4" on shakers. Steady smaller cuttings returns, not sticky on shakers to -2,300'. Hole unloaded @ 2,269' MD, siltstone savings from 2" to 10" steady on all shakers for 45 minutes while backreaming stand. 7/24/2018 7/24/2018 2.50 INTRMI CASING BKRM P Continue BROOH from 2,140'to 2,140.0 1,935.0 12:00 14:30 1,935' MD, 950 gpm, 2300 psi, 120 rpm, 1-3k Tq, 7/24/2018 7/24/2018 1.00 INTRMI CASING CIRC P Circulate casing clean, pump 40 bbl 1,935.0 1,935.0 14:30 15:30 weighted nut plug sweep, followed by second sweep @ 750 gpm, 1400 psi, 100 rpm, 1-2k Tq. Page 6137 Report Printed: 91712018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start DBPM Start Time End Time our (hr) Phase Op Code ActlMy Cada Time P -T -X Operation (aKB) End Depth (ORB) 7/24/2018 7/24/2018 0.25 INTRMI CASING OWFF P Monitor well for flow, static with slight 1,935.0 1,935.0 15:30 15:45 drop in 15 min. 7/24/2018 7/24/2018 0.75 INTRMI CASING TRIP P POOH on elevators from 1,935' MD to 1,935.0 619.0 15:45 16:30 HWDP @ 619' MD. P/U=90k, correct hole fill. 7/24/2018 7/2412018 0.25 INTRMI CASING OWFF P Monitor well for flow @ HWDP, static. 619.0 619.0 16:30 16:45 SIMOPS- PJSM on L/D BHA. 7/24/2018 7/24/2018 2.25 INTRMI CASING SHAH P Rack back 4 stands HWDP with jars, 619.0 0.0 16:45 19:00 lay down remaining BHA. 7/2412018 7/24/2018 0.50 INTRMI CASING SHAH P Remove BHA Components from dg 0.0 0.0 19:00 19:30 floor, clean and clear. 7/24/2018 7/24/2018 1.00 INTRMI CASING RURD P Mobilize casing tools and equipment 0.0 0.0 19:30 20:30 to rig floor. SIMOPS- R/U Volant CRT. 7/24/2018 7/24/2018 1.50 INTRMI CASING BOPE P PJSM, change upper pipe rams from 0.0 0.0 20:30 22:00 3%" x 6" VBR to 9-5/8" SBR. SIMOPS- Continue to dg up casing equipment. 7/24/2018 7/24/2018 0.75 INTRMI CASING BOPE P Pull wear bushing and set test plug. 0.0 0.0 22:00 22:45 Observe trip nipple <t" from bottom of master bushing due rig settling. 7/24/2018 7/2412018 0.25 INTRMI CASING BOPE P Pull trip nipple. 0.0 0.0 22:45 23:00 7/24/2018 7/2412018 0.50 INTRMI CASING BOPE P Set 9-5/8" test joint, R/U and flood 0.0 0.0 23:00 23:30 stack and lines for testing. SIMOPS, cut down 4" from trip nipple. 7/24/2018 7/25/2018 0.50 INTRMI CASING BOPE P Test annular preventer with 9-5/8" test 0.0 0.0 23:30 00:00 joint to 250 psi for 5 min, 25400 psi for 10 min charted. 7/25/2018 7/25/2018 0.50 INTRMI CASING BOPE P Continue testing with 9-5/8" test joint, 0.0 0.0 00:00 00:30 Test Upper SBR's to 250 psi for 5 min, 3500 psi for 10 minutes charted. Rig down test equipment. 7/25/2018 7/25/2018 0.50 INTRMI CASING RURD P Pull test plug, set thin wall wear ring. 0.0 0.0 00:30 01:00 7/25/2018 7125/2018 0.75 INTRMI CASING RURD P Rig up to run 9-5/8" casing, verify pipe 0.0 0.0 01:00 01:45 count and centralizers / pup / hanger. 7125/2018 7/25/2018 0.25 INTRMI CASING SFTY P PJSM on running 9-5/8" casing. 0.0 0.0 01:45 02:00 7/25/2018 725/2018 7.00 INTRMI CASING PUTS P Make up shoe track, Bakedock to pin 0.0 4,087.0 02:00 09:00 of #4. Pump through shoe track and check floats, good. Continue P/U and RIH with 9-5/8" 40 # TXP-HS TN80 and TXP L80 casing to 4,067' MD per detail (103 jts in hole) Taking weight -50k. P/U=190k, S/0=170k. 7/25/2018 7/25/2018 1.50 INTRMI CASING CIRC P Circulate and condition mud, 2.5 bpm- 4,087.0 4,087.0 09:00 10:30 7 bpm, 180-230 psi. Some slight packing off. Pumped 5200 stks, (2 bottoms up) 10.1+ ppg max mud weight out. 7/25/2018 7/25/2018 1.50 INTRMI CASING PUTS P Conilnue RIH from 4,087' MD to 4,087.0 4,880.0 10:30 12:00 4,880' MD per detail. S/0= 182k. 7/25/2018 7/252018 2.00 INTRMI CASING PUTS P Continue RIH from 4,880' MD to 4,880.0 5,921.0 12:00 14:00 5,921' MD per detail. S/0= 175k. Observe loss of 25-30k SOW. 7/25/2018 7125/2018 1.00 INTRMI CASING CIRC P Break circulation @ 1 bpm, 480 psi, 5,921.0 5,99-10- 14:00 15:00 stage up to 3.5 bpm, wash down joint to 5,961' MD pumped 100 bbl. 7/25/2018 7/25/2018 2.00 INTRMI CASING PUTS P Continue RIH from 5,961' MD to 5,961.0 7,043.0 15:00 17:00 7,043' MD per detail. S/0= 175k. Observe loss of 30-35k SOW. Page 7137 ReportPrinted: 917/2018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stall Depth Start Time End Mme Dur (hr) Phase Op Code Aobviry Code Time P-T-X Opembon (W) End Depth (fiKB) 7/25/2018 7/25/2018 3.00 INTRMI CASING CIRC P Break circulation @ 1 bpm, 630 psi, 7,043.0 7,043.0 17:00 20:00 stage up to 8 bpm. Heaviest mud weight out 11.0+, circulate until mud weight 10.1+ out. Pumped 800 bbl, 1.75 bottoms up. No recordable losses during circulation. 7/25/2018 7/25/2018 3.00 INTRMI CASING PUTB P Continue RIH from 7,043' MD to 7,043.0 8,806.0 20:00 23:00 8,806' MD per detail. S/O= 150k. Observe loss of 30-35k SOW. Getting good displacement during casing run. Calculated displacement for trip=132 bbl, Actual Displacement=110 bbl. 7/25/2018 7/26/2018 1.00 INTRMI CASING CIRC P Break circulation @ 1 bpm, 880 psi, 8,806.0 8,846.0 23:00 00:00 stage up to 4 bpm, wash down joint to 8,846' MD pumped 120 bbl. No recordable losses during circulation. 7/26/2018 7/26/2018 3.50 INTRMI CASING PUTB P Continue PIU and RIH with 9-5/8" 40 # 8,846.0 10,279.0 00:00 03:30 TXP L80, pup and XO to H563 casing from 8,846' MD to 10,279' MD per detail. 254 jts in hole plus XO and pup. 7/26/2018 7/26/2018 0.75 INTRMI CASING HOSO P Make up hanger and landing joint, 10,279.0 10,317.0 03:30 04:15 wash down @.5 bpm, 980 ICP. Land hanger and stay landed. (Note, very tight tolerances through stack and thin wall wear ring, Reciprocation would be very risky) Final SOW=190k. 7/26/2018 7/26/2018 5.00 INTRMI CEMENT CIRC P Circulate and condition mud, stage up 10,317.0 10,317.0 04:15 09:15 from .5 bpm to 4.5 bpm, 980 psi to 500 psi, Stay at 4.5 bpm until first wave of heavy mud (11.5+) out of hole @ 3,600 stks. Stage up to 6 mpm until second wave of heavy mud coming out (11.7+), separated by 120 bbl clean mud pumped at 8,800' while RIH. Stage up to 8 bpm, 460 psi FCP. 10.0 ppg in, 10.1 ppg out, total 3 x bottoms up pumped. 7/26/2018 7/26/2018 1.00 INTRMI CEMENT RURD P Shut down, OWFF static. Blow down 10,317.0 10,317.0 09:15 10:15 top drive, remove mud saver valve from Volant CRT. Rig up cement hose and 1502 equipment to cement line. 7/26/2018 7/26/2018 0.50 INTRMI CEMENT CIRC P Break circulation through cement 10,317.0 10,317.0 10:15 10:45 hose, 8 bpm 650 psi. SIMOPS- PJSM on cementing 9-5/8" casing. 7/26/2018 7/26/2018 1.25 INTRM1 CEMENT CMNT P SLB flood lines with 5 bbl water. 10,317.0 10,317.0 10:45 12:00 Pressure test to 3500 psi, good. SLB pumped 58.5 bbl 12.5 ppg mud push. Shut down and drop bottom plug. Mix and pump 39 bbl 12.2 ppg Lead cement @ 3.4-4.2 bpm. Swap to tail, begin pumping 15.8 ppg tail. 7/26/2018 7/26/2018 0.50 INTRMI CEMENT CMNT P Continue pumping 15.8 ppg Tail 10,317.0 10,317.0 12:00 12:30 cement, 2.9-3.4 bpm @ 473 psi (46 bbl). Shut down, drop top plug. SLB kick out with 20 bbl water. 7/26/2018 7/26/2018 1.50 INTRMI CEMENT CMNT P Rig displace cement with 10.0 ppg 10,317.0 10,317.0 12:30 14:00 LSND @ 8 bpm, ICP=430 psi, FCP @ 8 bpm=730 psi. Slowed pump to 3 bpm, 540 psi @ 730 bbl away. Continue displacement to 7603 strokes, plug did not bump. Shut down. Page 8/37 ReportPrinted: 917/2018 Operations Summary (with Timelog Depths) 8 td♦nrt . MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Wr(hn Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (MB) 7/26/2018 7/26/2018 0.50 INTRMI CEMENT CMNT P Hold 540 psi for 10 minutes, pumped 10,317.0 10,317.0 1400 1430 final strokes to max 7607 total @ .3 bpm, 600 psi. Plug not bumped. Hold 600 psi for 10 minutes. Bleed off and check floats, Floats good. CIP @ 14:17 hrs. 7/26/2018 7/26/2018 1.00 INTRMI CEMENT RURD P Rig down Volant CRT, lay down 10,317.0 0.0 14:30 15:30 landing joint. 7/26/2018 7/26/2018 0.50 INTRMI CEMENT RURD P Pull wear bushing. 0.0 0.0 15:30 16:00 7/26/2018 7/26/2018 1.50 INTRMI CEMENT WWSP P Set 9-5/8" packoff and test to 5000 psi 0.0 0.0 16:00 17:30 for 10 minutes, CPAI witnessed - good. 7/26/2018 7/26/2018 1.50 INTRMI CEMENT TRIP T Mobilize storm packer to set due 0.0 940.0 17:30 19:00 cement top plug not bumped. SIMOPS - RI with stack washer, 3 stands 5" HWDP, 7 stands 5" DP to 940' MD. 20k hang off weight. Make up Type'L' Retrievomatic Service Packer to stump. 7/26/2018 7/26/2018 1.50 INTRMI CEMENT WAIT T Standby for delivery of Twin Thread 940.0 940.0 19:00 20:30 Safety joint and Rotational Equalization Valve from CD1, not delivered with Storm Packer. 7/26/2018 7/26/2018 0.50 INTRMI CEMENT MPSP T Make up twin thread safety joint and 940.0 0.0 20:30 21:00 equalization valve to packer, RIH with packer to 1,048' MD bullnose depth, Packer COE @ 102' MD, 82k SOW. Set packer per Baker rep with 1/4 LH turn. Set dawn to block weight. Right hand turn 13 turns to release, POOH. Top of packer stump @ 92.11' MD 7/26/2018 7/26/2018 0.50 INTRMI CEMENT PRTS T Close blind rams and test packer to 0.0 0.0 21:00 21:30 1000 psi for 5 minutes, 0.6 bbl pumped. Bleed off and rig down. 7/26/2018 7/26/2018 1.00 INTRMI CEMENT NUND P PJSM, Drain stack, pull mouse hole, 0.0 0.0 21:30 2230 pull trip nipple and Flow box for N/D. SIMOPS- Change out solenoid valves on tap drive. 7/26/2018 7/26/2018 1.00 INTRMI CEMENT NUND P N/D BOPE and tubing spool. 0.0 0.0 22:30 23:30 SIMOPS- Change out solenoid valves on top drive. 7/26/2018 7/27/2018 0.50 INTRMI CEMENT NUND P Prep for install 7" casing spool. 0.0 0.0 23:30 00:00 SIMOPS- Change out solenoid valves on top drive. 7/27/2018 7/27/2018 0.75 INTRMI CEMENT NUND P Install 7" casing spool 0.0 0.0 00:00 00:45 7/27/2018 7/27/2018 0.25 INTRMI CEMENT PRTS P FMC test upper packoff seals to 0.0 0.0 00:45 01:00 250/5000 psi for 5/10 minutes CPAI witnessed - good. 7/27/2018 7/27/2018 1.50 INTRMI CEMENT NUND P N/U BOPE to spool, torque with 0.0 0.0 01:00 02:30 1 1 1 1 1 1 Sweeny wrench. 7/27/2018 7/27/2018 1.50 INTRMI CEMENT MPDA P PJSM, R/U MPDE, Flowline, mud 0.0 0.0 02:30 0400 bucket line, Flowbox, drain lines, 1502 equipment and trip nipple. 7/27/2018 7/27/2018 0.50 INTRMI CEMENT NUND P Continue rig up in cellar, rig up Ball 0.0 0.0 04:00 04:30 mill to annulus for annular LOT, Flush and freeze protect. Page 9137 Report Printed: 917/2018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stall Depth Start Time EM Time Dur (hr) Phase Op Code Activity Code lime P-T-X Operabon (fiKB) End Depth(RKB) 7/27/2018 7/27/2018 0.50 INTRMI CEMENT SVRG P Service rig, top drive, draworks and 0.0 0.0 04:30 05:00 iron roughneck. Test new solenoids on top drive, good. SIMOPS- Perform annular LOT on 13- 3/8" x 9-5/8" annulus, 15.5 ppg EMW. Begin flush and FP, 300 bbl water and 85 bbl diesel. 7/2712018 7/27/2018 1.00 INTRMI CEMENT RURD P Obtain new RKB's, install 90' 0.0 0.0 05:00 06:00 mousehole. P/U 5" test joint, set upper test plug. Pull test joint. 7/27/2018 7/27/2018 1.00 INTRMI WHDBOP RURD P PJSM, change out Upper Pipe Rams 0.0 0.0 06:00 07:00 1 from 9-5/8" SBR to 4XV x 7" VBR. 7/27/2018 7/27/2018 1.50 INTRMI WHDBOP RURD P Rig up to test BOPE, fill slack, choke 0.0 0.0 07:00 08:30 and kill lines and choke manifold with water, purge air from system. 7/27/2018 7/27/2018 3.00 INTRMI WHDBOP BOPE P Test with 5", 4" and 7" test jts. AOGCC 0.0 0.0 08:30 11:30 Guy Cook waived, BLM Mutasim Elganzoory waived via email 7/24 09:14. Rams, annular and XT39 tests 250 psi for 5 min, 3500 psi for 10 min for BLM. All other 5/5 min. With 5" TJ test Annular Preventer, 4W x 7" upper VBR, 3%" x 6" lower VBR, Auto and manual IBOP's, NC50 FOSV, Dart, choke manifold valves #1-14, 4" Demco kill, HCR choke and kill, Manual choke and kill. 4" Test joint, test annular, XT39 Dart 250/3500 for 5/10 min. 7/27/2018 7/27/2018 0.50 INTRMI WHDBOP BOPE P Perform accumulator function test. 0.0 0.0 11:30 12:00 System pressure=3050 psi, manifold=1500 psi, Pressure after functioning all rams, annular and HCR's=1500 psi. 200 psi attained=26 sec with electric pump, Full system recovery=138 sec with 1 electric and 3 air pumps. Backup nitrogen 4 bottle average=2100 psi. 7/27/2018 7/27/2018 3.00 INTRMI WHDBOP BOPE P Continue testing with 4" TJ, 31/2'x 6" 0.0 0.0 12:00 15:00 lower VBR's, XT39 FOSV 250/3500 5/10 min. 7" test joint tested annular preventer and upper 4%" x 7" VBR's, 5/10 min. Tested blind rams 5/5 min. Tested manual and super auto choke to 1100 psi. Tested dg gas, PVT and flow alarms. 7/27/2018 7/27/2018 0.50 INTRMI WHDBOP RURD P Pull test plug, blow down and rig down 0.0 0.0 15:00 15:30 test equipment. 7/27/2018 7/27/2018 0.50 INTRMI CEMENT MPSP T PJSM, M/U Baker Type'L' 0.0 0.0 15:30 16:00 Relrievomatic service packer retrieval tool. 7/27/2018 7/27/2018 0.50 INTRMI CEMENT MPSP T RIH to 92', engage top of packer 1,048.0 940.0 16:00 16:30 stump. Open equalization valve, no pressre. Release packer and pull to surface. Lay down packer and tools. 7/27/2018 7/27/2018 1.00 INTRMI CEMENT TRIP T POOH, rack back 7 stands 5" DP, 3 940.0 0.0 16:30 17:30 stands HWDP, lay down ported bull nose, (20k setting weight pipe for storm packer) 7/27/2018 7/27/2018 0.50 INTRMI CEMENT RURD P FMC set 8.75" ID long wear bushing. 0.0 0.0 17:30 18:00 7/27/2018 7/27/2018 0.50 INTRM1 CEMENT BHAH P Clean and clear rig floor. 0.0 0.0 18:00 18:30 7/27/2018 7/27/2018 0.50 INTRMI CEMENT BHAH P PJSM on M/U 8-3/4" motor cleanout 0.0 0.0 18:30 19:00 BHA#3. Mobilize tools to rig floor. Page 10/37 Report Printed: 917/2018 Operations Summary (with Timelog Depths) (low MT6-08 .. Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Cone Time P -T -X Operation (fIKB) End Depth (flKB) 7/27/2018 7/27/2018 0.50 INTRMI CEMENT BHAH P Make up BHA #3 to 399' MD. 0.0 399.0 19:00 19:30 7/27/2018 7/2812018 4.50 INTRMI CEMENT TRIP P Trip in hole from 399' MD to 8,418' 399.0 8,418.0 19:30 00:00 MD. P/U=200k, S/0=140k. 7/28/2018 7/28/2018 1.00 INTRMI CEMENT TRIP P Trip in hole from 8,418' MD to 10,000' 8,418.0 10,000.0 00:00 01:00 MD filling pipe every 20 stands. 7/28/2018 7128/2018 1.50 INTRMI CEMENT PRTS P Rig up for casing test. Test casing to 10,000.0 10,000.0 01:00 02:30 1 1 13500 psi for 30 minutes charted, good. 7128/2018 7/28/2018 1.00 INTRMI CEMENT SLPC P Slip and cut 98' drilling line, calibrate 10,000.0 10,000.0 02:30 0330 block height. 7/28/2018 7/28/2018 0.50 INTRMI CEMENT SVRG P Service top drive, block and draworks. 10,000.0 10,000.0 03:30 0400 7/28/2018 7/28/2018 1.50 INTRM2 CEMENT COCF P Wash down w/o rotation @ 310 gpm, 10,000.0 10,230.0 04:00 05:30 800 psi tag plugs on depth @ 10,230' MD. 7/28/2018 7/28/2018 2.25 INTRMI CEMENT DRLG P Drill float collar, shoe track, shoe and 10,230.0 10,330.0 05:30 07:45 rathole from 10,230' MD to 10,330' MD, 400 gpm, 1180 psi, 40 rpm, 11- 14k Tq. Tag up on shoe on depth @ 10,315' MD. 7/28/2018 7/28/2018 0.75 INTRMI CEMENT DDRL P Drill 20' new formation from 10,330' 10,330.0 10,350.0 07:45 08:30 MD to 10,350' MD, 7,252' MD. SIMOPS- Condition mud with product and weight up to 10.8 ppg on the fly. 7/28/2018 7/28/2018 1.00 INTRMI CEMENT CIRC P Continue conditioning mud to 10.8 10,350.0 10,284.0 08:30 09:30 ppg, backream through shoe to 10,284' MD @ 650-300 gpm, 60 rpm, 14-11 k Tq. 7/28/2018 7/28/2018 1.00 INTRMI CEMENT FIT P R/U test equipment, perform FIT to 10,284.0 10,284.0 09:30 10:30 14.0 ppg EMW. 3.5 bbl pumped, 1204 psi. Bleed off, blow down and rig down. 7/28/2018 7/28/2018 0.50 INTRM2 DRILL REAM P Obtain SPR's, wash and ream down 10,284.0 10,350.0 10:30 11:00 from 10,284' MD to 10,350' MD @ 550 gpm, 2150 psi, 60 rpm, 11.5k Tq. 7/28/2018 7/28/2018 1.00 INTRM2 DRILL DDRL P Drill from 10,350' MD to 10,377' MD, 10,350.0 10,377.0 11:00 12:00 7,268' TVD. Tour ADT=1.6 hrs.P/U=210k, S/0=160k, ROT=180k, Tq on/off--10.7k/9.3k. 7/28/2018 7/28/2018 0.75 INTRM2 DRILL DDRL P Continue drilling from 10,377' MD to 10,377.0 10,408.0 12:00 12:45 10,408' MD, 7,284' TVD. ADT=1.3 hrs.P/U=215k, S/0=160k, ROT=185k, Tq on/off--11k/10k. 7/28/2018 7/28/2018 1.25 INTRM2 CSGDRL BKRM P Backream out of hole while CBU x 1.5 10,408.0 10,284.0 12:45 14:00 from 10,408' MD to 10,284' MD @ 500 gpm, 2100 psi, 60 rpm, 10-k Tq. BR across shoe x 2. P/U=225k, S/0=160k. 7/28/2018 7/28/2018 0.50 INTRM2 CSGDRL OWFF P Monitor well for flow, static. Attempt to 10,284.0 10,284.0 14:00 14:30 POOH on elevators from 10,284' MD to 10,245' MD, 20--30k overpull immediatly. RBIH to 10,284'. 7/28/2018 7128/2018 1.00 INTRM2 CSGDRL CIRC P Circulate bottoms up again x 1.5 @ 10,284.0 10,284.0 14:30 15:30 650 gpm, 2700 psi, 60- rpm, 9k Tq. Reciprocate from 10,284' MD to 10,189' MD. Observe shale cavings / returns on shakers. 7/28/2018 7/28/2018 1.50 INTRM2 CSGDRL TRIP P POOH on elevators from 10,284MD 10,284.0 9,321.0 15:30 17:00 to 9,321' MD. P/U=225k, observe good hole fill. 7/28/2018 7/28/2018 0.50 INTRM2 CSGDRL CIRC P Pump 28 bbl 12 ppg Slug. 9,321.0 9,321.0 17:00 17:30 Page 11137 Report Printed: 917/2018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log sten Depth start lime End Time our (hr) Phase Op Code Acftity Code Tima P-T-X Operation (11KB) End Depm(MS) 7/28/2018 712812018 6.00 INTRM2 CSGDRL TRIP P Continue POOH from 9,321' MD to 9,321.0 399.0 17:30 23:30 399' MD. Calc Fill=83 bbl, Actual 1`111=87 bbl. 7/28/2018 7/28/2018 0.25 INTRM2 CSGDRL OWFF P OWFF static at HWDP. 399.0 399.0 23:30 23:45 7/28/2018 7/29/2018 0.25 INTRM2 CSGDRL TRIP P Rack back HWDP and Jars to 32' MD. 399.0 32.0 23:45 00:00 7/29/2018 7/29/2018 1.00 INTRM2 CSGDRL BHAH P Lay down BHA #3 from 32' per DD. 32.0 0.0 00:00 01:00 7/29/2018 7/29/2018 0.75 INTRM2 CSGDRL BHAH P Clean and clear rig floor, lay down 0.0 0.0 01:00 01:45 excess tools. Change out elevators and mobilize BHA #4 components to rig floor. 7/29/2018 7/29/2018 3.00 INTRM2 CSGDRL BHAH P Make up stop sub, back up steering 0.0 O.0 01:45 04:45 head to backup D505T bit. Lay down same to shed. Make up primary lower BHA #4 (AutoTrak steering head, OnTrak, SDN, CoPilot, GaugePro) per DD/MWD. 7/29/2018 7/29/2018 2.75 INTRM2 CSGDRL BHAH T Troubleshoot AutoTrak/MWD. When 0.0 0.0 04:45 07:30 plugged in to ensure tools communicating, could not see the AutoTrak. Attempt different ports and configurations. BHI consult tech support, determine a programming issue, resolved and verified communication with tools. Rack back lower BHA #4 on ODS. 7129/2018 7/29/2018 1.00 INTRM2 CSGDRL RURD P P/U C-Plate, slips, job box, Rig up 7" 0.0 0.0 07:30 08:30 liner running tools. R/U torque turn equipment, M/U XO's to TIW valve(s). Mobilize Kick stand to floor, set in mouse hole. 7/29/2018 7/29/2018 3.50 INTRM2 CSGDRL PUTB P PJSM, P/U and run 7" Tanana Blue 0.0 1,228.0 08:30 12:00 liner. M/U 32# Reamer shoe and 29 joints 26# L-80 TN Blue with crimped on Hydrofonn centralizers per detail top 1,228' MD. Torque turn connections to 13,000 ft/lbs with Seal Guard ECF dope. S/0=86k 7/29/2018 7/2912018 2.00 INTRM2 CSGDRL PUTB P Continue RIH with 7" TN Blue liner 1,228.0 2,380.0 12:00 14:00 from 1,228' MD to 2,380' MD. M/U lower 7" Quick conned. P/U=11 Ok, S/0=105k. 7/29/2018 7/29/2018 1.00 INTRM2 CSGDRL RURD P Clean and clear rig floor, rig down 2,380.0 0.0 14:00 15:00 casing equipment. Lay down same from rig floor. 7/29/2018 7/29/2018 1.50 INTRM2 CSGDRL RURD P Mobilize work platform to rig floor and 0.0 133.0 15:00 16:30 set up. R/U false bowl and stand. Review kick stand drill. UD lower quick connect sub. 7/29/2018 7/29/2018 0.50 INTRM2 CSGDRL BHAH P RIH with inner BRA (previously racked 133.0 133.0 16:30 17:00 back) to 82' MD. Make up motor and BCPM to 133' MD. 7/29/2018 7/29/2018 0.50 INTRM2 CSGDRL SHAH P PJSM, Load sources. 133.0 167.0 17:00 17:30 7/29/2018 7/29/2018 1.00 INTRM2 CSGDRL BHAH P M/U smart battery sub to 167' MD. 167.0 178.0 17:30 18:30 Plug in and verify comms. Continue to make up BHAto 178' MD. 7/29/2018 7/29/2018 1.50 INTRM2 CSGDRL TRIP P RIH with BHA on 4" 14# DP from 178' 178.0 2,458.0 18:30 20:00 MD to 2,458' MD. P/U=85k, S/0=80k. Page 12137 Report Printed: 9/712018 Uperations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth Start Time Eno Time Dur (hr) Phew Op Code Activity Code Time P -T -X Opwaton (M(B) EM Dep, mKS) 7/29/2018 7/292018 0.50 INTRM2 CSGDRL HOSO P Continue RIH, No -Go out 22.5' in on 2,458.0 2,458.0 20:00 20:30 stand #25. Set down 3k. POOH and rack back stand 25. Space out per Baker reps with 12.59' pup. 7/29/2018 7/29/2018 0.50 INTRM2 CSGDRL HOSO P M/U liner running tool as per Baker 2,458.0 2,491.0 20:30 21:00 reps to 2,491' MO. RID false bowl and work platform. 7/29/2018 7/29/2018 0.50 INTRM2 CSGDRL BHAH P M/U flow diverter, string stabilizer and 2,491.0 2,514.0 21:00 21:30 1 1 flapper float to 2,514'MD, 7/29/2018 7/2912018 0.50 INTRM2 CSGDRL TRIP P RIH 2 stands to 2,700' MD. 2,514.0 2,700.0 21:30 22:00 7/2912018 7/29/2018 0.50 INTRM2 CSGDRL DHEO P Shallow test MWD @ 250 gpm, 1850 2,700.0 2,700.0 22:00 22:30 psi -good. 7/29/2018 7/29/2018 0.50 INTRM2 CSGDRL TRIP P Trip in hole on 5" DP from 2,700' MD 2,700.0 3,642.0 22:30 23:00 to 3,642' MD. S/0=1 50k. Calc disp=43 bbl, Actual 31 bbl. 7/29/2018 7292018 0.50 INTRM2 CSGDRL SVRG P Lubricate rig, service roughneck, 3,642.0 3,642.0 23:00 23:30 drawworks. 7/29/2018 7/302018 0.50 INTRM2 CSGDRL RGRP T Troubleshoot drawworks, noise 36,425.0 3,642.0 23:30 00:00 Coming from electric brake outer bearing. 7/30/2018 7/30/2018 0.50 INTRM2 CSGDRL RGRP T Troubleshoot drawworks, noise 3,642.0 3,642.0 00:00 00:30 coming from electric brake outer bearing. 7/30/2018 7/30/2018 7.00 INTRM2 CSGDRL TRIP P Continue RIH with BHA #4 to shoe, 3,642.0 10,043.0 00:30 07:30 from 3,7642' MD to 10,043' MD, fill pipe every 20 stands. Observe mud pushing away slightly @ 3000 fph, slowed to 2000 fph and get correct displacement. SIMOPS- Mobilize crane and crew from CD1, rebuilt brake delivered from CD5. 7/30/2018 7/30/2018 4.50 INTRM2 CSGDRL RGRP T Stab safety valve, line up hole fill on 10,043.0 10,043.0 07:30 12:00 well to monitor. PJSM, Change out Baylor Dynamatic electric brake. 7/30/2018 7130/2018 7.50 INTRM2 CSGDRL RGRP T Continue changing out electric brake. 10,043.0 10,043.0 12:00 19:30 SIMOPS- lay down 5" HWDP and Jars from DS. Monitor well with trip tank, 0 bbl gainlloss 7/3012018 7/302018 0.50 INTRM2 CSGDRL MPDA P PJSM, pull trip nipple and install RCD. 10,043.0 10,043.0 19:30 20:00 7/30/2018 7/30/2018 0.25 INTRM2 CSGDRL MPDA P Break in bearing rotating 50 rpm, 12k 10,043.0 10,043.0 20:00 20:15 Tel, pumping 2 bpm 750 psi. 7/30/2018 7/30/2018 0.75 INTRM2 CSGDRL TRIP P Trip in hole from 10,043' MD to 10,043.0 10,232.0 20:15 21:00 10,232' MD. P/U=260k, S10=180k. 7/30/2018 7/30/2018 1.00 INTRM2 CSGDRL REAM P Wash and ream from 10,232' MD to 10,232.0 10,408.0 21:00 22:00 bottom 10,408' MD @ 200 gpm, 1700 psi, 40 rpm, 1 Ok Tq. Reduce rotary to 20 rpm, and RIH @ 20 fph as reamer shoe passes by float collar and float shoe. No tq or drag observed. 7/30/2018 7/30/2018 0.50 INTRM2 CSGDRL DCSG P Drill from 10,408' MD to 10,414' MD @ 10,408.0 10,414.0 22:00 22:30 200 gpm, 1700 psi, 40 rpm, 13k Tq. 2- 4k WOB. Downlink to activate flow diverter. 7/302018 7/31/2018 1.50 INTRM2 CSGDRL DCSG P Drill ahead from 10,414' MD to 10,468' 10,414.0 10,468.0 22:30 00:00 MD, 7,318' TVD. ADT=1.2 hrs, P/U=260k, S/0=180k, ROT=210k, Tq on/off=13k/11k. 600 gpm, 2500 psi, ECD= 11.5 ppg EMW. Page 13/37 Report Printed: 917/2018 Gperations Summary (with Timelog Depths) MT6-O8 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start DepN start Time End Time Our (hr) Phase Op Code Mvrty Code Time P -T-% Opersdon (ftKB) End Depth (MB) 7/31/2018 7/31/2018 12.00 INTRM2 CSGDRL DCSG P Drill ahead from 10,468'to 10,892' 10,466.0 10,892.0 00:00 12:00 MD / 7,549' TVD. ADT=10.8 hrs, P/U=N/A, S/O= N/A, ROT=205 k, Tq on/off--12k/9k. 650 gpm, 2990 psi, ECD= 11.73 ppg EMW. 7/31/2018 7/3112018 11.75 INTRM2 CSGDRL DCSG P Drill ahead from 10,892'to 11,537' 10,892.0 11,537.0 12:00 23:45 MD / 7,830' TVD. ADT=10.5 hrs, P/U=N/A, S10= NIA, ROT=215 k, Tq on/off=l6k/10k. 650 gpm, 3200 psi, ECD= 11.83 ppg EMW. (Rotary stall 11,530') 7/31/2018 811/2018 0.25 INTRM2 CSGDRL DHEQ T Trouble shoot communication with 11,537.0 11,537.0 23:45 00:00 directional tools & stand pipe pressure loss. 8/1/2018 8/1/2018 1.75 INTRM2 CSGDRL DHEQ T Trouble shoot communication with 11,537.0 11,537.0 00:00 01:45 directional tools. Test surface equipment to 3500 psi & confnn issue is down hole. Close flow diverter & Continue to trouble shoot. 8/1/2018 8/1/2018 0.25 INTRM2 CSGDRL DCSG T Drill ahead with no communication in 11,537.0 11,546.0 01:45 0200 attempt to gain communication with flow diverter closed f/11,537'to 11,546' 8/1/2018 8/1/2018 0.50 INTRM2 CSGDRL DHEQ T Trouble shoot communication with 11,546.0 11,546.0 02:00 02:30 directional tools. No success 8/1/2018 8/1/2018 0.25 INTRM2 CSGDRL DCSG T Drill ahead with no communication in 11,546.0 11,550.0 02:30 0245 attempt to gain communication with flow diverter closed (/11,546' to 11,550. Confirm reamer closed & stack wt of reamer shoe on 6" open hole ledge. 8/1/2018 8/1/2018 0.25 INTRM2 CSGDRL DHEQ T Trouble shoot communication with 11,550.0 11,550.0 02:45 03:00 directional tools. No success. Decision made to make preparations to POOH. 8/1/2018 8/1/2018 6.25 INTRM2 CSGDRL CIRC T Wt up from 10.3 ppg to 11.1 ppg in .2 11,550.0 11,550.0 03:00 09:15 -.3 ppg increments. Initial 650 gpm / 2350 psi. Final 350 gpm / 1070 psi P/U wt 245k&SO wt 185k 8/1/2018 8/1/2018 1.25 INTRM2 CSGDRL CIRC T Drop ball & attempt to release from 11,550.0 11,550.0 09:15 10:30 liner w/2 bpm 1710 psi. Ball on seat 447 stks. Pressure up to 2080 psi & unable to release from liner. Fluid leaking thru flow diverter. Apply 200 psi on back side, Pressure up to 3910 psi & blow ball off seat. Pu/u string & released from liner. (Reamer shoe 111,469'& TOL 9,065') PU wt 225 k 8/1/2018 8/1/2018 3.00 INTRM2 CSGDRL SMPD T Strip OOH as per MPD schedule 11,550.0 9,006.0 10:30 13:30 f/11,550' to 9006' 8/1/2018 8/1/2018 0.50 INTRM2 CSGDRL OWFF T FIC (static 9,006.0 9,006.0 13:30 14:00 8/1/2018 8/112018 4.00 INTRM2 CSGDRL SMPD T Strip OOH as per MPD schedule 9,006.0 2,605.0 14:00 18:00 f/9006' to 2,605 8/1/2018 811/2018 0.25 INTRM2 CSGDRL OWFF T F/C (static - PJSM on pulling RCD 2,605.0 2,605.0 18:00 18:15 bearing 8/1/2018 8/1/2018 0.50 INTRM2 CSGDRL MPDA T Pull RCD bearing & install trip nipple. 2,605.0 2,605.0 18:15 18:45 8/1/2018 8/1/2018 1.25 INTRM2 CSGDRL BHAH T Rack back 1 stand 5" DP. UD flow 2,605.0 2,458.0 18:45 20:00 diverter & Baker liner quick connect to 2,458'. Observe flow diverter nozzle washed out. 8/1/2018 8/1/2018 2.00 INTRM2 CSGDRL TRIP T POOH racking back 4" DP f/2458'to 2,458.0 178.0 20:00 22:00 178' Page 14/37 Report Printed: 91712018 Uperations Summary (with Timelog Depths) MT6-08 Qg: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Star) Time ErtlTmne our (hr) Phase Op Code muVily Cotle Time P -T -x Operation (ftKB) End Depth (11KB) 8/1/2018 8/2/2018 2.00 INTRM2 CSGDRL BHAH T UD BHA as per Baker reps. to 116'. 178.0 116.0 22:00 00:00 (plug in smart battery, Remove sources) 8/212018 8!2/2018 0.75 INTRM2 CSGDRL BHAH T UD BHA #4 as per Baker reps. f/116'. 116.0 0.0 00:00 00:45 8/2/2018 8/2/2018 4.00 INTRM2 CSGDRL SHAH T M/U BHA#5 as per Baker reps. (Load 0.0 175.0 00:45 04:45 sources) 8/2/2018 8/2/2018 2.00 INTRM2 CSGDRL TRIP T RIH f/175'to 2,456' 175.0 2,456.0 04:45 06:45 8/2/2018 802018 1.25 INTRM2 CSGDRL SHAH T WU 10'space out pup, liner running 2,456.0 2,510.0 06:45 08:00 tools & Bow diverter to 2,510' 8/212018 8/2/2018 0.75 INTRM2 CSGDRL DHEQ T Shallow hole test MWD tools w/250 2,510.0 2,510.0 08:00 0845 gpm / 1580 psi. (good) 8/2/2018 8/2/2018 4.50 INTRM2 CSGDRL TRIP T RIH 1/2,510' l0 8,815' 2,510.0 8,815.0 08:45 13:15 8/2/2018 8/2/2018 0.75 INTRM2 CSGDRL MPDA T Pull trip nipple & install RCD bearing. 8,815.0 8,815.0 13:15 14:00 Break in bearing w/2 bpm / 630 psi, 20 rpm / 1 k trq 8/212018 812/2018 3.50 INTRM2 CSGDRL TRIP T RIH fl8,815'to 11,546' P/U wt 225 k! 8,815.0 11,546.0 14:00 1730 SO wt 165 k 8/2/2018 8/2/2018 0.50 INTRM2 CSGDRL TRIP T RIH f/11,546'to 11,548'& set down 11,546.0 11,548.0 17:30 18:00 w/20 k WOB & latch up to liner. P/U to 250 k & confirm latched up. Attempt to rotate string with no success. 8/2/2018 8/2/2018 0.25 INTRM2 CSGDRL CIRC T Attempt to circ with reamer shoe on 11,548.0 11,535.0 18:00 18:15 ledge & pressure up to 1000 psi. No returns. P/u to 305K & observe string move up hole 16to 11,535' 8/2/2018 8/212018 3.25 INTRM2 CSGDRL CIRC T Break circ w/full returns & stage Bow 11,535.0 11,535.0 18:15 21:30 rate up to 5 bpm / 1850 psi. Reduce mud wt from 11.1 ppg to 10.5 ppg. At 21:30 hrs attempt to reciprocate pipe & instant pack off. 8/2/2018 8/3/2018 2.50 INTRM2 CSGDRL OTHR T Appy back pressure & try to work liner 11,535.0 11,515.0 21:30 00:00 & pack off free. Attempt to regain circulation with no success. Max P/U wt 450 k & S/0 wt to 100 k. It appears liner moved up the hole to 11,515'. Not able to re -gain circulation & liner will not move up or down. Liner stuck at 11,434' / TOL 9,030' 8/3/2018 8/3/2018 0.75 INTRM2 CSGDRL OTHR T Cont. to attempt to re -gain circulation 11,515.0 11,515.0 00:00 0045 & work liner free. Max P/U wt 500 k. No success. Decision made to release from liner 8/3/2018 8/3/2018 1.25 INTRM2 PLUG OTHR T Drop 1.75" ball & let fall for 45 min. 11,515.0 11,515.0 00:45 02:00 Pressure up to 4200 psi to release from liner. Ball did not blow seat. Bleed off pressure. Pressure back up to 4020 psi & ball blow seat. P/U with 225 k & confirm released from liner. Liner shoe estimate -11,434'/ TOL 9,030' 8/3/2018 8/3/2018 0.50 INTRM2 PLUG PMPO T Pump out of hole f/11,515' l0 inside 7" 11,515.0 11,420.0 02:00 02:30 j liner@11,420' 8/3/2018 8/3/2018 2.00 INTRM2 PLUG CIRC T Circ & cond mud to 10.5 ppg. 11,420.0 11,420.0 02:30 04:30 8/312018 8/3/2018 2.25 INTRM2 PLUG OWFF T F/C (slight ooze) Formation appears to 11,420.0 11,420.0 04:30 06:45 be charged up from trying to establish circulation after pack off. 8/3/2018 8/3/2018 0.25 INTRM2 PLUG SMPD T Strip OOH f/11,420'to 11,357' as per 11,420.0 11,357.0 06:45 07:00 MPD schedule Page 15137 Report Printed: 91712018 Uperations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Soo Depth Start Time End Time Our (no Phase Op Code Activity Code Time P-T-X Operation (ftKB) EM Depth(nKB) 8/3/2018 8/3/2018 0.25 INTRM2 PLUG OWFF T F/C (slight ooze). PJSM on slip & cut 11,357.0 11,357.0 07:00 07:15 8/3/2018 8/3/2018 1.00 INTRM2 PLUG SLPC T Slip & cut drill line while FIC (slight 11,357.0 11,357.0 07:15 08:15 ooze). 8/3/2018 8/3/2018 0.50 INTRM2 PLUG SVRG T Service rig. 11,357.0 11,357.0 08:15 08:45 8/3/2018 8/3/2018 2.75 INTRM2 PLUG CIRC T Wt up to 10.8 ppg 11,357.0 11,357.0 08:45 11:30 8/3/2018 8/3/2018 1.50 INTRM2 PLUG OWFF T FIC (slight ooze). Appears to be 11,357.0 11,357.0 11:30 13:00 slowing down 8/3/2018 8/3/2018 2.50 INTRM2 PLUG SMPD T Strip OOH f/11,357' to 9,002' as per 11,357.0 9,002.0 13:00 15:30 MPD schedule 8/3/2018 8/3/2018 0.50 INTRM2 PLUG OWFF T F/C (slight ooze & slowing down) 9,002.0 9,002.0 15:30 16:00 8/3/2018 8/3/2018 4.75 INTRM2 PLUG SMPD T Strip OOH f/9,002'to 2,510' as per 9,002.0 2,510.0 16:00 20:45 MPD schedule 8/312018 8/3/2018 0.50 INTRM2 PLUG OWFF T F/C (static) 2,510.0 2,510.0 20:45 21:15 8/3/2018 8/3/2018 0.50 INTRM2 PLUG MPDA T Pull RCD bearing & install trip nipple 2,510.0 2,510.0 21:15 21:45 8/3/2018 8/3/2018 0.50 INTRM2 PLUG SHAH T L/D flow diverter & liner running tools 2,510.0 2,456.0 21:45 2215 f/2,510' to 2,456- 8/3/2018 8/4/2018 1.75 INTRM2 PLUG TRIP T POOH f/2,456' to 171' 2,456.0 171.0 22:15 0000 8/412018 8/4/2018 0.75 INTRM2 PLUG CLEN T Clean & Gear floor from wet trip. 171.0 171.0 00:00 00:45 814/2018 8/412018 2.00 INTRM2 PLUG BHAH T L/D BHA#5 as per Baker reps. (PJSM 171.0 0.0 00:45 02:45 & remove sources) 8/4/2018 8/412018 1.00 INTRM2 PLUG BHAH T Clean & clear floor of BHA tools & 0.0 0.0 02:45 03:45 equipment 8/4/2018 8/4/2018 0.50 INTRM2 PLUG BHAH T M/U CIBP as per Baker reps to 12' 0.0 12.0 03:45 04:15 8/4/2018 8142018 1.25 INTRM2 PLUG TRIP T RIH f/12'to 2,292' 12.0 2,292.0 04:15 05:30 8/4/2018 8/412018 0.50 INTRM2 PLUG CIRC T Fill pipe & break circ w/2 bpm / 100 psi 2,292.0 2,292.0 05:30 06:00 8/42018 814/2018 7.25 INTRM2 PLUG TRIP T RIH f/2,292'to 10,542 2,292.0 10,542.0 06:00 13:15 8/412018 8/4/2018 0.25 INTRM2 PLUG MPSP T Set CIBP @ 10,542' as per Baker rep. 10,542.0 10,542.0 13:15 13:30 8/4/2018 8/4/2018 1.50 INTRM2 PLUG CIRC T Circ B/U w/300 gpm / 800 - 670 psi 10,542.0 10,542.0 13:30 15:00 8/4/2018 8/4/2018 0.25 INTRM2 PLUG OWFF T F/C (static) 10,542.0 10,542.0 15:00 15:15 8/4/2018 8/4/2018 0.50 INTRM2 PLUG MPDA T Pull trip nipple & install RCD bearing 10,542.0 10,542.0 15:15 15:45 8/4/2018 8/4/2018 6.50 INTRM2 PLUG SMPD T Strip OOH f/10,542' to 2,292' as per 10,542.0 2,292.0 15:45 22:15 MPD schedule 8/4/2018 8/4/2018 0.25 INTRM2 PLUG OWFF T F/C (static) 2,292.0 2,292.0 22:15 22:30 8142018 8/4/2018 0.50 INTRM2 PLUG MPDA T Pull RCD bearing & install trip niple. 2,292.0 2,292.0 22:30 23:00 8/42018 8/512018 1.00 INTRM2 PLUG TRIP T C/O handling equipment to 4". POOH 2,292.0 1,728.0 23:00 00:00 f/2,292'to 1,728' 8/5/2018 815/2018 1.50 INTRM2 PLUG TRIP T POOH f/1,728'to 12' 1,728.0 12.0 00:00 01:30 8/5/2018 8/5/2018 0.25 INTRM2 PLUG BHAH T L/D retainer running tools. 12.0 0.0 01:30 0145 8/5/2018 8/5/2018 0.50 INTRM2 PLUG CLEN T Clean floor from wet trip 0.0 0.0 01:45 02:15 I Page 16137 Report Printed: 91712018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time our (no Phase Op Coe Activity Code Time P -T -X Operaum (KKS) EDW Depth (flKS) 8/5/2018 81512018 0.75 INTRM2 PLUG BHAH T Mobilize BHA components to rig floor 0.0 0.0 02:15 03:00 8/5/2018 815/2018 0.50 INTRM2 PLUG BHAH T M/U MSC BHA as per Baker reps. 0.0 12.0 03:00 03:30 8/512018 8/5/2018 0.75 INTRM2 PLUG TRIP T RIH f/12'to 1,470' 12.0 1,470.0 03:30 04:15 8/5/2018 8/5/2018 1.00 INTRM2 PLUG BHAH T M/U HRD liner running tools as per 1,470.0 1,491.0 04:15 0515 1 1 Baker reps. 8/5/2018 8/5/2018 6.50 INTRM2 PLUG TRIP T RIH f/1,491'to 8,737' 1,491.0 8,737.0 05:15 11:45 8/5/2018 8/512018 0.25 INTRM2 PLUG MPDA T Remove trip nipple & install RCD 8,737.0 8,737.0 11:45 12:00 bearing 8/5/2018 8/5/2018 2.25 INTRM2 PLUG TRIP T RIH f/8,737'to 10,469' 8,737.0 10,469.0 12:00 14:15 8/5/2018 8/5/2018 2.50 INTRM2 PLUG CPBO T Set cutter on depth @ 10,469'& cut 10,469.0 10,525.0 14:15 16:45 casing as per baker rep. Stage pumps up to 6.5 bpm / 1850 psi. Rotate w/100 rpm / 7-8 k trq. Did not see indication of pressure loss when cut was made. Set down 5 k & confirm cut was made. Shut down pumps & bleed off psi. P/U wt 208 k / SO wt 170 k. S/O to 10,525'& latch into liner. Apply right hand rotation & observe torque increase & confirm latched up. 8/5/2018 8/5/2018 1.50 INTRM2 PLUG SMPD T Strip OOH f/10,525'to 10,275' (max 10,525.0 10,275.0 16:45 18:15 P/U wl 290 k, & average P/U wt 240 - 225 k) 8/5/2018 8/5/2018 4.50 INTRM2 PLUG CIRC T Break circ & stage flow rate up to 5 10,275.0 10,275.0 18:15 22:45 bpm / 730 psi. Circ & cond mud to 10.8 ppg In/Out 8/5/2018 8/5/2018 0.50 INTRM2 PLUG OWFF T F/C (static) 10,275.0 10,275.0 22:45 23:15 8/5/2018 8/5/2018 0.25 INTRM2 PLUG CIRC T Pump 30 bbl dry job 10,275.0 10,275.0 23:15 23:30 8/512018 8/6/2018 0.50 INTRM2 PLUG SMPD T Strip OOH f110,275' to 10,002 10,275.0 10,002.0 23:30 00:00 8/6/2018 8/6/2018 7.50 INTRM2 PLUG SMPD T Strip OOH f/10,002 to 1,491' 10,002.0 1,491.0 00:00 07:30 8/6/2018 8/6/2018 0.25 INTRM2 PLUG OWFF T FIC (static) 1,491.0 1,491.0 07:30 07:45 8/6/2018 8/6/2018 0.50 INTRM2 PLUG MPDA T Pull RCD bearing & install trip nipple. 1,491.0 1,491.0 07:45 08:15 8/6/2018 8/6/2018 1.00 INTRM2 PLUG RURD T M/U C Plate, false rotary table & long 1,491.0 1,491.0 08:15 09:15 kick stand. 8/6/2018 8/6/2018 0.50 INTRM2 PLUG BHAH T UD HRDE liner running tools. 1,491.0 1,470.0 09:15 09:45 8/6/2018 8/6/2018 2.00 INTRM2 PLUG TRIP T POOH w/4" DP inner string f/1,470'to 1,470.0 12.0 09:45 11:45 12' 8/6/2018 8/6/2018 0.25 INTRM2 PLUG BHAH T UD MSC easy as per Baker reps. 12.0 0.0 11:45 12:00 8/6/2018 816/2018 1.50 INTRM2 PLUG RURD T RID false rotary table. R/U casing 0.0 0.0 12:00 13:30 running tools & equipment. 8/6/2018 8/6/2018 3.75 INTRM2 PLUG PULD T UD lower quick connect, & POOH 1,439.0 0.0 13:30 17:15 laying down 7" SDL. H1439'to surface. (35 its & 6' cut oft) 8/6/2018 8/6/2018 --[7m2 PLUG RURD T C/O upper rams to 3-1/2" X 6" VBR's. 0.0 0.0 17:15 19:45 R/U to test BOPE. SIMOPS - clean & clear floor of casing tools & equipment. Page 17/37 Report Printed: 917/2018 operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Cepm Start Time End Time our(hp Phase op Code Activity Code Time P -T -X Operation (RKB) End Depth(flK6) 8/6/2018 8/6/2018 2.00 INTRM2 PLUG BOPE T Test BOPE w/3-1/2" & 5" test joints. 0.0 0.0 1945 21:45 Annular 250 for 5 min / 2500 psi 10 min. Upper/Lower rams 250 for 5 min / 3500 psi 10 min. 8/6/2018 8/6/2018 0.50 INTRM2 PLUG BOPE T R/D testing equip. Pull lest plug & set 0.0 0.0 21:45 22:15 WR 8/6/2018 8/612018 0.50 INTRM2 PLUG RURD T R/U tubing equipment, power tongs & 0.0 0.0 22:15 22:45 slips/elevators. 8/6/2018 8/7/2018 1.25 INTRM2 PLUG PUTB T PIU 3-1/2" tubing cement stinger assy 0.0 521.0 22:45 00:00 to 521' 8/7/2018 8/7/2018 0.75 INTRM2 PLUG PUTB T P/U 3-1/2" tubing cement stinger assy 521.0 1,027.0 00:00 00:45 f/521'to 1,027'. 8/7/2018 8/7/2018 6.25 INTRM2 PLUG TRIP T RIH f/1,027'to 10,252' 1,027.0 10,252.0 00:45 07:00 8/7/2018 8/7/2018 3.25 INTRM2 PLUG WASH T Wash down w/10 bpm / 930 psi & tag 10,252.0 10,534.0 07:00 10:15 cement retainer on depth @ 10,542'. Pick up to tool joint @ 10,534'. PU wt 210 k / SO wt 167 k. (it appeared that tubing collars were making contact every 30' with something inside the shoe track) 8/7/2018 8/7/2018 0.50 INTRM2 PLUG CIRC T R/U head pin & cement hoses. Break 10,534.0 10,534.0 10:15 10:45 circ & stage to 6 bpm / 600 psi. PJSM on cementing. 817/2018 8/7/2018 1.50 INTRM2 PLUG CMNT T Dowell flood lines w/2 bbls of H2O & 10,534.0 10,534.0 10:45 12:15 PT to 3500 psi (good). Dowell pump 30.5 bbls 12.5 ppg Mud push, 41.8 bbls 17.0 ppg 1.0 fl3/sX yield Class G cement, 9.7 bbls 12.5 ppg Mud push & clear lines w/1.7 bbls H2O w/5 bpm / 300 psi. Rig displace w/145 bbls 10.8 ppg LSND w/6 bpm 1120 - 620 psi. Slow down to 2 bpm / 360 psi for last 10 bbls. (155 bbls total) 8/7/2018 8/7/2018 0.50 INTRM2 PLUG TRIP T L/D cement hose. POOH f/10,534'to 10,534.0 10,218.0 12:15 12:45 10,218' 8/7/2018 8!7/2018 2.25 INTRM2 PLUG CIRC T Load DP w/nert ball. Pump 20 bbls 10,534.0 10,218.0 12:45 15:00 H2O, chase with 10.8 ppg LSND & circ dean w/8 bpm / 850 - 630 psi (Dumped 208 bbls cement oontraminated mud, cement & mud push) 8/7/2018 8/7/2018 0.25 INTRM2 PLUG OWFF T F/C (static) 10,218.0 10,218.0 15:00 15:15 8/7/2018 8/7/2018 0.50 INTRM2 PLUG TRIP T POOH f/10,218'to 9,783' 10,218.0 9,783.0 15:15 15:45 877/2018 8/7/2018 1.00 INTRM2 PLUG SLPC T Slip & out 68' drill line. SIMOPS- 10,218.0 9,783.0 15:45 16:45 clean under shakers. 8/7/2018 8/7/2018 0.75 INTRM2 PLUG TRIP T Service dg, top drive & draw works. 10,218.0 9,783.0 16:45 17:30 8/7/2018 8/7/2018 5.50 INTRM2 PLUG TRIP T POOH f/9,783' to 3,846'. Checking for 9,783.0 3,846.0 17:30 23:00 cement rings. Observe a significant amount of cement rings on stand #33. Decision made to pump dry job & check every connection. SIMOPS - repair iron roughneck. 8/7/2018 8/7/2018 0.50 INTRM2 PLUG CIRC T Pump 32 bbls 12.9 ppg dry job. 3,846.0 3,846.0 23:00 23:30 8/7/2018 8/8/2018 0.50 INTRM2 PLUG TRIP T POOH f/3,846'to 3,658'. Checking 3,846.0 3,658.0 23:30 00:00 each connection for cement rings. 8/8/2018 8/8/2018 4.50 INTRM2 PLUG TRIP T POOH f/3,658'to 1,027' Checking 3,658.0 1,027.0 00:00 04:30 each connection for cement rings. Page 18137 Report Printed: 91712018 Operations Summary (with Timelog Depths) . MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth(RKB) 8/812018 8/8/2018 0.75 INTRM2 PLUG RURD T C/O handling equipment. R1U tubing 1,027.0 1,027.0 04:30 05:15 power tongs. 8/8/2018 818/2018 3.00 INTRM2 PLUG PULD T POOH & UD 32 jts 3-1/2" tubing & 1,027.0 0.0 05:15 08:15 stinger. 8/8/2018 8/8/2018 1.00 INTRM2 PLUG RURD T R/D tubing running equipment. Clean 0.0 0.0 08:15 09:15 & clear floor. Drain BOPE stack. 8/812018 8/8/2018 0.50 INTRM2 PLUG W W WH T M/U stack washer & flush stack. B/D 0.0 0.0 09:15 09:45 1 1 1 lines 8/812018 8/8/2018 2.50 INTRM2 WHDBOP RURD T C/O upper rams to 4-1/2" X 7" VBR's. 0.0 0.0 09:45 12:15 Retrieve wear ring & install test plug. Fill stack & flood lines w/H20. R/U to test BOPE. 8/8/2018 8/8/2018 3.25 INTRM2 WHDBOP BOPE T Test BOPE w/5" lest jt. Upper 4-1/2" X 0.0 0.0 1215 15:30 7" VBR's, choke valves #1 - 14, Auto/Man IBOP, HCR choke/kill, 4" Demco, 5" Dart & FOSV to 250 psi for 5 min & 3500 psi for 10 min. Test gas alarms 8/8/2018 8/812018 2.00 INTRM2 WHDBOP RGRP T Attempt to test lower pipe rams. 0.0 0.0 15:30 17:30 Hydraulic hose blew from Koomy to lower pipe rams. 40 gallon hydraulic oil spill (35 gal in containment 15 gal on gravel pad ). Clean up spill, C/O hose & re -fill Koomy 8/8/2018 8/8/2018 4.00 INTRM2 WHDBOP BOPE T Cont. Test HOPE. Lower 3-1/2" X 6" 0.0 0.0 1730 21:30 VBR's & annular, & blind rams to 250 psi for 5 min & 3500 psi for 10 min. Accumulator test, Initial 3200 psi, final 1450 psi, 1st 200 psi recharge = 23 sec's, full recharge = 152 second. 4 bottles @ 2150 psi. Draw down on chokes U1100 psi. AOGCC Adam Earl witness, BLM Quinn Sawyer waive witness test. (F/P on lower pipe rams, blown hydraulic hose) 818/2018 8/8/2018 0.50 INTRM2 WHDBOP RURD T RID testing equipment & B/D lines. 0.0 0.0 21:30 22:00 Pull test plug. Set 8.75" wear ring 8/8/2018 8/8/2018 1.00 INTRM2 PLUG BHAH T Bring BHA components to rig floor. 0.0 0.0 22:00 23:00 8/8/2018 819/2018 1.00 INTRM2 PLUG BHAH T PJSM. M/U mud motor kick off BHA #9 0.0 74.0 23:00 00:00 as per Baker reps to 74' 8/9/2018 8/9/2018 2.00 INTRM2 PLUG BHAH T Cont. M/U mud motor kickoff BHA#9 74.0 512.0 00:00 02:00 as per Baker reps 1/74' to 512' 8/9/2018 8/9/2018 1.00 INTRM2 PLUG TRIP T RIH f/512' to 2,392' 512.0 2,392.0 02:00 0300 8/912018 8/9/2018 0.50 INTRM2 PLUG DHEQ T Shallow hole lest mwd tools w/400 2,392.0 2,392.0 03:00 03:30 gpm 11000 psi 8/92018 8/9/2018 6.25 INTRM2 PLUG TRIP T RIH f/2,392'to 10,207' (check 2,392.0 10,207.0 03:30 09:45 connections for cement rings) 8/9/2018 8/9/2018 0.25 INTRM2 PLUG REAM T W&R w/80 gpm / 570 psi & tag TOC 10,207.0 10,221.0 09:45 10:00 (03 10,221' 8/9/2018 819/2018 1.25 INTRM2 PLUG DRLG T Drill cement f/10,221' to 10,328'w/500 10,221.0 10,328.0 10:00 11:15 gpm, 2420 psi, 40 rpm, 9.5 k trq 8/92018 8/912018 6.25 INTRM2 DRILL DDRL T Drill ahead & get kicked off f/10,328'to 10,328.0 10,491.0 11:15 17:30 TD of 10,491' MD / 7,335' TVD, ADT 5.0 Hrs, ECD 11.68 ppg, 500 gpm, 2310 psi, PU wt 225 k, SO wt 175 k, ROT wt 200 k, 40 rpm, Trq 9.5 / 8 f fUlba (7.5'separation from PBl) 8/92018 819/2018 2.00 INTRM2 CSGDRL DISP T Displace to new 10.8 ppg LSND w/500 10,491.0 10,491.0 17:30 19:30 - 250 gpm / 2500 - 840 psi (Vac trucks had a hard time keeping up off-loading fluid so flow rate was reduced) Page 19/37 Report Printed: 9/7/2018 Operations Summary (with Timelog Depths) f- MTS -08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth StartTime End Time Dur (hr) phase Op Cod. Activity Code Time P -T -X Operonon (ftKB) End Depth(ftKB) 8/9/2018 8/10/2018 4.50 INTRM2 CSGDRL BKRM T BROOH f/10,491'to 9,020'w/500 - 10,491.0 9,020.0 1930 0000 575 gpm / 2200 - 2600 psi, 40 rpm 7 - 9 k trq. Hole trying to pack off, took a significant amount of time trying to work BHA into the shoe, with hole un- loading significant's amount of shale. Cont. to back ream in casing trying to clean hole. Pump hi -vis weighted sweep at 9550' 8/10/2018 8/10/2018 0.75 INTRM2 CSGDRL BKRM T Circ out sweep w/575 gpm, 2550 psi, 9,020.0 8,923.0 00:00 00:45 40 rpm, 6K to, w/ rot and recip f/ 9082' to 9052', BROOH f/ 9020' to 8923' 8/10/2018 8/10/2018 0.25 INTRM2 CSGDRL OWFF T Observe well for flow, static. SI MOPS- 8,923.0 8,923.0 00:45 01:00 PJSM on installing RCD 8/10/2018 8/10/2018 0.25 INTRM2 CSGDRL MPDA T Remove trip nipple, install RCD 8,923.0 8,923.0 01:00 01:15 bearing, line up to strip OOH 8/10/2018 8/10/2018 4.75 INTRM2 CSGDRL SMPD T Strip OOH f/ 8923'to 603' per strip 8,923.0 603.0 01:15 06:00 schedule. Holding 200-190/120 psi ouUm slips 8/10/2018 8/10/2018 0.25 INTRM2 CSGDRL OWFF T Observe well for flow, static. SIMOPS- 603.0 603.0 06:00 06:15 PJSM on installing trip nipple 8/10/2018 8/10/2018 0.50 INTRM2 CSGDRL MPDA T Remove RCD bearing, install trip 603.0 603.0 06:15 06:45 nipple 8/10/2018 8/10/2018 0.25 INTRM2 CSGDRL TRIP T POOH on elevators f/603'to 512' 603.0 512.0 06:45 07:00 8/10/2018 8/10/2018 1.00 INTRM2 CSGDRL PULD T POOH, LD 5"HWDP/Jars f/512'to 512.0 144.0 07:00 08:00 144' 8/10/2018 8/10/2018 2.00 INTRM2 CSGDRL BHAH T PJSM, LD BHA for Baker. Calc 144.0 0.0 08:00 10:00 fill=81.92 bbls, Atual fII=111 bbls 8/10/2018 8/10/2018 0.50 INTRM2 CSGDRL BHAH T Clean/clear floor 0.0 0.0 10:00 10:30 8/10/2018 8/10/2018 1.00 INTRM2 CSGDRL RURD T PU tools and equip to floor 0.0 0.0 10:30 11:30 8/10/2018 8/10/2018 0.50 INTRM2 CSGDRL BHAH T MU bit to steering head and LD 0.0 0.0 11:30 1200 8/10/2018 8/10/2018 2.50 INTRM2 CSGDRL SHAH T MU SDL inner string BHA per Baker t/ 0.0 165.0 12:00 1430 165' 8/10/2018 8/10/2018 0.75 INTRM2 CSGDRL BHAH T MWD load smart battery. SIMOPS- 165.0 165.0 14:30 15:15 stage work platform on floor 8/10/2018 8/10/2018 0.50 INTRM2 CSGDRL BHAH T Continue MU SDL inner string BHA to 165.0 0.0 15:15 15:45 174' and rack back in derrick 8/10/2018 8/10/2018 1.50 INTRM2 CSGDRL RURD T RU to run 7" liner and PU tools and 0.0 0.0 15:45 17:15 equip to floor 8/10/2018 8/10/2018 5.25 INTRM2 CSGDRL PUTBPJSM, T P/U and run 7" Tenaris Blue 0.0 2,406.0 17:15 22:30 liner. M/U 32# Reamer shoe and 58 /. ti@.t� joints 26# L-80 TN Blue with crimped >11 on Hydroform centralizers per detail top 2406' MD. Torque turn connections to 15,000 ft/lbs with Seal Guard ECF dope. P/U= 110, S/0=108k 8/10/2018 8/10/2018 1.00 INTRM2 CSGDRL RURD T MU Lwr QC, Remove blocks, RD 2,406.0 2,406.0 22:30 2330 tongs, Build work platform, PU C - plate, install false table/ slip bowl, LD lift sub, CO elevators 8/10/2018 8/11/2018 0.50 INTRM2 CSGDRL BHAH T RIH w/ BHA inner string t/ 82' 0.0 82.0 23:30 0000 8/11/2018 8/11/2018 1.75 INTRM2 CSGDRL BHAH T RIH w/ BHA inner string f/82'to 82.0 174.0 00:00 01:45 174' (PJSM & load sources @ 133') Plug into MWD 8/11/2018 8/11/2018 1.75 INTRM2 CSGDRL TRIP T RIH w/ BHA inner string on 4" DP 174.0 2,488.0 01:45 0330 1 1 1 f/174' to 2,488' Page 20/37 Report Printed: 9/7/2018 Operations Summary (with Timelog Depths) MT6-O8 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth start Time End Time our (hr) Phase Op Code AcWdy Cade Time P-T-X Operatwn (fIKB) End Depth (MKB) 8/11/2018 8/11/2018 0.25 INTRM2 CSGDRL HOSO T Rih w/single it & mark it for space out 2,488.0 2,488.0 03:30 03:45 pups. POOH & UD single it. 8/11/2018 8/11/2018 0.50 INTRM2 CSGDRL BHAH T M/U pup its, quick connect & HRDE & 2,488.0 2,495.0 03:45 04:15 tie inner string into 7" SDL. 8/11/2018 8/11/2018 0.50 INTRM2 CSGDRL RURD T R/D false bowl & table. RID working 2,495.0 2,495.0 04:15 04:45 platform. 8/11/2018 8/11/2018 0.50 INTRM2 CSGDRL BHAH T MIN float sub, flow diverter & 1 stand 2,495.0 2,538.0 04:45 05:15 1 1 5" DP 8/11/2018 8/11/2018 0.50 INTRM2 CSGDRL DHEQ T Shallow hole test MWD tools w/220 2,538.0 2,538.0 05:15 05:45 gpm / 1500 psi 8/11/2018 8/11/2018 10.75 INTRM2 CSGDRL TRIP T RIH w/T' SDL f/2,538' to 10,163' 2,538.0 10,163.0 05:45 16:30 8/11/2018 8/11/2018 0.50 INTRM2 CSGDRL MPDA T F/C (static). Pull trip nipple & install 10,163.0 10,163.0 16:30 17:00 RCD bearing. 8/11/2018 8/11/2018 0.75 INTRM2 CSGDRL CIRC T Break circ & obtain base parameters 10,163.0 10,257.0 17:00 17:45 f/10,163' to 10,257'. PU wt 243 k, SO wt 182 k, ROT wt 212 k, 20 rpm 10 k trq, 220 gpm, 1680 psi, TRPM = 3252 / 275 gpm, 2160 psi, TRPM = 4152 8/11/2018 8/11/2018 3.25 INTRM2 CSGDRL REAM T W&R f/10,257'to TO 10,491'w/220 10,257.0 10,491.0 17:45 21:00 gpm / 1680 psi, 20 rpm 110 k trq. Reduce mud wt from 10.8 ppg to 10.3 ppg 8/11/2018 8/12/2018 3.00 INTRM2 CSGDRL DCSG T Drill ahead f/10,491'to 10,565' MD / 10,491.0 10,565.0 21:00 00:00 7,380' TVD, ADT 2.6 Hrs, ECD 11.48 ppg, 550 gpm, 2250 psi, PU wt 243 k, SO wt 182 k, ROT wt 212 k, 40 rpm, 10.5/9 k ft/lbs trq, 5 k WOB. (Opened under reamer & flow diverter @ 10,562' MD) 8/12/2018 8/12/2018 12.00 INTRM2 CSGDRL DCSG T Drill ahead f/10,565'to 10,916' MD / 10,565.0 10,916.0 00:00 12:00 7,547' TVD, ADT 10.2 Hrs, ECD 11.51 ppg, 550 gpm, 2540 psi, PU wt 240 k, SO wt 190 k, ROT wt 214 k, 40 rpm, 10.5/9 k f/lbs trq, 5-8 k WOB. 8/12/2018 8/13/2018 12.00 INTRM2 CSGDRL DCSG T Drill ahead f/10,916'to 11,388' MD / 10,916.0 11,388.0 12:00 00:00 7,755' TVD, ADT 10.3 Hrs, ECD 11.51 ppg, 550 gpm, 2580 psi, PU wt 248 k, SO wt 185 k, ROT wt 213 k, 40 rpm, 12/10 k ft/lbs trq, 6-10 k WOB. 8/13/2018 8/13/2018 3.75 INTRM2 CSGDRL DCSG T Drill ahead f/11,388'to 11,550' MD / 11,388.0 11,550.0 00:00 03:45 7,813' TVD, ADT 3.4 Hrs, ECD 11.51 ppg, 550 gpm, 2600 psi, PU wt 250 k, SO wt 185 k, ROT wt 213 k, 40 rpm, 12/10 k fl/lbs trq, 6-10 k WOB. 8/13/2018 8/13/2018 8.25 INTRM2 CSGDRL DCSG P Drill ahead f/11,550'to 11,885'MD/ 11,550.0 11,885.0 03:45 12:00 7,886' TVD, ADT 7.8 Hrs, ECD 11.55 ppg, 575 gpm, 2810 psi, PU wt 255 k, SO wt 185 k, ROT wt 215 k, 40 rpm, 14.5/12 k f tlbs trq, 5-10 k WOB. 8/13/2018 8/14/2018 12.00 INTRM2 CSGDRL DCSG P Drill ahead f/11,885'to 12,265' MD / 11,885.0 12,265.0 12:00 00:00 7,942' TVD, ADT 10.2 Hrs, ECD 11.52 ppg, 575 gpm, 2910 psi, PU wt 275 k, SO wt 168 k, ROT wt 212 k, 40 rpm, 15/12 k ff/Ibs trq, 5-8 k WOB. 8/14/2018 8/14/2018 9.50 INTRM2 CSGDRL DCSG P Drill ahead with SDL from 12,265' to 12,265.0 12,550.0 00:00 09:30 TO 12,550' MD / 7,969' TVD, ADT 8.3 Hrs. MPD on connections. Flow diverter washed-out at 12,506'. Under reamer closed at 12,536' 8/14/2018 8/14/2018 0.75 INTRM2 CEMENT CIRC P Circulate and condition with 300 gpm, 12,550.0 12,550.0 09:30 10:15 1 I 2570 psi, 40 rpm, 14k TQ. PU/Down weight = 305/173k, Rotating = 220k Page 21/37 Report Printed: 91712018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log S1ah Depth Start Time End Time our (hr) Phese Op Code Acth; ty Code Time P-T-X Operation (fika) End Depth (111<e) 8/14/2018 8/14/2018 4.25 INTRM2 CEMENT CIRC P Weight up from 10.3 ppg to 10.8 ppg 12,550.0 12,550.0 10:15 14:30 with 625 gpm - 575 gpm / 2290 - 2130 psi. Max ECD = 11.75 ppg 8/14/2018 8/14/2018 0.75 INTRM2 CEMENT CIRC P Verify flow diverter is closed at 300 12,550.0 12,550.0 14:30 15:15 gpm / 2400 psi. Drop 1.75" OD bronze ball. Set down 10K, pump ball down at n 2 bpm 1840-790 psi. Ballon seat at 465 slks. Set down 10K and pressure Set do K up to 3,760 psi to shear ball off seat. PU and confirm liner released tPUW= 230k) 8/14/2018 8/14/2018 1.00 INTRM2 CEMENT PMPO P POOH with pumps from 12,550'to 12,550.0 12,329.0 15:15 16:15 12,329' at 84-300 gpm 1900 - 2420 psi (Circ 2 x 4"x7" volumes while pulling) 8/14/2018 8/14/2018 0.25 INTRM2 CEMENT OWFF P Perform flow check (static). Blow 12,329.0 12,329.0 16:15 16:30 down top drive and line up to Strip OOH 8/14/2018 8/14/2018 7.25 INTRM2 CEMENT SMPD P Strip OOH from 12,329' to 2,661' 12,329.0 2,661.0 16:30 23:45 140/130 & 350/230 in & out slips 8/14/2018 8/15/2018 0.25 INTRM2 CEMENT OWFF P Perform flow check (static) 2,661.0 2,661.0 23:45 00:00 8/15/2018 8/15/2018 0.50 INTRM2 CEMENT MPDA P Rig down MPD and rig up trip nipple 2,661.0 2,661.0 00:00 00:30 8/15/2018 8/15/2018 0.25 INTRM2 CEMENT TRIP P POOH racking back 5" DP from 2,661' 2,661.0 2,538.0 00:30 00:45 to 2,538'. Funtion annular UPR/LPR 6/15/2018 8/15/2018 0.50 INTRM2 CEMENT SHAH P POOH from 2,538' to 2,488'. Lay down 2,538.0 2,488.0 00:45 01:15 float sub, stab, flow-diverter and liner running tools as per Baker 8/15/2018 8/15/2018 2.00 INTRM2 CEMENT TRIP P POOH racking back 4" DP from 2,488' 2,488.0 176.0 01:15 03:15 to 176' 8/15/2018 8/15/2018 0.25 INTRM2 CEMENT OWFF P Perform flow check (static). SIMOPS: 176.0 176.0 03:15 03:30 PJSM - Lay down BHA 8/15/2018 8/15/2018 0.50 INTRM2 CEMENT SHAH P Lay down BHA as per Baker DD and 176.0 116.0 03:30 04:00 MWD 8/15/2018 8/152018 0.50 INTRM2 CEMENT SFTY P PJSM - Unloading nuclear sources 116.0 116.0 04:00 04:30 8/15/2018 8/15/2018 1.25 INTRM2 CEMENT BHAH P Continue laying down BHA as per 116.0 0.0 04:30 05:45 Baker. Function blinds 8/15/2018 8/15/2018 2.00 INTRM2 CEMENT SHAH P Clean and clear floor. Lay down SDL 0.0 0.0 05:45 07:45 drilling BHA via B/S. PU and break back-up bit from SDL motor. PU tools, equipment, cast iron cement retainer, space-out pups and double stack power tongs. SIMOPS: Mechanic inspect Baylor Brake and observe shaft bolts backing-out. RD coolant lines. RD guards and slide out Baylor Brake. Lock-tight and tighten shaft bolts to spec) 8/15/2018 8/152018 0.50 INTRM2 CEMENT SEQP P Service rig, draw works and iron 0.0 0.0 07:45 08:15 roughneck while mechanic continue work on Baylor Brake. SIMOPS: Prep tools for cementing run 8/15/2018 8/15/2018 1.50 INTRM2 CEMENT SEQP P Continue work on Baylor Brake. Slide 0.0 08:15 09:45 into position, shim & bolt in place. RU(1A n�4 C coolant lines and guards. Funtion test !' 7 Baylor Brake - good r 8/15/2018 8/15/2018 1.75 INTRM2 CEMENT SFTY P PJSM - MU cement retainer BHA and 0.0 2,343.0 09:45 11:30 RIH to , 8/15/2016 8/15/2018 1.25 INTRM2 CEMENT BHAH P PJSM - MU seal assembly, SLZXP 2,343.0 2,417.0 11:30 12:45 1 I I I and space-out pups from 2,343 to 2,417' Page 22137 ReportPrinted: 917/2018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time Eno Time Our (hr) Phase Op Cotle Acvvity Code Time P-T-X Operation (NKB) Ertl Depth (WB) 8/15/2018 8/15/2018 0.25 INTRM2 CEMENT CIRC P Circulate 1 string volume at 3 bpm 2,417.0 2,417.0 12:45 13:00 (170 psi) and 5 bpm (290 psi). PUW/SOW = 100k 8/15/2018 8/15/2018 4.75 INTRM2 CEMENT TRIP P RIH from 2,508 to 9,947' 2,417.0 9,947.0 13:00 17:45 8/15/2018 8/15/2018 0.75 INTRM2 CEMENT CIRC P Establish circulation at 3 bpm (400 9,947.0 10,135.0 17:45 18:30 psi) and wash TOL and QC from 9,947'to 10,135'. PUW/SOW = 205/170 k 8/15/2018 8/15/2018 3.00 INTRM2 CEMENT TRIP P RIH from 10,135'to 10,302' 10,135.0 10,302.0 18:30 21:30 8/15/2018 8/15/2018 0.25 INTRM2 CEMENT CIRC P Obtain parameters PUW/SOW = 10,302.0 10,302.0 21:30 21:45 2331182 k. Stage pumps in 0.5 bpm increments to 2.5 bpm: 0.5 bpm = 350 psi 1.0 bpm = 410 psi 1.5 bpm = 440 psi 2.0 bpm = 500 psi 2.5 bpm = 570 psi 8/1512018 8/15/2018 0.50 INTRM2 CEMENT WASH P Wash down from 10,302' at 0.5 bpm 10,302.0 12,302.0 21:45 22:15 (280320)psi. Observe seals enter at 12,413' (pressure increase to 350 psi and 2k WT) 8/15/2018 8/15/2018 1.00 INTRM2 CEMENT RURD P Rack stand to 12,369' and MU cement 12,302.0 12,302.0 22:15 23:15 swivel, swing and cement hose as well as a 6.63' and 16.02' pups 8/15/2018 8/15/2018 0.25 INTRM2 CEMENT WASH P Wash down and No Go at 12,417' with 12,302.0 12,302.0 23:15 23:30 30k down. PU 25k over to confirm latch 8/15/2018 8/16/2018 0.50 INTRM2 CEMENT CIRC Stage pumps in 0.5 bpm increments to 12,302.0 12,302.0 23:30 00:00 1.0 bpm: µ 0.5 bpm = 350 psi .,w C9� 1.0 bpm = 400 psi 8/16/2018 8/16/2018 1.00 INTRM2 CEMENT CIRC PContinue staging pumps in 0.5 bpm 12,302.0 12,302.0 00:00 01:00 ./1 N increments to 2.5 bpm: ( 1.5 bpm = 440 psi 2.0 bpm = 500 psi 2.5 bpm = 570 psi 8/16/2018 8/16/2018 1.00 INTRM2 CEMENT HOSO P Release from liner and set cement 12,302.0 12,302.0 01:00 02:00 retainer. Drop 1.75" OD ball and set down 20k. Pump 2 bpm (510 psi) and observed ball on seat at 370 stks. Pressure up to 4,100 psi and hold for 1 minute. Bleed off to 790 psi and slack off 10k down. Observe pressure drop after 3 minutes. PU and break over with 230k to release from SLZXP. PU 10' and rotate 14 turns right with 205k RTW, 8 rpm, 5.5k TQ. PUW/SOW = 260/157 k. CamWt retainer set at 12 406'. PU and e valve cc o'le %th 225k up 8/16/2018 8/16/2018 2.00 INTRM2 CEMENT CIRC P Stage up to 8 bpm: 12,302.0 12,302.0 02:00 04:00 1.0 bpm = 410 psi 2.0 bpm = 500 psi 3.0 bpm = 590 psi 4.0 bpm = 720 psi 5.0 bpm = 830 psi 6.0 bpm = 960 psi 7.0 bpm = 1,120 psi 8.0 bpm = 1,320 psi SIMOPS: PJSM -Cement job. SfinD into cement retainer and set down 25k an rib e- crculation with 2 bpm (510 psi). Page 23137 ReportPrinted: 9/712016 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stat Depth Stan Time End Tune our (hr) Phase Op Code AcbvAy Code Time P -T -V OpeniWn (i1KB) End Depth h1KEh 8/16/2018 8/16/2018 1.25 INTRM2 CEMENT CMNT 1p Schlumberger PT cement lines to 12,302.0 12,302.0 04:00 05:15 4,000 psi. Pump 7" liner cement as per program: 20 bbls of 11.3# Mud Push @ 2.0 bpm �k 62.2 bible of 15.8# cement @ 2.0 bpm 20 bbls of 8.3# water @ 2.0 bpm 8/16/2018 8/16/2018 2.00 INTRM2 CEMENT CMNT P Displace cement with rig pump 10.8 12,302.0 12,302.0 05:15 07:15 ppg LSND starting at 2 bpm. ased the rale tc 2.5 bpm at bible a catch up ce Red ced rate bac o .0 bpm at 40 bible away when observed pressure coming up to 60 psi from 20 psi. Continue displacing the cement at 2.0 bpm and reduce the rate to 1.0 bpm at 110 bbls away (prior cement at shoe at 116 bbls). Continue chasing with rig pump at 1.0 bpm for a total displacement of 171.2 bbls. CIP at 7:30 hrs (left 5 bbls of cement in DP) 8/16/2018 8/1612018 0.25 INTRM2 CEMENT PACK P Set packer as per Baker. PU and 12,302.0 12,302.0 07:15 07:30 expose dog sub with UW/DW = 230/125 k. Observe shift at 165k. PU 215k, ROT 15 rpm, 6k TQ, SO 140k Confirm packerset 8/16/2018 8/16/2018 0.50 INTRM2 CEMENT OWFF P Monitor well for flow (static). SIMOPS: 12,302.0 12,302.0 07:30 08:00 Blow down and dg down cement swivel and cement line 8/16/2018 8/16/2018 1.50 INTRM2 CEMENT TRIP P POOH from 12,302'to 10,135' on trip 12,302.0 10,135.0 08:00 09:30 1 1 1 tank 8/16/2016 8/16/2018 2.25 INTRM2 CEMENT TRIP P POOH from 10,135'to 9,947'with 15.5 10,135.0 9,947.0 09:30 11:45 bpm (2,210 - 2,190 psi). CBU with 15.5 bpm and OWFF (static) 8/16/2018 811612018 0.25 INTRM2 CEMENT CIRC P Pump 20 bbls of a 12.0# slug 9,947.0 9,947.0 11:45 12:00 8116/2018 8116/2018 1.00 INTRM2 CEMENT SLPC P PJSM and slip and cut 68' of drilling 9,947.0 9,947.0 12:00 13:00 line 8/16/2018 8/16/2018 0.50 INTRM2 CEMENT SVRG P Service top drive and draw works 9,947.0 9,947.0 13:00 13:30 8/16/2018 8/17/2018 10.50 INTRM2 CEMENT TRIP P Continue POOH on trip tank from 9,947.0 2,630.0 13:30 00:00 9,947'to 2,630' while checking and cleaning cement rings (became more substantial from std #35) 8/17/2018 8/17/2018 1.00 INTRM2 CEMENT TRIP P Continue POOH on trip tank from 9,947.0 2,297.0 00:00 01:00 9,947' to 2,297' while checking and cleaning cement rings. Lay down SLZXP running tool and space out pups and 2Its of 4" DP 8/17/2018 8/1712018 1.25 INTRM2 CEMENT TRIP P POOH and rack back 4" DP in derrick 2,297.0 0.0 01:00 02:15 from 2,297'to CICR running tool and lay down same. 8/17/2018 8/17/2018 0.75 INTRM2 CEMENT RURD P Clean and clear the rig floor and lay 0.0 0.0 02:15 03:00 down pup jts. PU double stack power tongs. PU 7" csg elevators. SIMOPS: Prep to test liner top packer againts blind rams 8/17/2018 8/17/2018 0.50 INTRM2 CEMENT PRTS P RU and test 7" liner top packer to 0.0 0.0 03:00 03:30 1,000 psi for 10 minutes on chart. RD test equipment 8/17/2018 8/17/2018 0.50 INTRM2 CEMENT RURD P Pull wear ring as per FMC and blow 0.0 0.0 03:30 04:00 down kill line 8/17/2018 8/17/2016 1.00 INTRM2 CEMENT PUTB P RU to run 7" 26# L-80 BTCM tie back 0.0 0.0 04:00 05:00 Page 24137 ReportPrinted: 91712018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan oepm stannm End Time our(hp Phase Op Code Activity Code Time P.T.X Operation (WS) End Depth(ftKB) 8/17/2018 8/17/2016 4.25 INTRM2 CEMENT TRIP P PJSM & RIH with 7" csg as per detail 0.0 2,993.0 05:00 09:15 to 2,993' 8/17/2018 8/17/2018 0.50 INTRM2 CEMENT CIRC P RU head pin and pump 32.5 bola of a 2,993.0 2,993.0 09:15 09:45 13.2# dry job. RD head pin 8/17/2018 8/17/2018 4.25 INTRM2 CEMENT TRIP P Continue RIH with 7" tie back from 2,993.0 7,215.0 09:45 14:00 2,993'to 7,215' as per detail. HI-Line power lost 8/17/2018 8/17/2018 0.50 INTRM2 CEMENT OTHR T Warm up gen set #1 and #2. Rig on 7,215.0 7,215.0 14:00 14:30 Gen power at 14:20 hrs. Sync in top drive 8/17/2018 8/17/2018 3.50 INTRM2 CEMENT TRIP P Continue RIH with 7" tie back from 7,215.0 9,997.0 14:30 18:00 7,215'to 9,997' as per detail 8/17/2018 8/17/2018 0.50 INTRM2 CEMENT HOSO P RU and wash down to locate seals on 9,997.0 10,029.0 18:00 18:30 7# tie back joint #237 at 1 bpm (350 psi). Located seals at 10,029' MD. No- goat 10,010' MD 8/17/2018 8/17/2018 0.50 INTRM2 CEMENT PRTS P RU and test seals to 1,000 psi. Chart 10,029.0 10,029.0 18:30 19:00 test for 10 minutes (1.7 bbls pumped to pressure up) 8/17/2018 8/17/2018 0.50 INTRM2 CEMENT HOSO P POOH and lay down 3 7" be back 10,029.0 10,029.0 19:00 19:30 joints: #237, #236 and #235 (Total of 234 7" tie back joints in the hole). PUW = 240k 8/17/2018 8/17/2018 1.50 INTRM2 CEMENT HOSO P MU 7" 26# L-80 BTCM pups for space 10,029.0 10,029.0 19:30 21:00 out (21,14', 10.07' and 5.79') and BTCM to 563 XO joint, hanger and landing joint with head pin for circulating 8/17/2018 8/17/2018 0.50 INTRM2 CEMENT HOSO P Wash down and locate seals at 1 bpm 10,029.0 10,029.0 21:00 21:30 (340 psi). SOW = 175K. PU and space out hanger under annular 8/17/2018 8/17/2018 0.50 INTRM2 CEMENT SFTY P PJSM and line up to reverse circulate. 10,029.0 10,029.0 21:30 22:00 Pump to verify open circulation path at 3 bpm (800 psi) 8/17/2018 8/17/2018 1.50 INTRM2 CEMENT CRIH P Reverse circulate well to spot 10,029.0 10,029.0 22:00 23:30 corrosion inhibited brine at 3 bpm (800 psi). Pump 20 bbls of high visc spacer and chase with 244.3 bbls of 9.0# brine. FCP = 730 psi 8/17/2018 8/18/2018 0.50 INTRM2 CEMENT FRZP P Swap to ball mill. RU and pressure 10,029.0 10,029.0 23:30 00:00 test lines to 2,500 psi in preparation for freeze protect 8/18/2018 8/1812018 0.50 INTRM2 CEMENT FRZP P Reverse circulate 40 bbls of diesel to 10,029.0 10,029.0 00:00 00:30 1 freeze protect at 1.5 bpm (640 FCP) 8/18/2018 8118/2018 0.25 INTRM2 CEMENT HOSO P Strip in hole to 10,016' S/O = 180k. 10,029.0 10,016.0 00:30 00:45 Sting into seals, bleed off pressure and open annular 8/18/2018 8/18/2018 0.25 INTRM2 CEMENT HOSO P RIH and land out 5.21' from fully 10,016.0 10,024.6 00:45 01:00 located at 10,024.62' mule shoe depth. S/O = 21 OK 8/18/2018 8/1812018 1.00 INTRM2 CEMENT RURD P Break out and lay down 7" landing 10,024.6 0.0 01:00 02:00 joint. Rig down circulating equipment and drain the stack to tote 8/18/2018 8/18/2018 1.50 INTRM2 CEMENT W WSP P Set 7" x 9-5/8" pack-off as per FMC. 0.0 0.0 02:00 03:30 RILDS and lest void to 5,000 (CPAI witness test). SIMOPS: Lay down 7" elevators, double power tongs and osg equipment 8/18/2018 1.50 INTRM2 CEMENT PRTS P RU and pressure test 7" x 9-5/8" 0.0 0.0 18/18/2018 03:30 05:00 1 annulus to 2,500 psi for 30 minutes on 1 l chart. Rig down test equipment and blow down lines Page 25137 Report Printed: 9/7/2018 operations Summary (with Timelog Depths) MT6-O8 e Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Imre Dur (hr) Phase Op Code Activity GDde Time P-T-x Operadon (ftKB) Ehd Depth (tlKB) 8/18/2018 8/18/2018 2.00 INTRM2 CEMENT BOPE P PJSM and change out from 4.5" x 7" 0.0 0.0 05:00 07:00 upper rams to 3-1/2" x 6" VBRs. SIMOPS: C/O from NC-50 to XT-39 saver sub on top drive 8/18/2018 8/18/2018 1.50 INTRM2 CEMENT BOPE P RU and test UVBRs to 250/3,500 psi 0.0 0.0 07:00 08:30 for 5 minutes each with 4" TJ. RID equipment 8/18/2018 8/18/2018 0.50 INTRM2 CEMENT RURD P Set 6.25" OD wear ring 0.0 0.0 08:30 09:00 8/18/2018 8/18/2018 0.50 INTRM2 CEMENT BHAH P PU BHA tools and equipment via 0.0 0.0 09:00 09:30 ibeaverslide 8/18/2018 8/1812018 1.75 INTRM2 CEMENT BHAH P PJSM & MU 6" Clean out BHA as per 0.0 263.0 09:30 11:15 Baker DD to 263'. Motor offset set to 0 deg 8/18/2018 8/18/2018 0.50 INTRM2 CEMENT PULD P RIH with BHA to 575' 263.0 575.0 11:15 11:45 8/18/2018 8/18/2018 0.25 INTRM2 CEMENT SVRG P Service rig - replace o-ring on iron 575.0 575.0 11:45 12:00 roughneck 8/18/2018 8/19/2018 12.00 INTRM2 CEMENT PULD P Single in the hole with 4" DP from 575' 575.0 10,453.0 12:00 00:00 to 10,453'from the pipe shed. PUW/SOW = 175k/140k. Calculated displacement = 65 bbls, actual = 56 bbls. 8/19/2018 8/19/2018 1.00 INTRM2 CEMENT TRIP P Continue RIH from 10,453'to 12,256' 10,453.0 12,256.0 00:00 01:00 from derrick. UW/DW = 195/145k 8/19/2018 8/19/2018 1.75 INTRM2 CEMENT PRTS P RU and test 7" rasing to 3,500 psi for 12,256.0 12,256.0 01:00 02:45 30 minutes on chart. Blow down lines and rig down test equipment. Obtain SCRS at 20/30 spm prior to drilling out 8/19/2018 8/1912018 0.50 INTRM2 CEMENT COCF P Wash and ream down from 12,256'o 12,256.0 12,406.0 02:45 03:15 12,405' with 200 gpm (1,780 psi), 40 rpm, 8-12k Tq. Tag cement at 12,405' and cement retainer at 12,406' 8/19/2018 8/19/2018 5.00 INTRM2 CEMENT DRLG P Drill out cement retainer, shoe track 12,406.0 12,550.0 03:15 08:15 and rat hole from 12,405'to 12,550' 8/19/2018 8/19/2018 0.75 INTRM2 CEMENT DDRL P Drill 20' of new formation from 12,550' 12,550.0 12,570.0 08:15 09:00 to 12,570'. ADT = 0.7, TVD = 7,972'. UW/DW/RW = 205/145/160 k 8/19/2018 8/19/2018 1.00 INTRM2 CEMENT TRIP P Pull into the shoe from 12,570'to 12,570.0 12,447.0 09:00 10:00 12,447'. C&C with 300 gpm (2,080 psi) 60 rpm, 8k Tq. Obtain SCRS @ 20/30 spm. OWFF (static) 8/19/2018 8/19/2018 1.00 INTRM2 CEMENT FIT P RU and perform fit test to 12.6 ppg 12,447.0 12,447.0 10:00 11:00 EMW. Blow down lines and rig down test equipment 8/1912018 8/19/2018 0.25 PROD1 DRILL OWFF P OWFF (static). Dropping in annulus 4" 12,447.0 12,447.0 11:00 11:15 8/1912018 8/19/2018 3.25 PROD1 DRILL TRIP P POOH on the trip tank from 12,447' to 12,447.0 10,055.0 11:15 14:30 10,055' (Observed incorrect hole fill) 8/19/2018 8/19/2018 0.25 PROD1 DRILL OWFF P Monitor well for 15 minutes (static). 10,055.0 10,055.0 14:30 14:45 Aired up mud at trip nipple. SIMOPS: Mobilize RCD to rig Floor 8/19/2018 8/19/2018 0.50 PROD1 DRILL MPDA P Pull trip nipple and install RCD 10,055.0 10,055.0 14:45 15:15 8/19/2018 8119/2018 6.50 PROD1 DRILL SMPD P SOOH from 10,055'to 545'. PU = 10,055.0 545.0 15:15 21:45 180k 8/1912018 8119/2018 1.00 PROD1 DRILL SFTY P Monitor well until static. SIMOPS: 545.0 545.0 21:45 22:45 PJSM - Remove RCD bearing, install trip nipple & UD BHA 8/19/2018 8/1912018 0.50 PROD1 DRILL MPDA P Pull RCD and install trip nipple 545.0 545.0 22:45 23:15 Page 26137 ReportPrinted: 917/2018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Star) Time End Time our (hr) Phase op coo Activity Code Time P-T-x operatlon (WS) Ehd Depth (Itl(B) 8/19/2018 8/19/2018 0.25 PROD1 DRILL TRIP P Rack back stands from 545'to 260'. 545.0 260.0 23:15 23:30 PU = 80k. Calculated fill for trip = 78 Wis. Actual = 82 bbis 8/19/2018 8/20/2018 0.50 PROD1 DRILL BHAH P Rack back and lay down 6" Clean out 260.0 96.0 23:30 00:00 BHA from 260'to 96' 8/20/2018 8/20/2018 0.50 PROD1 DRILL BHAH P Continue to lay down 6" Clean out 96.0 0.0 00:00 00:30 BHA from Was per Baker 8/20/2018 8/20/2018 0.50 PROD1 DRILL RURD P Pull wear ring as per FMC 0.0 0.0 00:30 01:00 8/20/2018 8/20/2018 1.00 PRODt WHDBOP BOPE P RU to test BOPE. Set 4" TJ and UPR 0.0 0.0 01:00 02:00 test plug. RU lest equipment. Fill slack choke line and kill line with 8.3 ppg water. Purge air from system 8/20/2018 8/20/2018 2.25 PROD1 WHDBOP BOPE P `"Perform AOGCC BOPE test to 0.0 0.0 02:00 04:15 250/3500 psi 5 min each. AOGCC test witness waived by Matthew Herrera (AOGCC). " toe l�k�/J Test with 4" Test joint, Annular preventer, upper and lower pipe ram. CC FOSV/Dart, Auto and manual IBOP. L J Choke valves #1 - 14, needle above #1, 4" Demco kill, HCR choke and kill. Manual choke and kill on stack. Test remote panel in boiler room. Test remote PVTS and flow meter. 8/20/2018 8/20/2018 0.50 PROD1 WHDBOP BOPE P Perform accumulator function test- 0.0 0.0 04:15 04:45 System pressure = 3,000 psi. Pressure after functioning all rams, annular and HCR's = 1,550 psi. 200 psi attained in 30 seconds. Full system pressure recovery in 147 seconds. 4 nitrogen bottle average = 2,150 psi. SIMOPS: PU 4-1/2" TJ to dg floor. 8/20/2018 8/20/2018 1.25 PROD1 WHDBOP BOPE P Test with 4-1/2" TJ, annular, upper and 0.0 0.0 04:45 06:00 lower pipe rams and blind rams .Test manual and super auto choke to 1,100 psi. Test rig gas alarms. 8/2012018 8/20/2018 0.75 PROD1 DRILL RURD P Set 6.25" ID wear ring as per FMC. 0.0 0.0 06:00 06:45 SIMOPS: RD test equipment and blow down lines 8/20/2018 8/20/2018 1.00 PROD1 DRILL RURD P Clean and clear rig floor. PU BHA 0.0 0.0 06:45 07:45 tools and equipment via beaver slide 8/20/2018 8/20/2018 1.25 PROD1 DRILL BHAH P PJSM & MU BHA to 79' as per Baker 0.0 79.0 07:45 09:00 1 DD/MWD 820/2018 8/20/2018 0.50 PROD1 DRILL SHAH P Plug in MWD. SIMOPS: MU NMDC in 79.0 79.0 09:00 09:30 90' MH & PU sources box 8/20/2018 8/20/2018 0.25 PROD1 DRILL BHAH P Baker load nuclear sources 79.0 79.0 09:30 0945 8120/2018 8/20/2018 0.25 PROD1 DRILL BHAH P Continue MU BHAto 345' with NMDC 79.0 345.0 09:45 10:00 and HW stands from derrick 8/20/2018 8/202018 1.00 PRODt DRILL TRIP P RIH from 345'to 1,769' from derrick 345.0 1,769.0 10:00 11:00 820/2018 8/20/2018 0.50 PROD1 DRILL DHEQ P Perform shallow MWD test with 250 1,769.0 1,769.0 11:00 11:30 gpm (1,250 psi), 20 rpm 0.7 Tq 8/20/2018 820/2018 5.00 PROD1 DRILL TRIP P Continue to TIH from 1,769'to 12,434' 1,760.0 12,434.0 11:30 16:30 MD PUW/SOW = 180/140k Calculated displacement = 73 Wis. Actual = 73 bbis 8/20/2018 8/20/2018 1.00 PROD1 DRILL SLPC P Cut off drilling line. SIMOPS: Circulate 12,434.0 12,434.0 16:30 17:30 at 2 bpm (1,100 psi) Page 27137 Report Printed: 917/2018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Deph Start Tine End Time our (hr) Phase Op Code Activit' Code Time P-T-XOperation (KKB) End Deph (ftKB) 8/20/2018 8/20/2018 0.50 PROD1 DRILL SVRG P Lubricate rig 12,434.0 12,434.0 17:30 18:00 8/20/2018 8/20/2018 2.00 PROD1 DRILL CIRC P PJSM and displace well over to 9.2 12,434.0 12,434.0 18:00 20:00 ppg FloPro at 5 bpm. ICP = 2,300 psi. Pump 28 bbls of high vis spacer. Chase with 447 bbis of 9.2 ppg FloPro. Reciprocate from 12,434' to 12,339' MD, 40 rpm, 5k Tq 8/20/2018 8/20/2018 0.50 PROD1 DRILL OWFF P Monitor well for Flow for 30 minutes. 12,434.0 12,434.0 20:00 20:30 Slight trickle in return 8/20/2018 8/20/2018 1.00 PROD? DRILL CIRC P Circulate btms up at 220 gpm, 1,340 12,434.0 12,434.0 20:30 21:30 psi, 40 rpm, 4.5 Tq. to ensure even FloPro in/out. Reciprocate from 12,434'to 12,339' 8/20/2018 8/20/2018 0.50 PROD1 DRILL OWFF P Drain trip nipple and monitor well at 12,434.0 12,434.0 21:30 22:00 the 2" RCD bleed line, catching samples in a vis cup every 5 minutes for 30 minutes. Unable to get a consistent down trend in returns. Final check - 0.6 bph. 8/20/2018 8/20/2018 0.50 PROD1 DRILL CIRC P Resume circulation at 220 gpm, 1,400 12,434.0 12,434.0 22:00 22:30 psi, 40 rpm, 4k Tq while notifying town for plan forward. Decision to stop circulating and continue monitoring the well. 8/20/2018 8/20/2018 1.25 PROD1 DRILL OWFF P Continue monitoring well at the 2" 12,434.0 12,434.0 22:30 23:45 RCD bleed line while catching samples in a vis cup every 5 minutes. Still unable to establish a consistent down trend in returns. Well not static at rates from 0.34 to 0.7 bph. Notify town engineer. Decision to install RCD bearing and drill ahead 8/20/2018 8/21/2018 0.25 PROD1 DRILL RURD P Mobilize RCD bearing to the rig floor 12,434.0 12,434.0 23:45 00:00 8/21/2018 8/21/2018 0.50 PROD1 DRILL MPDA P PJSM and pull trip nipple, install MPD 12,434.0 12,434.0 00:00 00:30 element. 8/21/2018 8/21/2018 1.50 PROD1 DRILL REAM P Wash and ream down from 12.434' 12,434.0 12,570.0 00:30 02:00 MD to 12,570' MD, logging shoe track 180 fph. 220 gpm, 1550 psi, 60 rpm, 4.5k Tq. Note: No gas observed @ bottoms up. 8/21/2018 8/21/2018 10.00 PROD1 DRILL DDRL P Directional drill from 12,570' MD to 12,570.0 13,293.0 02:00 12:00 13,293' MD, 7,990' TVD. ADT=8.1 hrs, 120 rpm, Tq on/off= 6k/4.5k, 220 gpm, 1850 psi, 10.52 ppg ECD. Closing MPD chokes on connections, observe no pressure build. (7"x 9.625") Annulus B=480 psi, (9.625" x 13.375") Annulus C=100 psi. 8/21/2018 8/22/2018 12.00 PROD1 DRILL DDRL P Directional drill from 13,293 MD to 13,293.0 13,905.0 12:00 00:00 13,905' MD, 7,965' TVD. ADT=10.7 hrs, 160 rpm, Tq on/off= 7k/5k, 220 gpm, 1800 psi, 10.52 ppg ECD. Closing MPD chokes on connections, observe no pressure build. Annulus B=650 psi, Annulus C=100 psi. 8/22/2018 8/22/2018 4.75 PROD1 DRILL DDRL P Directional drill from 13,905' MD to 13,905.0 14,127.0 00:00 04:45 14,127' MD, 7,955' TVD. ADT=3.9 hrs, 160 rpm, Tq on/off= 7k/5k, 220 gpm, 1800 psi, 10.52 ppg ECD. Closing MPD chokes on connections, observe no pressure build. Page 28137 Report Printed: 917/2018 Uperations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time our (hi Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depih(ftKB) 8/22/2018 8/22/2018 1.50 PROD1 DRILL CIRC T MWD pulser shut down after downlink, 14,127.0 14,127.0 04:45 06:15 troubleshoot. Vary pump rates and RPM, shut down to re-start, pump 30 bbl low vis sweep. MWD truned back on, prior to sweep. Assumed debris washed off. Strong signal, tools appear undamaged. 8/22/2018 8/22/2018 5.75 PROD1 DRILL DDRL P Directional drill from 14,127' MD to 14,127.0 14,675.0 06:15 12:00 14,675' MD, 7,930' TVD. Tour ADT=8.3 hrs, 160 rpm, WOB=7k, Tq on/off= 6.5k/5k, 220 gpm, 2120 psi, 11.02 ppg ECD. Closing MPD chokes on connections, observe no pressure build. Annulus B=275 psi, Annulus C=100 psi. (Bled down 7" x 9.625" annulus'B' from 800 psi to 200 psi) 8/22/2018 8/23/2018 12.00 PROD1 DRILL DDRL P Directional drill from 14,675' MD to 14,675.0 15,655.0 12:00 0000 15,655' MD, 7,923' TVD. Tour ADT=9.8 hrs, 160 rpm, WOB=7-13k, Tq on/off= 7.5k/5.5k, 220 gpm, 2250 psi, 11.16 ppg ECD. Closing MPD chokes on connections, observe no pressure build. Annulus B=360 psi, Annulus C=100 psi. 8/23/2018 8/23/2018 11.75 PROD1 DRILL DDRL P Directional drill from 15,655' MD to 15,655.0 16229.0 00:00 11:45 16,229' MD, 7,893' TVD. Tour ADT=10.4 hrs, 140 rpm, WOB=5k, Tq on/off= 8.5k/5.5k, 220 gpm, 2380 psi, 11.15 ppg ECD. Drilled out of zone @ 15,625', higher gamma readings —100 gAPI but no shale in cuttings. Begin making dynamic connections holding 10.8 ppg. Observe possible minor packing off while drilling @ 16,200', slight increase in pump pressure and ECD. 8/23/2018 8/23/2018 5.75 PROD1 DRILL BKRM T Decision to start BROOH from 16,229' 16,229.0 15,625.0 11:45 1730 MD to 15,625' MD, 7,893' TVD, evaluating hole conditions. Making dynamic connections (400 psi) 8/23/2018 8/23/2018 0.50 PROD1 DRILL CIRC T CBU at 220 gpm (2,210 psi), 100 rpm, 15,625.0 15,579.0 17:30 1800 5k Tq. Reciprocate from 15,625' MD to 15,579' MD. ECD = 10.87 ppg. PUW/SOW = 180k/1 40k 8/23/2018 8/23/2018 1.50 PROD1 DRILL TRIP T Strip in hole from 15,625' MD to 15,625.0 16,065.0 18:00 19:30 16,065' MD 480/520 psi out /in slips. No problems running in hole. 8/23/2018 8/23/2018 1.50 PRODt DRILL REAM T Wash and ream from 16,065' MD to 16,065.0 16,229.0 19:30 21:00 16,229' MD at 220 gpm (2,240 psi), 100 rpm, 5.5 Tq, no apparent stability issues. 8/23/2018 8/24/2018 3.00 PROD1 DRILL DDRL P Drill from 16,229' MD to 16,333' MD 16,229.0 19.333.0 21:00 00:00 (7,896' TVD). ADT = 2.5 hrs, BIT = 49.4, Jars = 49.7. PUW/SOW/ROT = 200k/135k/155k. On/Off Tq = 6.5k/5k. ECD = 10.9. Observe gamma increase to —130 gAPI then fall off to —80. No shale in samples. Annulus B=600 psi, Annulus C=100 psi. Page 29/37 ReportPrinted: 9/7/2018 B y Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Deplh Start Time End Time our(hr) Phase Op Code Activity Code Time P-LX Operation (ftKB) End Depth lftKB) 8/24/2018 8/24/2018 12.00 PROD1 DRILL DDRL P Drill from 16,333' MD (7,896' TVD) to 16,333.0 17,006.0 0000 12:00 17,006' MD (7,911' TVD). ADT = 10.6 hrs. PUW/SOW/ROT = 200k/125k/157k. On/Off Tq = 7.0k/6.0k. ECD = 11.0 ppg 8/24/2018 8/24/2018 3.50 FROM DRILL DDRL P Drill from 17,006' MD (7,911' TVD) to 17,006.0 17,293.0 1200 1530 17,293' MD (7,918' TVD) while holding 400 psi backpressure on connections. Dynamic loss observed while drilling 30-40 bhp. Begin adding background LCM 2ppb Nut Plug. PUW/SOW/ROT = 197k/125k/157k On/Off Tq = 7.0k/5.5k ECD = 10.87 ppg 8/24/2018 8/24/2018 2.25 PROD1 DRILL CIRC T Observe floats not holding during a 17,293.0 17,253.0 15:30 17:45 connection. Pump 50 bbls of LCM pill at 220 gpm (2,220 psi), 100 rpm, 7.Ok Tq. Follow with 40 bbls of an anti-jam pill to clear the floats once the LCM pill was out of bit. Reciprocate from 17,293' to 17,253' MD 8/24/2018 8/25/2018 6.25 PROD1 DRILL DDRL P Continue drilling from 17,293' MD 17,253.0 17,693.0 17:45 00:00 (7,918' TVD) to 17,693' (7,916' TVD) while holding 200 psi back pressure on connections. ADT = 7.7 hrs. PUW/SOW/ROT = 200k/125k/160k On/Off Tq = 10.0k/8.0k. ECD = 11.0 ppg, losses return to <10 bph seepage loss. Observe gamma increase to —123 gAPI. No significant shale in samples. Annulus B=270 psi, Annulus C=100 psi. Daily loss to formation= 380 bbl 8/25/2018 8/25/2018 2.50 FROM DRILL DDRL P Continue drilling from 17,693' MD to 17,693.0 17,775.0 0000 0230 17,775'(7,791- TVD) holding 320 psi back pressure on connections (floats holding). P/U=200k, S/0=115k, ROT= 155k, On/Off Tq = 9k/6k. 220 gpm, 2330 psi, 160 rpm, ECD = 11.03 PM Slow drilling due geology, experience intermittant MWD failure, (No Resistivity) 8/25/2018 8/25/2018 1.00 FROM DRILL CIRC T Stop drilling @ 17,775', no resistivity 17,775.0 17,775.0 0230 0330 Cycle pump, send two downlinks to get Res to wake up. 8/25/2018 8/25/2018 4.25 FROM DRILL DDRL P Continue drilling from 17,775' MD to 17,775.0 17,960.0 0330 0745 17,960'(7,774- TVD) holding 320 psi back pressure on connections.220 gpm, 2400 psi, 140 rpm. Slow drilling due geology, experience intermittant MWD communication failure, (No Resistivity) 8/25/2018 8/25/2018 0.75 FROM DRILL CIRC T Rotate and reciprocate @ 17,960' MD, 17,960.0 17,960.0 07:45 0830 cycling pumps, downlinking, adjusting rotary to get Resistivity to wake up. 220 gpm, 2400 psi, 120 rpm, 8k Tq. 8/25/2018 8/25/2018 1.25 FROM DRILL DDRL P Continue drilling from 17,960' MD to 17,960.0 18,068.0 08:30 09:45 18,068' (7,768' TVD) holding 320 psi back pressure on connections. 220 gpm, 2430 psi, ECD = 11.10 ppg, 140 rpm Still experiencing intermittant MWD communication failure, (No Resistivity) Page 30137 ReportPrinted: 9/7/2018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time EM Time Dur (hr) Phase Op Code Adivity Code Time P -T-% Operation (ftKB) End Depth (ftKB) 8/25/2018 8/25/2018 2.25 PROD? DRILL CIRC T Rotate and reciprocate from 18,054' 18,068.0 18,068.0 0945 12:00 MD to 17,959' MD, cycling pumps, downlinking, adjusting rotary to get Res to wake up. 220 gpm, 2400 psi, 120 rpm, 8k Tq. Tour ADT=8.5 hrs. Annulus B=510 psi, Annulus C=100 psi @ 11:30 hrs. 8/25/2018 8/25/2018 2.25 PROD1 DRILL DDRL P Continue drilling from 18,068' MD to 18,068.0 18,160.0 1200 1415 18,160', 7,763' TVD holding 320 psi back pressure on connections. ADT= 8.5 hrs. P/U=200k, S/0=115k, ROT=155k, On/Off Tq = 9k/6k. 220 gpm, 2430 psi, ECD = 11.24 ppg, 8/25/2018 8/25/2018 1.00 PROD1 DRILL CIRC T Stop drilling @ 18,160', no resistivity. 18,160.0 18,160.0 14:15 15:15 Cycle pump, send 7 downlinks to get Res to wake up. 8/25/2018 8/25/2018 5.25 PROD1 DRILL DDRL P Continue drilling from 18,160' MD to 18,160.0 18,383.0 15:15 20:30 18,383'(7,869- TVD) holding 320 psi back pressure on connections. Tour ADT= 5.8 hrs. P/U=200k, S/0=120k, ROT=157k, On/Off Tq = 10k/7k. 220 gpm, 2500 psi, ECD = 11.0 ppg, Slow drilling due geology and resistivity issues. 8/25/2018 8/25/2018 1.00 PROD1 DRILL CIRC T Circulate and troubleshoot MWD 18,383.0 18,340.0 20:30 21:30 signal, no Resistivity. Pump low vis/ hi vis sweep around, vary rpms, send multiple downlinks. Hard restart MWD, no good. 8/25/2018 8/26/2018 2.50 PROD1 DRILL CIRC T Continue circulating (Total 2 bottoms 18,340.0 18,149.0 21:30 0000 up) @ 220 gpm, 2500 psi, 100 rpm, 7k Tq. Rack back a stand per bottoms up to 18,149' MD. Prep to POOH for BHA. Annulus B=360 psi, Annulus C=100 psi. Daily loss to formation= 260 bbl, 640 bbl cumulative. 8/26/2018 8/26/2018 2.25 PROD1 DRILL CIRC T Circulate 2 more BU, racking back a 18,149.0 18,054.0 00:00 02:15 stand after each BU from 18,149' MD to 18,054' MD. 220 gpm, 2400 psi, 100 rpm, 8.4k Tq. 8/26/2018 8/26/2018 5.50 PROD1 DRILL SMPD T Strip out of hole with MPD from 18,054.0 12 434.0 02:15 07:45 18,054' MD to 12,434' MD per schedule holding 330 psi pulling and 80 psi in slips. P/U=205k. Calc Fill=36.58 bbl, Actual Fill=66 bbl. 8/26/2018 8/26/2018 1.00 PROD1 DRILL CIRC T CBU @ 220 gpm, 1680 psi, 80 rpm, 12,434.0 12,434.0 07:45 0845 3.5k Tq. SIMOPS- PJSM on 9.6 ppg Vis brine displacement. 8/26/2018 8/26/2018 0.25 PROD1 DRILL OWFF T OWFF- Static with 9.2 ppg Flo Pro. 12,434.0 12,434.0 08:45 09:00 8/26/2018 8/26/2018 2.00 PROD1 DRILL DISP T Displace casing to 9.6 ppg Viscosifed 12,434.0 12,434.0 09:00 11:00 brine with 27 bbl Hi Vis spacer, Displace to 9.6 ppg @ 220 gpm, 1770- 1280 psi, 80 rpm, 3k Tq. Obtain SPR's, line up to SOON. 8/26/2018 8/26/2018 1.00 PROD1 DRILL SMPD T Continue SOOH from 12,434' MD to 12,434.0 11,484.0 11:00 12:00 11,484' MD per stripping schedule, holding 70 psi pulling and 40 psi in slips. P/U=188k. Page 31/37 Report Printed: 9/7/2018 Operations Summary (with Timelog Depths) MT6-O8 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log stars Depth SW Time End Time our (hr) Phase Do Code ActiWy Cade Time P -T -X operation (MCB) End Depth (ftKB) 8/26/2018 8/26/2018 6.50 PROD1 DRILL SMPD T Continue SOOH from 11,484' MD to 11,484.0 1,000.0 12:00 18:30 1,000' MD per stripping schedule, holding 70 psi pulling and 40 psi in slips. P/U=90k. 8/2612018 8/26/2018 0.25 PROD1 DRILL OWFF T Monitor well, static. 1,000.0 1,000.0 18:30 18:45 SIMOPS- Prep for trip nipple / BHA 8/2612018 8/26/2018 0.50 PROD1 DRILL MPDA T Pull RCD, Install trip nipple. 1,000.0 1,000.0 18:45 19:15 8/2612018 8/26/2018 0.25 PROD1 DRILL TRIP T POOH on elevators from 1,000' MD to 1,000.0 345.0 19:15 19:30 345' MD. 8/2612018 8/26/2018 1.50 PRODI DRILL BHAH T Rack back HWDP/Jars, lay down 345.0 0.0 19:30 21:00 BHA#13 from 345', remove sources. Calc Fill=114 bbl, Actual Fill= 157 bbl 8/26/2018 8/26/2018 1.00 PROD1 DRILL BHAH T Clean and clear rig floor. Mobilize new 0.0 0.0 21:00 22:00 BHA tools to rig floor. 8/26/2018 8/27/2018 2.00 PROD1 DRILL BHAH T PJSM, M/U BHA#14 to 110' MD. 0.0 110.0 22:00 00:00 Annulus B=100 psi, Annulus C=0 psi. Daily loss to formation= 95 bbl, 735 bbl cumulative. 8/2712018 8/27/2018 1.00 PROD1 DRILL BHAH T Continuie M/U BHA#14 from 110' MD 110.0 346.0 00:00 01:00 to 346' MD. Load sources, M/U HWDP and Jars. 8/27/2018 8/27/2018 1.00 PROD1 DRILL TRIP T RIH with BHA#14 on DP from 346' 346.0 2,246.0 01:00 02:00 MD to 2,246' MD. 8/27/2018 8/27/2018 0.25 PROD1 DRILL DHEQ T Shallow pulse test MWD tools @ 220 2,246.0 2,246.0 02:00 02:15 gpm, 820 psi - Good. 8/27/2018 8/27/2018 7.00 PROD1 DRILL TRIP T Continue RIH from 2,246' MD to 2,246.0 12,435.0 02:15 09:15 12,435' MD filling pipe every 20 stands. P/U=195k, S/0=145k. Perform weekly ram function test. 8127/2018 8/27/2018 1.00 PROD1 DRILL SLPC T PJSM, Slip and cut 52' drilling line. 12,435.0 12,435.0 09:15 10:15 (SIMOPS- circulate @ 2 bpm) 8/27/2018 8/27/2018 0.75 PROD1 DRILL SVRG T Service top drive, draw works, blocks, 12,435.0 12,435.0 10:15 11:00 perform weekly derrick inspection. 8/27/2018 8/27/2018 1.00 PROD1 DRILL CIRC T OWFF, slightly aerated. Continue 12,435.0 12,435.0 11:00 12:00 circulating surface to surface @ 220 gpm, 1240 psi. Annulus B=100 psi, Annulus C=0 psi. 812712018 8/27/2018 0.50 PROD1 DRILL MPDA T Pull trip nipple, install RCD. 12,435.0 12,435.0 12:00 12:30 812712018 8/27/2018 2.00 PROD1 DRILL DISP T Displace from 9.6 ppg Vis Brine to 9.2 12,435.0 12,435.0 12:30 14:30 ppg FloPro @ 220 gpm, 1850 psi, 40 rpm, 6k Tq. Pumped 40 bbl Hi Ys spacer, chase with 415 bbl FloPro. 8/27/2018 8/27/2018 0.25 PRODI DRILL OWFF T Close chokes, monitor well - static 12,435.0 12,435.0 14:30 14:45 8/27/2018 8/27/2018 3.75 PROD1 DRILL TRIP T Continue RIH from 12,435' MD to 12,435.0 17,960.0 14:45 18:30 17,960' MD. Observe slack off weight fall off from 125k to 90k. 8/27/2018 8127/2018 1.50 PROD1 DRILL REAM T Wash and ream down from 17,960' 17,960.0 18,383.0 18:30 20:00 MD to 18,383' MD @ 220 gpm, 2500 psi, 100 rpm, 7k Tq, 11.4 ECD. 8/27/2018 8/28/2018 4.00 PROD1 DRILL DDRL P Resume drilling from 18,383' MD to 18,383.0 18,535.0 20:00 00:00 18,535', 7,873' TVD shutting chokes on connections. ADT= 3.0 ms. P/U=200k, S/0=125k, ROT=160k, On/Off Tq = 9.5k/7.5k. 220 gpm, 2300 psi, ECD = 11.05 ppg, Annulus B=100 psi, Annulus C=O psi. Daily loss to formation= 40 bbl, 775 bbl cumulative. Page 32137 Report Printed: 91712018 Uperations Summary (with Timelog Depths) AWC MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depm Stan Tune End Time Dur (hr) Phase Op code Acwdy Cale Time P -T -X Operation (f1KB) End Depih(Po(e) 8/28/2018 8/28/2018 1.25 PRODI DRILL REAM T BROOH f/18,535'to 18,436'w/220 18,535.0 18,535.0 00:00 01:15 gpm, 2230 psi, 100 rpm, 9.5 k trq., Pump sweep & trouble shoot MWD tools. W&R back to TD of 18,535' 8/28/2018 828/2018 10.75 PROD? DRILL DDRL P Drill ahead f/18,535'to 19,103' MD, 18,535.0 19,103.0 01:15 12:00 7,883' TVD shutting chokes on connections. ADT= 8.7 hrs. P/U=205k, S/O= N/A, ROT=159k, On/Off Tq = 10.2k/8.5k. 220 gpm, 2340 psi, ECD = 10.98 ppg• 8/28/2018 8/29/2018 12.00 PROD? DRILL DDRL P Drill ahead f/19,103'to 20,019'MD, 19,103.0 20,019.0 12:00 00:00 7,876' TVD shutting chokes on connections. ADT= 10 hrs. P/U=210k, S/0= N/A, ROT=160k, On/Off Tq = 10k/9k. 220 gpm, 2700 psi, ECD = 10.7 ppg, Annulus B=100 psi, Annulus C=0 psi. Daily loss to formation= 220 bbl, 995 bbl cumulative. 8/29/2018 8/29/2018 12.00 PROD1 DRILL DDRL P Drill ahead f/20,019'to 20,607' MD, 20,019.0 20,607.0 00:00 12:00 7,873' TVD shutting chokes on connections. ADT= 10.8 hrs. P/U=208k, S/O= N/A, ROT=160k, On/Off Tq = 11.5k/l Ik. 220 gpm, 2890 psi, ECD = 11.81 ppg, 8/29/2018 8/292018 0.75 PROD1 DRILL DDRL P Drill ahead f/20,607'to 20,626' (RCD 20,607.0 20,607.0 12:00 12:45 bearing leaking) 8/29/2018 81292018 0.75 PRODI DRILL CIRC P Circ open hole volume w/220 gpm, 20,607.0 20,607.0 12:45 13:30 2800 psi. Monitor well (static) 8/29/2018 8/29/2018 0.50 PROD1 DRILL MPDA P Change out RCD bearing 20,607.0 20,607.0 13:30 14:00 8/29/2018 829/2018 7.50 PROD1 DRILL DDRL P Drill ahead f/20,607'to 21,102' MD, 20,607.0 21,102.0 14:00 21:30 7,841' TVD shutting chokes on connections. ADT= 6.8 hrs. P/U=215k, S/O= NIA, ROT=162k, On/Off Tq = 15k/12k. 220 gpm, 2900 psi, ECD = 11.88 ppg• 8/29/2018 8/30/2018 2.50 PROD1 CASING CIRC P Circ & cond hole & rack back 1 stand 21,102.0 20,960.0 21:30 00:00 per B/U F/21,102'to 20,960'w/220 gpm, 2900 psi, 100 rpm, 12 k trq. Daily loss to formation = 196 bbls, 1191 bbls cumulative. 8/30/2018 8/30/2018 4.75 PROD1 CASING CIRC P Circ & cond hole & rack back 1 stand 20,960.0 20,626.0 00:00 04:45 per WU f/20,960' to 20,626'w/220 j gpm, 2700 psi, 100 rpm, 12 k trq. 8/30/2018 8/30/2018 2.25 PRODI CASING DISP P Pump 33 bbl spacer & displace to 9.5+ 2u,626.ol 20,531.0 04:45 07:00 vis brine w220 gpm, 2700 - 1900 psi. Rack back 1 stand to 20,531', PU wt 220 k, SO wt 127 k, ROT wt 165 k, 9.9 k trq. 8/30/2018 8/302018 0.25 PRODI CASING OWFF P FIC (static). Line up MPD 20,531.0 20,531.0 07:00 07:15 8/30/2018 8/302018 2.00 PROD1 CASING SMPD P Strip OOH f/20,531'to 19,293'. 20,531.0 19,293.0 07:15 09:15 Consistent overpull thru siderite. Unable to achive slack off. 8/30/2018 8/302018 0.75 PROD1 CASING REAM P W&R back in hole f/19,293' to 19,388' 19,293.0 19,388.0 09:15 10:00 8/3012018 8/30/2018 0.25 PROD1 CASING TRIP P RIH f/19,388'to 19,579' 19,388.0 19,579.0 10:00 10:15 8/3012018 8/302018 4.00 PROD1 CASING BKRM P BROOH f/19,579'to 18,055'w/240 19,579.0 18,055.0 10:15 14:15 1 1 1 gpm, 1900 psi, 100 rpm, 9 k trq. 8/30/2018 8/30/2018 2.75 PRODI CASING CIRC P Circ hole clean for 2 B/U w/240 gpm, 18,055.0 18,055.0 14:15 17:00 1860 psi, 100 rpm, 9 k trq. Hole un- loaded significant amounts of cuttings. Page 33137 Report Printed: 9/712018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time EM Time Dur(m) Phase Op Code Acdvfty Code Time P -T -X Opembon (itKB) End Depth(flKB) 8/30/2018 8/30/2018 0.25 PROD1 CASING OWFF P F/C (static) 18,055.0 18,055.0 1700 17:15 8/30/2018 8/30/2018 4.75 PROD1 CASING SMPD P Strip OOH f/18,055'to 12,435' 18,055.0 12,435.0 17:15 22:00 8/30/2018 8/31/2018 2.00 PROD1 CASING CIRC P Pump 40 bbl high vis sweep & circ 12,435.0 12,339.0 22:00 00:00 hole clean w/230 gpm, 1480 psi, 40 rpm, 6 k trq. PU wt 200 k, SO wt 155 k, ROT 163 k 8/31/2018 8/31/2018 0.25 PROD1 CASING CIRC P Cont. to circ hole clean w/230 gpm, 12,339.0 12,339.0 00:00 00:15 1480 psi, 40 rpm, 6 k trq. 8/31/2018 8/31/2018 0.25 PROD1 CASING OWFF P F/C (static) 12,339.0 12,339.0 00:15 00:30 8/312018 8/31/2018 5.00 PROD1 CASING SMPD P Strip OOH as per MPD schedule 12,339.0 4,735.0 00:30 05:30 f/12,339'to 4,735' 8/31/2018 8/31/2018 0.50 PROD1 CASING MPDA P F/C & PJSM. Pull RCD bearing & 4,735.0 4,735.0 05:30 06:00 install trip nipple. 8131/2018 8/31/2018 3.00 PROD1 CASING TRIP P POOH f/4,735' to 149' (rack back 4,735.0 149.0 06:00 09:00 HWDP & UD jars) 8131/2018 8/31/2018 2.25 PROD1 CASING SHAH P UD BHA as per Baker reps. (PJSM & 149.0 0.0 09:00 11:15 remove sources) 8131/2018 8/31/2018 0.50 PROD1 CASING SHAH P Clean & clear floor of BHA tools & 0.0 0.0 11:15 11:45 equipment. 8131/2018 8/31/2018 0.75 COMPZN CASING RURD P R/U to run liner. R/U ower ton s, 4- 0.0 0.0 11:45 12:30 1/2"slips elevators. 8/31/2018 9/12018 11.50 COMPZN CASING PUTB P PJSM. P/U & RIH 4-1/2" TXP liner as 0.0 7,933.0 12:30 00:00 ,1 per tally to 7,933' (195 its & 29 perf (\ pups in the hole) PU wt 125 k / SO wt 122 k 9/1/2018 911/2018 2.00 COMPZN CASING OTHR P Change out elevators to 4", P/U HRDE 7,933.0 8,048.0 00:00 02:00 ZXP liner top packer and Flex Lock liner hanger easy. Make up 2-3/8" slick seal and ball seat easy Make up SLB SCMT tools to bottom of liner running tools. Mix and pour Zanplex, RIH to 8,048' MD. P/U=120k, S/0=110k. 9/1/2018 9/12018 0.50 COMPZN CASING CIRC P M/U 1 stand DP & RIH to 8,140'. 8,048.0 8,140.0 02:00 02:30 Break circ w/2 bpm, 50 psi. PU wt 132 k/SO wt 113k 9/1/2018 9/12018 0.75 COMPZN CASING RUNL P RIH wlliner on DP f/8,140'to 8,996' 8,140.0 8,996.0 02:30 03:15 9/1/2018 911/2018 0.25 COMPZN CASING SVRG P Service rig & iron roughneck 8,996.0 8,996.0 03:15 03:30 9/1/2018 911/2018 1.75 COMPZN CASING RUNL P RIH wlliner on DP f/8,996'to 12,343' 8,996.0 12,343.0 03:30 05:15 9/1/2018 911/2018 0.50 COMPZN CASING CIRC P Circ DP volume w/3 bpm, 210 psi. 12,343.0 12,343.0 05:15 05:45 Obtain torque and drag parameters. PU wt 175 k, SO wt 140 k, ROT wt 152 k, 10 rpm @4 ktrq, 20 rpm @4k trq. 9/1/2018 9/1/2018 7.00 COMPZN CASING RUNL P RIH w/liner on DP f/12,343'to 20,350' 12,343.0 20,350.0 05:45 12:45 PU wt 240 k, SO wt 145 k ( had to finesse liner in hole working thru formation changes & inclination changes) PU wt 240 k / SO wt 145 k 911/2018 9/1/2018 2.00 COMPZN CASING CIRC P Circ BILI from top perf pup w/3 bpm, 20,350.0 20,350.0 12:45 14:45 470 psi (Max gas 140 units) 9/112018 9/1/2018 0.25 COMPZN CASING OWFF P F/C (slight ooze then static) 20,350.0 20,350.0 14:45 15:00 Page 34/37 Report Printed: 91712018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depen Sart Time End Time Dur (hn Phase OP Code Activity Code Time P -T -X Operation (ftKB) End Depth (flKB) 9/1/2018 9/1/2018 0.75 COMPZN CASING PACK P Drop 1.625" setting ball, pump down 20,350.0 12,320.0 15:00 15:45 @ 3 bpm, 460 psi for 70 bbl, slow rate to 1 bpm 100 psi. Ball on seat @ 87 bbl. Increase pressure to 2200 psi. Slack off to 85 k observe hanger set. Pressure up to 3500 psi and hold 5 min. Bleed off. P/U and observe free travel @ 205k. SIO and observe shear @ 115k. Confirm released from liner. 9/1/2018 911/2018 0.75 COMPZN CASING PRTS P Rig up and pressure test liner top 12,320.0 12,320.0 15:45 16:30 packer to 3300 psi for ten minutes charted. 4-1/2" shoe @ 20,350'/ TOL 12,320.81' 9/1/2018 9/1/2018 0.25 COMPZN WELLPR TRIP P POOH w/liner running tools & SCMT 12,320.0 12,320.0 16:30 16:45 to top of liner. 9/1/2018 9/112018 0.25 COMPZN WELLPR OWFF P F/C(slight drop) 12,320.0 12,320.0 16:45 17:00 9/1/2018 9/1/2018 2.25 COMPZN WELLPR QEVL P POOH f/12,320 & cement bond log to 12,320.0 9,950.0 17:00 19:15 9,950' 9/1/2018 9/1/2018 1.00 COMPZN WELLPR SLPC P Slip&cut 75'drill line. 9,950.0 9,950.0 19:15 20:15 9/1/2018 9/1/2018 0.50 COMPZN WELLPR SVRG P Sevice dg, top drive & draw works. 9,950.0 9,950.0 20:15 20:45 9/1/2018 9/2/2018 3.25 COMPZN WELLPR PULD P POOH & L/D 4" DP f/9,950' to 6,544 9,950.0 6,544.0 20:45 00:00 9/2/2018 9/2/2018 6.50 COMPZN WELLPR PULD P POOH & L/D 4" DP f/6,544 to 93' (54 6,544.0 93.0 00:00 06:30 As Wearknot culled out for hardband) 9/2/2018 9/2/2018 1.00 COMPZN WELLPR BHAH P UD Liner running tools 7 SLB SCMT 93.0 0.0 06:30 07:30 logging tools. 9/2/2018 9/2/2018 0.50 COMPZN WELLPR BHAH P Clean & clear floor. 0.0 0.0 07:30 08:00 9/2/2018 9/212018 0.50 COMPZN WHDBOP WWWH P M/U stack washer &flush stack. 0.0 0.0 08:00 08:30 9/2/2018 9/2/2018 1.50 COMPZN WHDBOP RURD P Pull wear ring & set test plug. R/U to 08:30 10:00 lest BOPE. Fill stack & lines w/H20. 9/2/2018 9/2/2018 5.25 COMPZN WHDBOP BOPE P Test BOPE 250 psi for 5 min 13500 0.0 0.0 10:00 15:15 psi for 10 min's w/4-112" test joint. Annular, 4" Demco, Choke valves 1 - n 14; IBOP's, Choke needle valve, 3- 1/2" X 6" VBR's Upper & Lower & blind rams, 5" Dart/FOSV, HCR / Man choke/kill, Accumulator test, Initial I 3000 psi, final 1500 psi, 1st 200 psi recharge = 30 sec's, full recharge = 155 second. 4 battles @ 2150 psi. Gas alarms, PVT alarms and flow indicated tested. Draw down on chokes t11100 psi. AOGCC Brian Bixby & BLM Quinn Sawyer waived witness or test. 9/2/2018 9/2/2018 0.50 COMPZN WHDBOP RURD P R/D testing equipment. 0.0 0.0 15:15 15:45 9/2/2018 9/2/2018 1.00 COMPZN RPCOMP RURD P R/U to run completion. R/U power 0.0 0.0 15:45 1645 tongs, 4-1/2" slips & elevators. 9/2/2018 9/3/2018 7.25 COMPZN RPCOMP PUTB P PJSM. Run 4-1/2" Tenads Blue 0.0 5,135.0 16:45 00:00 wllorque tum to 5,135' (127 jts in the hole) 9/312018 9/3/2018 10.00 COMPZN RPCOMP PUTB P Run 4-1/2" Tanana Blue w/torque turn 5,135.0 12,332.0 00:00 10:00 f/5,135' to 12,332'. (Break circ w/1 bpm @ 60 psi & locate seals @ 12,318) 9/312018 9/3/2018 1.75 COMPZN RPCOMP HOSO P UD 2 jts tubing. WU space out pups. 12,332.0 12,295.0 10:00 11:45 I 1 Bring hanger to rig floor. Page 35137 Report Printed: 91712018 Operations Summary (with Timelog Depths) MT6-08 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Aclivay Code Time P-T-X Operation (MKa) End Deplh (%KS) 9/3/2018 9/3/2018 0.25 COMPZN RPCOMP WAIT T Rig crew not ready for next task. Had 12,295.0 12,295.0 11:45 12:00 to wait for tools & equipment to dg up head pin to landing jt. 9/3/2018 9/3/2018 1.75 COMPZN RPCOMP THGR P RID cement hose & XO's. Unable to 12,295.0 12,295.0 12:00 13:45 make up due to clearance. Remove bell guide on top drive.Still lack of clearance. Install 4' bale extensions. WU hanger & landing joint. 9/3/2018 9/3/2018 1.25 COMPZN RPCOMP CRIH T Line up pump down cement hose. 12,295.0 12,295.0 13:45 15:00 Observe fluid leaking out of XO. Land tubing on hanger & inspect circulating equipment. C/O XO assembly. P/U & inspect hanger seals. 9/3/2018 9/3/2018 2.50 COMPZN RPCOMP CRIH P Pump 29 bbl spacer. Displace to 9.5 12,295.0 12,295.0 15:00 17:30 ppg brine & chase with Cl brine w/5 bpm, 500 psi. (spotted Cl brine VTOL to bottom of SOV) 913/2018 9/3/2018 0.50 COMPZN RPCOMP OWFF P FIC (static) 12,295.0 12,295.0 17:30 18:00 9/3/2018 9/3/2018 1.50 COMPZN RPCOMP THGR P RIH & land on hanger @ 12,295.0 12,326.0 18:00 19:30 12,328.42' (4.26' from fully located). RILDS. Test hanger seals 250 psi 15 min & 5000 psi / 10 min on chart. 9/3/2018 9/3/2018 3.00 COMPZN RPCOMP PRTS P RID head pin. Drop ball & rod. R/U 12,328,0 12,328.0 19:30 22:30 head pin. Test tubing l0 4200 psi & hart for 30 min (goodBleed down tubing to 2000 psi. Test IA to 3300 psi �5 Oak- Oa L✓ & chart for 30 min (good). Shear SOV 2150 psi. Break circ down IT-& tubing w/2 bpm @ 770 psi. 9/3/2018 9/3/2018 0.50 COMPZN RPCOMP RURD P RID cement hose. B/D lines & UD 0.0 0.0 22:30 23:00 landing joint 9/3/2018 9/3/2018 0.75 COMPZN WHDBOP MPSP P Install HP-BPV. Install landing joint B. 0.0 0.0 23:00 23:45 Test in direction of flow 2500 psi for 15 min (good). UD landing joint B 9/3/2018 9/4/2018 0.25 COMPZN WHDBOP OWFF P FIC (static) 0.0 0.0 23:45 00:00 9/4/2018 9/4/2018 0.25 COMPZN WHDBOP OWFF P FIC (static) 0.0 0.0 00:00 00:15 9/4/2018 9/4/2018 0.50 COMPZN WHDBOP OTHR P UD 4-1/2" elevators & bale 0.0 0.0 00:15 00:45 extensions. MID 4" DP elevators. 9/4/2018 9/4/2018 0.50 COMPZN WHDBOP WWWH P MID stack washer &flush stack with 0.0 0.0 00:45 01:15 fresh H2O & safe surf O 9/412018 914/2018 0.75 COMPZN WHDBOP OTHR P B/D top drive, kill/choke, & hole 0.0 0.0 01:15 02:00 fill/bleeder lines. 9/4/2018 914/2018 6.00 COMPZN WHDBOP SVRG P Break ram doors & remove rams for 0.0 0.0 02:00 08:00 BOPE maintenance.. SIMOPS - Clean & clear rig floor. Pull rotary table cover & clean pollution pan & flow box. Remove trip nipple. N/D choke & kill lines. 9/4/2018 9/4/2018 5.00 COMPZN WHDBOP NUND P N/D flow line, hole fill lines & bleeder 0.0 0.0 08:00 13:00 lines, flow box, Katch Kan & MPD valves. RID choke & flare lines. RID choke hose. Rack back BOPE on pedestal. 9/4/2018 9/4/2018 2.50 COMPZN WHDBOP NUND P Install SMS & test dart. NIU tree 0.0 0.0 13:00 15:30 adaptor. Unable to seat properly. P/U It HWDP & set down w/14 k WOB to seat. Secure flange. 9/4/2018 9/4/2018 1.00 COMPZN WHDBOP PRTS P FMC test flange to 5000 psi (good). 0.0 0.0 15:30 16:30 Fill tree w/diesel & lest 250 low & 5000 psi high & chart for 10 min. Page 36137 Report Printed: 9/712018 l arations Summary (with Timelog D,,,,ths) MT6-O8 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depen Sbd Time End Time our (hr) Phase Op Code Acilvlly Code Time P -T -X Operation (flKS) End Deplh(RKB) 9/4/2018 9/4/2018 3.00 COMPZN WHDBOP FRZP P R/U circ lines from tubing & IA into 0.0 0.0 16:30 19:30 squeeze manifold in preparation for freeze protecting with little red. Install mouse hale. 9/4/2018 9/5/2018 4.50 COMPZN WHDBOP FRZP P PJSM. Little Red pressure test lines to 0.0 0.0 19:30 00:00 3000 psi. Pump 282 bbls diesel. Holding 1000 psi back pressure as diesel turns comer. SIMOPS - L/D 4" DP from derrick via mouse hole. 28 stds. 9/5/2018 9/5/2018 1.75 COMPZN WHOBOP FRZP P Cont. to freeze protect with Little Red. 0.0 0.0 00:00 01:45 Pumped 390 bbls diesel. total. while holding 1000 psi back pressure.SIMOPS - UD 4" DP from derrick via mouse. 9/5/2018 9/5/2018 0.50 COMPZN WHDBOP FRZP P Let U-tube for 30 min. 0.0 0.0 01:45 02:15 9/5/2018 9/5/2018 2.75 COMPZN WHDBOP MPSP P Bleed off surface lines. FMC R/U 0.0 0.0 02:15 05:00 lubricator & test U2000 psi (good). Set BPV. Little Red test BPV in direction of flow to 2500 psi & chart for 15 min (good). Bleed off pressure to 1000 psi. Shut in IA & well secure @ 4:45 Hrs Tubing & IA= 1000 psi. 9/5/2018 9/5!2018 0.50 DEMOB MOVE RURD P Bleed off & blow down surface lines. 0.0 0.0 05:00 05:30 Clean cellar, tree & misc tools & equipment off of scaffolding. 9/5/2018 9/5/2018 9.75 DEMOB MOVE PULD P UD remaining 4" DP from derrick via 0.0 0.0 05:30 15:15 mouse hole. (Culled 4 As 14# and 0 Jts 15.7# for hardband). SIMOPS - Pull ball mill away from rig. Replace arctic dump line in pump room. 9/5/2018 9/5/2018 2.75 DEMOB MOVE RURD P Clean pipe racks & cellar box. UD 0.0 0.0 15:15 1800 elevators, longs & misc equipment from dg floor. Remove traction motor from mud pump #1. Cont. to replace arctic dump. 9/5/2018 9/5/2018 3.00 DEMOB MOVE RURD P Work on dg move check list. Cont to 0.0 0.0 18:00 21:00 remove equipment from dg floor for inspection. Cont. work on traction motor & arctic dump line. Blow down H2O & steam lines. Disconnect electric lines. QuadCo calibrate gauges. 915/2018 916/2018 3.00 DEMOB MOVE RURD P Move pits & motors complex & pipe 0.0 0.0 21:00 00:00 shed away from sub. Skid rig floor. Raise support feet. Last drilling report For MT6-08. Rig released @ 24:00 His Page 37137 Report Printed: 9/7/2018 ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-08 Lower Lat 50-103-20772-00 Baker Hughes INTEQ Definitive Survey Report 18 September, 2018 r -j u"v£S .� ConocoPhillips� 4 ........ COf1000P71llIP5 Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. AVNS Project: Western Noah Slope She GMTi Lookout Pad Well: MT64B Welihore: MTfi-0BPBt_Cancelled Desi C2PBl-WP02 Pro)ect Western Noah Slope. Noah Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum one Datum: NAD 1927 (NADCON CONUS) Map Zona: Alaska Zone 04 Well MT640 Local Oo4Ninate persuades: Well W6.08 TVD Reference: Actual MT648@ 8005usfl(Actual DWant9) MD Reference: Actual MT648@ 88.05uM(Actual Delineate) North Reference: Thus Survey Oakulation Method: Minimum Curvature Dataaase: EDT 14 Alaska Production Well Position eNIS 0.00 tuft Noshing: Ground Level: .IDAV 0.00 usft Easting: Position Uncesainty (nT) 000 usft Wellhead Elevation: WellEen MT6-08 Levier Let Magdetlea kbtlel Name Sample Date BGGM201B 71112018 Design MT6-08 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: DepM From IND) (tam 0,00 Mee, Sea Level Using 9a.dnt,. scale fact., 6945.523.29usft 317,00360usfl 0.00usft Declination 1' 18 51 Tie On DepM: 10,283.41 HLS aEfm Imrt) (usft) 0,00 0.00 latitude: 70' 15' 22.749 N Lm.1a.de: 151'28'44.556 W Ground Level: 37.20.im Dlp Angle Mid Stmngth (nT) 60 70 57,4013 Direction 1°) 331.96 911WO18 3 52 08P Page t COMPASS 5000.148uiM es ConocoPhillips �+ ! ConocoPhillips Definitive Survey Report Company: ComPoPhilllps(Alasks) Inc. -MS Local Co-ordinate Reference: Mil MT6-M Project Wesmm Noe Slope TO Reference: Actual MT6-08@ 08.85usR(Actual DOyanl9) SIM: GMT1 Lookout Pad MD Reference: Actual NTB-08@ 88.85usf1(Actual Doyon l 9) Well: MTS -08 North Reference: True Wellbore: MT6-OBPB1_Cancelled Survey Calculation MemM: Minimum Curvature Des1g¢ C2PB1-wp02 Dambase: EDT 14 Alaska Pmdoction Survey Program Dan, .. From To Survey Survey (Msn) (deft) Survey(Welliene) Tool Name Des.Npnoe Smnwm EM Dab 60.00 115.00 1. Gymnam Gyro DMS 16" (MT648P81 GYD-CT-DMS Gyrate. cnnlAnllpipe We 7)15)2018 7/152018 210.38 677.91 2. BHGE MWD+CA+MSA IV"(MTB-OSPB MN/D+IFR-AK-0AZ-SO MA IFR AK CAZ SGG 7/162010 7/162018 771.90 924.00 3. GymCata Gym OMS 16" (MT6-0BPBi GYD-GGMS Gymtlata Viocompassing Ms 7252010 960.17 2,048.15 4. BHGE MWD+CA+MSA 1It" (Iirr"aPB MWD+IFR-AK-CAZ-SO MWD+IFR AK CAZ SCG 7/1&2010 7/1712018 2,084.30 10,283.06 S. BHGE JAWD+CA+MSA 12114 -(MTM MWO+IFRAK-CAZSC MWD+IFRAKCAZSCC 7/192010 72312018 10,328.00 10,435.64 BHGE MWD+CA+MSA6"(MT6-08 Lowe MWD MWD -Sancti &92010 &92018 10,513.25 12,522.70 BHGE MWD+CA+MSA6 x 8 We(MT6-0 MWD+IFRAK-0AZSC III AK CAZ SCC Minolta 31142018 12,596.03 21,073.17 BHGE MWD+CA+MSA 4In" (MT6-0BL MWD+IFRAK-CAZ-SC MWD+IFR AK CAZ SCC 812112018 8129RD18 survey Map Map Nrtleal MD Inc ActTVD Mae +WS +pJy( Nadi Easenp DLS Secgon Survey Tool Name Annotation (Inn) r) 11) teen) loan) foan) (aan) In) (11) flow) (n) W55 000 O.M 3a.55 4.30 000 000 5.945,52123 317,003.60 0.00 000 UNDEFINED 6000 0.55 72.88 60.00 -2885 003 0.11 5,945523.32 317.00351 235 4 c GYGCTDMS DI 11500 0.61 88.69 11500 26.15 0.22 0.63 5945,52349 317.060.24 0.13 4.N GYGLT-0046(1) 11535 0.61 ISOM 115.M Man OM 0.64 5,945,533.50 317.004.24 0.00 4M M IFR -N AZSC(2) 20" 210.30 On 87.34 210.37 1214 0.43 1.75 5,945523.85 317.005.37 030 -0.M MMDNFR-AK-0AZSOt21 301.40 079 &73 30138 21253 0.52 3.00 6,845523.74 317.00 1 0.04 A95 MWD+IFRJJ(-0A2SC (2) 393.91 042 82.05 Wong 311104 062 197 5846523.82 317,007.58 040 -131 IWDAFRAK AZSO (2) 40931 0.37 282.55 48919 40034 074 401 5,945,523.93 317,00763 O.B2 -133 MWD+IFR-AK-CAZ£C (2) 583.84 051 Mei 58181 494.96 082 330 5945.524.04 317,00.92 0.17 -082 MWDHFR-AKLAZ£C (2) 67791 1.34 32148 67]87 589.02 1.73 222 5.945.52497 317.005.86 1.16 040 MWDHFRAK AZSC(2) 771M 1.35 3MM 77183 .,a. 150 0.91 5.945536.77 317,004.59 0.01 Z&t GYPGC-M6(3) 83tW 1.97 3MM 830.91 M.06 485 A13 5,&5.528.16 317003.59 1.05 4.35 GYD-GGM6(3) 924M 275 329.74 923.83 834.98 805 -223 5,915.53140 317,001.57 090 8.16 Gyc-G 04"(3) 990.9 304 328.866 958.95 87110 8.69 -3.20 5,945,53166 317,000.63 1.50 10.06 MWD+IFR- AZ4tC(41 1,05&60 4.75 333.42 i,054.60 116,515 15.54 637 5,945.53098 316.997.81 1.57 16.71 NWD+IFRJJ CAZSCm) 9 ltInVIB 3:52:OBPM Page 3 COMPASS 5040.14 Build BS v: ConocoPhillips % O COIIOCOPhillip5 Definitive Survey Report mm Carllpany: Con.c.PMIbps(Alaska) Inc.-WNS Local Co-ordinate Reference: Well MTB -00 Prpaek Western NorM Slope TVD Reference: Actual MT"B@ BB.BSusn(ACWal Nyanl9) She: GMT1 Lookout Pad MD Reference: Actual MT6S8@ 88.85ush(Actual Nyanl9) Well: MT"B North Reference: True Ylallhem: MT6C8PB1_Canceled Survey Calculation Method: Minimumcerv.W. Design: UPBI- 02 Database: EDT 14 Alaska Production Survey 941&2018 3 U.011 M P., 4 COMPASS 500() 14 Budd 85 Map wm.l MO Inc AadTVO TVDSS +NIS +El -W NaMap Eased,1.11w) OLS setllen sumyTa0l Nama Anl1o!ffiion 0.11) 11) 1'1 loan) (ush) 1 --ft) (..to (R) M 114835 6 33 335.43 40 1,1.45 1,059.60 23.]6 -1026 5,945,54).29 346.16, 983.90 169 25.Bo MWD+IFR-PKLKSL(4) 1,24345 TN 3V.. 13410W 1.15298 00.44 -14.85 5,945.558.06 316,999.59 180 3730 MNDAFR- n4SC(4) 1,335]4 9,05 33].62 1,33olo 124625 46 ]6 -2062 594557054 316.9693 160 5106 MWDNFRJ CAZSC(4) 1,43133 1059 328." 142].31 1330.46 60.6] 3&m 5615,564.fi4 316,9]610 1.. 67,17 MWDAFR- CAZSC(4) 1,525.76 1270 MAI 151918 103094 ]]09 Ja65 5945,60130 31680504 217 6621 "D+IFR-AK-CAZ8C(4) 1619.64 1031 33105 1,611.0 1,52222 9622 4937 5,845.620.68 316,85658 112 100.13 MWD+1FR-AK-0AZ4C(4) 1,71401 15.]4 3W77 110221 1,613.36 117.60 E126 5845,64233 316,94522 152 13259 MWD+IFR- -CAZSC(4) 1,937.87 17,54 33052 1]52.14 1,70329 141,02 -74" 5,945.M 07 316,93261 1.92 15646 MWD+1FR-AK-CAZSC(4) 1931.92 18.98 32SW 1891,45 1,70.60 166.60 .1905 6,845692.05 316.910.62 154 180.91 MMYD+IFRAK-CAL (4) 1.95579 19.48 330.04 193231 1843.,^ 1619] S793 5945.707.56 31691013 0.93 2115.65 M IFR-. CAZSL(4) $01135 tam 320.92 1964.63 1,80.78 188.16 -107,28 5,9451X405 316,901.17 0]0 22534 MAT)+IFR-AWCAZSL(4) 13444-x16" 2,046.15 2012. 329.05 2,01921 1,93336 209.M -11360 5,945.73500 316895.12 0]0 237.91 MWD+IFRrWLPZSL(4) 2,(6430 20,2 328.79 2053.10 1,96425 24903 -119.93 5.945 745N 316.689.08 136 260.49 MWD+1FR-AHLAZ-8C(6) 2.1]9.09 21.50 3M.08 214153 2052., 24831 -03726 5,945,7]564 316,0]243 105 264.50 MND+IFRA CL C(5) 2,2"A1 2225 328.51 2,12904 '1,140.19 2]942 -155.52 5845,80639 316,854.83 075 31933 MWD+IFR-N(LAL6C(5) 236675 23]1 MILO 2.315.16 2,2531 31012 -174.R 5,945.83754 316.MB0 082 35565 MWD+IFR-AH-0AZSL(5) 2,4S0.8] 2010 329.13 240147 2,31262 34247 -193.&1 6,945.87D35 316,81816 1.16 39338 MWD+1FR-FK-0AZSC(5) 2,55255 5.11 35.05 2,40437 2,395.52 375.93 31360 5,945.90420 316199.13 2.11 43225 MWDHFRAK-CALSC(5) 2646.74 27.45 X2318 2557,56 2,478.71 41216 423480 5,94594102 316,]7003 1" 47421 M +IFRAK-CAZSC(5) 2,73893 27,47 32035 1,651.02 2,55217 44955 -2560] 5,945,878.83 316]57,]4 0.21 517.54 M +IFR-AK-CAZSC(5) 283223 27.53 3514 2133.01 26".18 48535 -27550 5846.01624 316737.01 021 560]6 M IFR- -CAZSC(6) 2927.36 27.61 329m 2.81734 2]28.49 52430 40)83 5,945,05171 316,715.61 022 64.17 MJUD+IFR-AKL SC(5) 3,021.6 27,6 32987 2900.64 2,011.99 %205 52294 5045932% 316.694.3 033 04709 M.ND+IFR- CAZSC(5) 3,116.47 27.6 32826 2,90042 2.895.9] 63.05 54523 5.9445 131,53 316,6730 035 69191 MNDAFRAH- -SC (5) 3.211.13 27.67 328.83 3,M,65 2,979.6 6]16 397.84 5,946168.76 316,65138 021 735.82 MWD+1FR- CAZSC(5) 3,304.m Z1.6 320.61 3,1516 3,M(s5 67IN 3640 5046207." 316,4.73 0.11 ]]921 MWD+IFR-AKCAZ4iL(5) 3.39921 2T6 M&6 a 20 3.14535 71245 41319 5,94624553 316,00T87 0,14 823m MWD+IFR-AKCAZSC(5) 3,4936 2783 3552 3,310.6 32580 ]499] 43643 5,946283.59 316,585.90 0.24 65680 MWD+IFRAK-CA24C(5) 3,580,10 29.05 3523 3.401.6 3,31290 7654 45&20 5,846322.71 31656164 1.34 911.88 MWD+1FR-AKCAZSL(5) 366263 32.13 UAW 3.483.19 3,394.34 82990 48304 5,846.X6465 316,54010 35 959.93 MWDNFR-AKCAZSL(5) 37]6]6 3370 329,05 3.562.19 347334 873.89 41006 5946.05.5 316,514.96 1.76 1,011,m MJVLI+IFR-AKCAZ4O(5) 941&2018 3 U.011 M P., 4 COMPASS 500() 14 Budd 85 `-. Conoco ConocoPhillips Definitive Survey Report Company: CDnoc9Phllllp9(Alaska) Inc -MS Local Co-orBinale Reference: Pmjeoe W'estem NOM slope TVD Reference: Site: GMT1 Lookout Pad MD Reference: Well: MT6-08 North Reference: Welflon, MT"BPB1_CanwheE Survey Calculation Methal Design'. C2PB1-wp02 Database: Well MTB -OB Actual MT"8 @ BB 85usfl (Actual Doyan 19) Actual MT648 (P 88.85usfl (Actual Dayton 19) True Minimum Curvature EDT 14 Alaska PmEuhaa B s Map Map Nltical MD (uslQ Ills (1) 4.81 t9 TVD (ush) TVDss lustt) +NS luzfll .8-W lush( Needs, Ea81h OUS VilliDLS Beuren Survey Tool Name Annotation fll (h) lm 3,H109.9 35.06 32915 363905 3,550.20 92062 53802 698456.0 3164M.14 3.27 1,0654.8 MNDHFR-M(-0PZSC(5) 3.964.95 39]9 330.0 3,712.76 3,61 970,69 567.47 5,946,50162 316.45992 318 1,123.69 MWD+IFRAKLP C(6) 4.09.60 43.21 3.29`5 3.783.63 3,61 1,025.43 396,42 5,946562,09 316,430.31 ..1 1,19837 MWD+IFRAK-CAZSC(6) 4,154.32 4615 330.05 3.65096 3.262.13 1,08333 b31.31 5,9436215) 316.398.03 3.15 1,25294 MVW+IFR-AK-04.250(5) 4,246,09 4067 33074 3.91362 3,81 1,142.58 .1.97 5.946.60162 316.30.62 2.78 I.M1.06 MWD+IFR-N(-04.250(5) 4,34108 5162 33D.64 3.973.7 3.885.12 10563 40037 5,945,74550 311 3.13 1393.34 MMA)+l ARCAZSC(5) 4.43515 Si 330.20 4=,61 3,°"1.76 1.270.94 -737.44 5.90.81169 31629130 2.92 1468.42 Mf4DtlFR-AA-04.250(5) 4,52918 56.40 320.95 4,084.04 3,995A. 1,338.32 -775.45 5,946879.98 31626094 Z. 1545]6 MWD+IFR-AK-0850(5) 4.8201 58.94 33153 4,138X1 4,04135 1,407,46 313.61 5,98.00.41 316.224.49 pm 1625.07 MNDHFRJJ(-CP23C(5) - 4,71884 56.94 331.68 4,15189 4,099.03 1,477.70 4ui 5.947.21,15 316,180.45 014 1,704.46 MWD+IFRAK-0AZ3C(5) 4,01353 6712 331.64 42394.6 4,150.61 1,547]0 4881 5,947,48204 316.152.42 0.19 1,78390 MWD+IFRAKLALSC(5) 4,907.03 57.13 331.06 429049 4.20164 161734 -9547 5.947,16246 316.116.75 030 1.851 MWO+IFRiN-04.250(5) 5,000.42 5112 331,32 4,34085 425200 1,665]9 -9630 5.947.231.80 316,081.5 049 1.840811 MODNFR-PH-047250(5) 5.0534 5119 33086 4.392.5 4,32".8 1,75552 -1,0020 5.947,30253 316.044.0 041 2,020.51 MMD+IFR-PI(-CAZSC(5) 5.1a945 5116 330.09 4,443.35 4,354.50 14824.41 -1,01 5,9O,3n.M 316,00122 069 2,0%.65 M Ifl R-PI(-CAZSC(5) 5.28208 57.13 3547 4,4061 440476 1,89165 -108024 5,81148.51 3159®]0 058 2,177.42 MWD+IFR-AK-0AZSC(51 5.375.69 5121 739.513 4,544.45 4,45661 1,95958 -1,12031 5947,50.5 315,931.39 0.13 2,256.16 MW)+IFR--CAZSC(5) 5.470.41 57.14 3555 4,595]0 4,5085 2028.0 -1,160.8 5,947,578@ 315.89284 0.08 2335.52 MWD+IFRAK-CPZSC(5) 5664.62 57.11 35.93 46884 4,557.99 2,0 1 -1202.32 5947 ,08.11 315.854.84 034 241459 MWDHFRAWCRSC(5) 5,656.0 57.17 32)66 468001 4,609.16 2,164.07 -1,240.18 5,94 7717.52 315,916,8 025 249375 MWD+IFRAK-0A2SC(5) 5,753.21 57.fl 35.94 4.749,17 460032 2,23332 -1,28001 5,947 78101 315.77630 OS ZWZ89 MM0+IFR" -SC(5) 5,847.43 57A. 33016 4.80027 4711.42 2,301.90 -1,31953 5,947,856.8 315,740.0 0.21 z6Ci MOD+IFR-PX-04.250(5) 5,884.5 57,15 330.0 4.85.5 4,7318 23500 -1,32".99 5947.88370 315,72566 025 2,68301 MOOAFR- CAZSC(5) 594900 57.18 35,54 4655.35 4.70.50 237598 -1,351.90 5.947.931.51 31569191 0.0 2,737.30 MNDHFRAK-CPZSC(5) 804331 57.9 33122 4,901 4,817,67 2,48.18 -1300.45 5,08,01.63 31568105 061 2,816.50 MND+IFRAK-CALSC(5) 6.13675 55.9 33133 4,95TW 4,86951 2,513.94 -1438.13 5940,017 315,627.0 015 2,094.9 MWD+IFR-AK-04.250(5) 6,51.63 56,9) 3319 5,09,0 4,1121120 2,58396 -1,475.9 5,98,142.19 315,591.0 050 2974.8 MWOdFR--CAZSC(5) 6.35.37 56.97 331.33 5,050.0 4.871.83 2,65303 -1513.61 5,94821300 315.555.0 050 3,05390 MWDHFRAK-CAZSC(5) 6,45.60 56.93 3314.3 5,1120 5,23.22 2,8321 -1,55104 5,9820122 315,510.87 1310 3,132.00 MWDMFR-AK{AZSC(5) 651551 5895 330.76 5.163.00 5,074.98 2,79.85 -1.509.89 59830" 315462.13 U.S. 3.21241 MOD+IPR-N(-04.250(5) 660945 56,95 33023 5215.00 5.1.23 2 a 37 -1,6567 5.98423.21 3154450 OV 3,29112 MOD.IFRAA-04.250(5) 9/1 Bi 18 3:52:01 pope 5 COMPASS 5000 f4 BUBG BS Survey ConocoPhillips ConocoPhillips Definitive Survey Report C..,m, CmwcoPhillipa(Alaska) Inc-WNS Local Coordinate Reference. Well MT6-08 Prefect: Westem NOM Slope ND Reference'. Actual MTB-U886S5us9(Actual Doyanl8) SM: GMT]Lookout Pad MD Reference: Actual MT641888.85us1(Actual DWanlg) Well: MT648 Month Reference: True Wellbore: MT6 BP81 Canceled Survey Calculation Method: Minimum Curvature Design: C2PBI,,02 Database'. EDT 14 Alaska Production Survey Annotation 9/182016 3W08W Pape 6 COMPASS 5000 14 8ulM 85 Map Map Vertical MD Inc AM 1VD TVO83 +WS +044, Northln9 Eaton, DLS Section survey tool Name (Bart) (7 M (Mart) loaf_ (uaill (..ft) rot IDI (°1190.1 ID) 57016 55.94 329.91 529fi19 5,12].34 2,928.44 -1,667 as 5998.49221 315,40151 028 3,.9,62 MWD+IFRJJ4 -SC (5) 6.28832 56,% 32905 5,31041 5X19.26 2,998.19 -0,2083B 5,918.56182 315.368.62 0.75 3,449.35 KMA)+IFRJJ(ZC C(5) 6m8 n 66.90 328,61 5,36962 5,280]2 3,M.95 _249.20 5,918,630.64 315,32951 0.23 3,52834 KAMD+IFR-MK AZ5C(5) 6,90581 5694 33.86 542041 5.331.56 3,132.59 -1,209.68 5,948,69824 315,290.60 0.14 3,60618 MAOHFR-A AZSC(6) 2.08016 WA2 320.08 5,421.95 5,363.10 3,2N.30 -1,830.64 5.948,26893 315,251.36 0.28 3.685.22 MWD -IFR -AI( -SC (5) 2.12426 5691 33912 5,523.26 5,439,41 3,262.80 -1,021.10 5,916.035.46 316,212.56 0.22 3.M3.60 MNDHFR-A AZ -SC (5) 2.50.18 5695 33023 5.524.51 5485.% 3335,05 -1,91022 5,940,90432 315.12455 090 3.842.52 MWDHFRAK-0AZSC(6) 2,368.82 5692 33011 5,65.14 5,53219 3,404.21 -1,908.5 5,848,924.12 315,13675 011 3,921.86 MNDHFRAK-CAZSC(5) 2.455.58 55,91 33050 5,622.5 5,5819,41 3,4896 -0,989.12 5.949043.34 315,aN,57 043 400002 MWD+ffR-AK-CA2£C(5) 2,550.93 5698 =30 5]2612 5639,87 354115 4,05.13 5,949113.05 315.06224 D.26 4,029.42 MWDOFRA-CP C(6) 2.044.24 Mae 33D.41 5.229.85 seen W 3.61010 -2.062.03 5.949,182.32 31505.01 0.10 4,156.03 MAVAFRN AZSC(5) 2,269,64 56.5 330.12 5,831.59 524224 3,62920 -2.10646 5,949.252.35 314.902.28 0.21 4,52.55 MWDNFR-AK-0A SC(5) 2834.35 5694 330.20 5.083.5 5,294.40 3,248.08 4?,14583 5,949,322.12 314lekc. 003 4,31691 MWD+IFR-PHLAZSC(5) 2,928.30 56.86 333.05 5,934,51 5.84566 3,816.21 -2,18,121 5,949.391.21 314912.86 0.59 439521 MrW+IFR-P AZ4lC(5) 002311 56,93 331.18 588616 5,892.31 3.686.9 -2,223.19 5,90.9.48208 314.025.62 029 4.42511 IffiV FRAI(-CAZSC(5) 8.11248 56.08 331.52 6032.61 5,998,28 3,955.60 -2,26100 5.9299.53241 314,033.43 035 4,554,20 MKMD+IFRAK-CAZSC(5) 6,21228 56,94 3315 608933 6,000.48 4,05,42 -2,29882 5,949.603.18 314,003.W 003 4.633,W MFNDHFRJJ AZ4C(5) 930614 6595 331.34 6,14D.n 6051.68 4,084.52 -2,336.53 594965819 314,26T38 019 4212,M IAVD+IFRAKL C(5) 8,400.35 56.95 331,59 5,191.90 6,103.05 4,163.95 -2324.25 5,949.243.44 314,23196 022 4291.28 MWDHFR40(C SC (5) 8.494.58 56,90 33029 6,243.32 6154.42 4,23314 -241230 5,949813.53 314,60800 011 4,820.25 ~+11FR-A"AZSC(5) 6,550.63 57A1 33D.34 6.294.53 620569 4,301,04 -2451.02 5,949603.14 314,667..92 046 4,919.10 MWD+]FRA AZSC(5) 6,682.94 57,02 331.02 6.31518 6,256.93 4320B2 -2,489,04 5,949,85309 314,6504 061 5.05.5 MW➢HFRJ44CA2SC(5) 8nTn 57..15 330.20 6.392.5 6,30043 4,40..29 -2,52082 5,950.023.43 3145113.50 O. 5,10780 MWD+IFRAJK A (5) 8,82143 52.12 329.94 6.446,08 6,359,21 4,508.50 -2,568all 5,950,082.52 314,595.86 0.31 5,186.52 M IFR -A AZSC(5) a area 52.17 ]29.49 6493291 6410.16 4,6M.62 -202.93 5,950,161,86 314,08218 0.45 5,5542 MJUD+IFR-AK-0AZSC(5) 9,05933 52.12 83.39 6549.92 6.461.12 469460 -2.89600 5,294.230.56 314.469.30 002 534425 IAADHFRAK AZSC(5) 9,16482 5714 35.23 6601.82 6,513.@ 4213.86 -2,68818 5,929',30818 314 <33.39 030 5,424,50 MMDHFR-MK AZSC(51 9.24252 57.21 329.52 6652.02 655312 4181.01 -2,M.10 5,950.368.87 314,300 016 5,502.25 MNO+IFRAKL C(5) 9,%369 52.08 329.& 62045 6,615.35 4.05060 -2,268.80 5,9W.439,5D 314.353.63 028 5,582.89 MNDHFRAK KZSC(5) 9,434.. %N 33013 625305 666481 081662 -2008,50 5,950,505,35 31431215 0.30 5050.99 MNOHFRAKLAZSC(5) 952935 57.u1 330,58 685,39 621654 4,88529 1'8463 5,950.52644 31422940 040 5,73654 MWD+IFRAK-CALSC(5) Annotation 9/182016 3W08W Pape 6 COMPASS 5000 14 8ulM 85 ConocoPhillips a"i�ii�DNEs ConocoPhillips Definitive Survey Report Company ConocoPbilipa(Alaska)Inc.-MS local C.Mokate Nelel-M.e: lryY0 MT6-06 Project: Westem NOM Slope Mi Rehlenca: Actual MT658 U 86,05usd (Actual Doyan 19) Sue: GMTI Lookout Pad MD Refemlw: Actual MT648 to 88.05us8 (Actual Dayton 19) Well: MT6-08 Nartb BMcmnce: True Wellbore: MT6.68PBt Cancelled Survey Calcuhtlon Method: Minimum Curvature Design- C2PB1-,,O2 Dabbaee: EDT 14 Alaska Production 97184016 3:52:06173 Page 7 COMPASS 509014 Build 85 Map Map Vertical MD Inc Rai M3 MMS +098 +EI -W Northing Eating OLS Seceon So., Tool Name Annaialion (u -m 11) M (U -M loam (-airy (ustt) IN In) (Y10-) M1 9,6239 5694 330.5 6855.71 6782.85 595455 4,885.W 5,95064513 314,24236 000 5.01740 MWD+IFR-AK-0AZSC(5) 8.91&83 56.94 330.83 6.908.70 6,819.85 5,124.19 -2,924.16 6990.71620 314. 4e7 025 5,89733 MWD+1FR-AK( AZSC(5, 8.013.]8 5890 331.09 6.95047 6.871.62 5.193.26 -289.176 5,890,28218 314,162.90 0.16 5,976.82 MWDNFR-AK-0AZSC(5) 9,096.91 56M 3300fi ],011]1 6,8830 5,262.00 y0M]9 5,950,05.31 314.131.8 013 6,054.90 MWDNFR-0 AzP C(5) 10,600.09 5695 3W.60 2,098.43 6973.50 5,33068 4,0n.n 5,950,98.93 314,094.97 .0.16 6,13365 MN0NFR-P A2SC(5) 10,094.80 5697 33081 7.11368 7,024.83 5,399.43 5,017.73 5.95095.5 314,0918 012 6,212,44 M IFR-M(-CAMC(5) 10,189.24 56.94 330.85 7,10.18 TOMM 5,468.55 5,116.31 5.951,055.09 314,021.26 0.05 6,81.59 M IFR -MK AZSC(5) 10,83.05 M98 33038 7.216.35 7,127.5 5,537.00 5.161.89 5.951 Mutt 313,88426 0.43 6,370,8 MrYD+IFRJJ AZ4iC(5) 10,,32809 56,645 330]7 7,2a0.94 7.152.09 559.04 5.17337 5951,109.24 3138f6.60 0.96 6,407.81 MJr➢(0) 10,37187 559 WSwl 7,55.35 7,17651 5,601.37 $19164 5,951,=3 313,94918 3.99 6,444.23 MWeD(6) 10.435.84 5362 MTQ 7=28 7,21344 5,645.5 5,21901 5.01345.01 3139M90 3.90 6.49510 MJYD(6) 10,51335 52.5 Y16.04 7,3,18.74 7 25 5,097.5 535311 5.51,8764 313,89007 160 6.558.02 MJN+IFR-MK AZSC(7) 1060270 5.47 325.64 749.34 7,3849 6,76139 -3,29&44 5,95136270 313,8,1631 373 6,63473 MWNHFRAKtP C(7) 1070252 60$ 320M 7.45298 7,364.13 6.02533 5,%5.04 595173.21 313.801.28 6.20 6,71437 MNDHFR-AK-0 -SC(7) 10)96.51 .347 322.51 7,497.24 7,401139 5,00.57 41,306,70 5,851,484.28 313]5132 3.91 6,795.3 MNDHFR-AKLA7.SC(7) 10,8905 639 322.15 7,539.10 245025 5,957.33 43,,14293 5,95,562.8 313]01.9 0.19 6,878.09 MWD+IFRAKLA (7) 10.90462 63.4,1 38.5 7,581.05 249220 8.0850 5,97.43 5,951.63100 313.653.80 298 6,962.32 MWDHFR-AKLAZ£C(7) 1107998 64.x9 38.51 76MM 7,53363 6.09865 5,543.52 6,95170385 313,609.46 303 7,0,1610 MWD+IFRAK-0PZSC(7) 1117333 64.42 331.34 25319 7,574.34 6.171.37 5,584119 5,851]78.53 313,57061 5.5 7,13186 MWDHFR- AZSC(7) 11.8275 64.31 33542 7704.04 7,615.19 6,24035 3,620.53 5,951,857.37 313,536.16 075 7,21688 MWD+IFRN A25C(7) 1136275 Man 336.0 7)44.41 7,855.5 6.38,70 41655.79 5,951,9'9.63 313.502.82 1.M 7,302.68 MWD+1FR-AK( AMC (7) 11454.5 0.55 336.87 7.78047 7.691.62 0.404.70 5,689.39 5.952,01533 313.01.13 3A4 7,30225 MWD+IFR-MKLAZSC(7) 8548.07 7144 33574 7,8125 7)23.81 6.405.97 4384.21 5,95208241 313,,13938 307 7,47536 IMV+IFR-M AZSC(7) 110932$ 74.15 335.46 7,8,10 2 7.75167 6,5621 5,700.67 5,952180.52 313,409.85 316 7,56.08 MWD+IFR-AI(-0AZSC(7) 14.M7.M n,m 3aa. 7,83.62 7.77477 6,65134 5,789.33 5,952,84.a6 313,367.21 &70 7,658.53 vnnUAFR-PHLA (7) 11.831.11 8.13 334.70 7.88170 2792.85 6.734.03 4)038.56 5952348.17 313.33001 278 7)4&05 MWDAFR-AKLAZSC(7) 11,92479 8212 335.8 7.88.15 7,097.30 6,8890 -3.077.71 5.952,432.96 31339291 220 7,8400 MWD+IFRIJ AZSC(7) 12,019.14 028 334.92 7.939.02 288.17 6.902.67 5.81208 5,99.51&65 31325561 035 7,93380 MWiHIFRJJ AZSC(7) 12,113.12 028 335.40 7,92173 7,032.,19 6907.17 ySue,. 5,85284.09 313.88.5 0.51 8,08.77 M6D+IFR-AK-CPZSC(7) 12.200.05 8207 335.17 7.931.67 7,845.82 7,03.60 5.995.52 5,9529313 313.101.33 0.31 8120.5 M IFRAK-CAZSC(7) 12,3025 820t 339.97 7,90]6 7,858.91 7,15248 4,OM 97 59977&24 313143.85 022 0,214.12 MND+1FR-AK-0AZSC(7) 97184016 3:52:06173 Page 7 COMPASS 509014 Build 85 ConocraPhillips ComnPhillips Definitive Survey Report ComPany: ConocoPPilips(Alaska) Inc. -KMS Local ralnah Relannocs: Mil MTS -08 Project Wesnru North Slope TVD Rehrence: Actual MT648 @ 88.85us8 (Actual Doyanl9) SBe: GMTI Lookout Pad MD Relerence: Actual MT608 @ 88.85usn (Actual Dayanl9) Wen: %TMS North Relerence: True Wellbors: MT&08PBt CanceOed Survey CalculaWn Meth.d: Minimum Curvature Deaton: C2PB1-wp02 Database: EDT 14 Alaska Production Survey Pannotaldon Wa20Is 3:52A813M Pape 8 COMPASS 5000.14 Build 65 Map Map %lertic.1 MD Inc Act TVD NOSE rW5 +Er4N Within, EastnB OLS Section Sunny Tool ft. (.an) (1) PI hake) (-airy (-M (nam (e) (e) (•1100•) (e) 12397.01 0394 33541 7 95931 7.87046 7.24242 4,07460 5.952.862.12 313,106.40 2.04 8,307]3 MWD+IFR-PK-0 C(7) 12489.53 05.66 33310 7,%7.69 7.878.84 7.325.27 4.11491 5,952.945.91 313063,12 2.77 8,39980 MND -IFR- -C-0 SC (7) 12.52270 %]8 331.97 7,%980 7,.1,. 7,36463 4,130.10 5,952.97564 313053.57 479 8.43289 MWONFRJ ZAZ3C(7) 12.586.03 08.02 33ZM 7,973.21 7,084.36 7,418.30 4,164.44 5,03,0,11.19 313,02068 1]3 650684 MD+IFR-AKLAZSC(8) 12,693.13 ..11 33213 7.976.42 7,807.57 7,5D3.45 4,208.79 5,M,12631 312,978.60 0.16 0,601.19 MWDOFR-AK-CAZSC(8) 12.786.52 0902 332a9 7,979.64 7,890.79 7.587.94 4252.94 5953,211.84 312,93&52 0.59 8,696.52 M +IFR-AKLPZ43C(0) 12.882.38 07.92 333.77 7,9..03 7,894.10 7.67145 4,2%.08 5.95,MST 312,895.47 1.13 8.79228 MWDdFRAK-CZSC(0) 12970.02 88.02 333.63 7886.42 7,097.57 7)59.15 4,33044 5963 ,39,07 33285521 010 0,%7.03 M IFRAKLALu^C(8) 13,073.29 a8.il 333.08 7.989.64 780029 7W1 26 4,38115 5,953,471.16 312.01459 0.56 8.96302 MW1l+IFRAK-CA2SL(81 13,184.05 81.10 33310 799030 7,901.45 7,98.46 44424.38 5,953,55741 312,77344 313 9,070.55 MWD+IFRrV(-CAZSC(8) 13,26ll7 89.33 33341 7959.94 7,901.09 8,01422 4,467.10 5,99,643.18 312732P0 1.89 9,173.44 NOAD+IFR-A AZSC(8) 13,359.60 8909 334.. 7,990.59 7,901.74 8,iWA5 4,5%.90 5,953,730.38 312,893.10 1.62 9,59.19 KIWD+IFR-PA-0AZSC(5) 13455.69 93.M 334.02 700700 7,903.04 8,18709 4,584.33 5953,815.00 31299.79 3.7D 9,355.14 MJNNFR-PNCAZSC(9) 13.55040 94.63 334.41 7,98130 7,MA5 828.15 4.591.43 5,953.%4.04 312.61477 142 9.459.55 MADHFRA-CQ-6C(8) 13"5... 9323 33327 7,974.75 7,885.90 0357.75 4,63340 5,953.9211.. 312,574.03 389 9,554.86 MNDHFRAK-CAZSC(8) 13 ]4011 9280 33260 7,869.76 7,189.91 8,442.13 4.67859 5954076.03 312 531n 0.84 9,64960 MWDNFR- -CAZSC(8) 13,836.5 91.48 331.95 7,..20 7,877.35 8.55.52 4,75.94 5.954.16148 312491.49 1.54 9.744.93 MWDNFR-AK-CPZSC(8) 13.01.15 90.07 33098 7.964.92 7,07607 0,609.85 47M,25 5954.245. 31244021 184 9,83970 MWDHFRAK-0 C(8) 14.026.06 9276 33167 7.962.57 7,8]372 8,693.08 4,011.77 5954,3301fi 312,404.73 293 9,934.64 MWD+IFR-AK-0P C(8) 14,41.49 93.27 33205 7,957.55 7,868]0 5,777.12 4,8%.R 5,9MAI&27 312.51.84 067 10,029.95 MWD+IFRAK-0PZSL(8) 1421654 93.55 332.66 795190 708305 0,86117 4,900.75 5,954.500.36 312.319.88 0.71 10.124.83 M WRdKL C(8) 14312.37 93.9 So 87 7,94594 7,057.09 8,98431 4,944.52 5954.585.43 313,278.19 022 10,220.48 MWDAFRAX-0 C(8) 14.40747 9259 332.96 7,940.@ 7,85197 0030.76 4,98776 5,954,671.99 3325701 1.04 10,31541 MND+IFRJH-0AZSO(8) 14,50245 82.31 33318 7,93578 7,847.91 9,115.35 -5,030]5 5954,757.61 34,196.10 0.38 10,41028 MNOHFR-M-CA-8C(8) 14,59591 9222 33381 7832% 7,844.14 9.20)71 -5.073.32 5954,843.97 312,155.62 0.67 10,84564 MNONFR-PN-04250(3) 14,59376 9238 334.]0 792914 7,640.5 9,286.95 -5,115.19 5.954 931.09 312,115.85 0.55 10,60134 MWD+IFR✓ -C-0 -6C(8) 1470944 9216 3M37 7925.5 7,85.84 9,373.04 5,35656 5.955,018.25 312.07059 0.23 10696.. MND+IFRAK-L SC (8) 1484:0 9257 33462 7.921.44 7,032.59 9.458.63 5,197.40 5.955.104.01 31203704 051 1079161 MWDAFRAK-LAZ4C(8) 14,979.91 0961 am. 7,91962 7,83057 9,545.03 5,238.15 5,955.19217 311.988.21 3.11 10.897.02 MWD+IFR-AB-0PZSL(8) 15,07458 8942 33105 7.800.75 7,83190 9629.62 SSO.ST 5%5,277]6 311.955.86 3.5 10.961.62 MWD+IFRAK-C ZSL(0) 15.169.75 89.25 331.74 794.19 783334 9,71350 5,32555 5955,38270 3fl91593 037 1307500 M +IFR-AKL ZC (0) Pannotaldon Wa20Is 3:52A813M Pape 8 COMPASS 5000.14 Build 65 `. Cono4hillips ConocoPhillips Defindive Survey Report Company: Conocomilips(Aleske) Inc .-WNS Local Coardmate Reference: WeII MTO-08 Profen: Marvin, North Slope ND Reference: Actual MT658088.85usn(Actual Doyanl9) She: GMT1 Walkout Pad MD Reference: Actual MT6-o8®88.85usft(Actual Doyanl9) Well: MT648 North tolerance: True Waltham: MT6.08PBi_C... alled Survey Calculation Method: Minimum Co.U,a Des18n: 021781- P(32 Database: EDT 14 Alaska Production Survey Annotation �FR Q I WRFS 91184018 8.52'Dow Page 9 COMPASS 600014 SuW 0 Me,MAP Vediwl MD Inc AM TVD TVDSS aN-S aev No Mi Ea(111n0 OLS Semon Survey Treat Name (-ft) P) M lush) loan) (ush) (-am Ift) rtl ml 1-11001 hl 15,26502 80.93 332.67 ],92370 ],83485 9]9].]6 5,369.9] 595.448.01 311,873,67 1,03 11,172 G6 MWDgFRAK-0.4251.18) 155999 90.44 332,80 7924.35 7,835.50 8,00221 541340 5,95553149 31183221 1.45 11,267.01 MWDNFR- -CAZSC(8) 15455.0 93.07 361.46 7,824.05 7,835.20 9,957.23 5,45732 5,85561951 311,]603] 0.51 11,35289 MWDHFR-P)t-CAZSC(8) 1555163 W.23 33235 7,923.79 7,834.94 10,052.23 5,501.64 5955?0559 311747.93 038 11,45864 MWDNFR-PI(-CAZSC(8) 15260.10 9060 33323 7923.11 7,834.5 10,13530 5,54511 5955.79050 3119%.2 Ill 11,55310 MNAHFR-N(-0.4250(8) 15.741.0 B4B7 333.54 7,918.56 7.40)1 10,221,37 5.58778 5,9558576 311,666.13 049 11,64633 MINDNIFR-AK-0AZSC(8) 15.83621 .691 334.44 7.960.42 7.4557 10.305.95 5.62SA2 5.85586232 311$16.% 1.50 11.74Z% MrYDHFR-AACAZSC(8) 15,931.5 9505 334.7 7,..11 7,011.26 1038125 5,62020 5,9%4048,% 311,587.79 1,43 11,037.05 WAD+IFR-AK-0AZSC(8) 16.025.07 925 332.86 7.89424 ],86039 10,475.98 5,711.95 59%,13439 311.548.19 375 11931.42 MMD+IFRJ -CA C(8) 15122.00 905 332,90 7,8030 7.803.45 10,561.2 -5.75676 5,95625,87 311,505.47 1.80 12,02752 MJu➢HFR-AKLAZSC(8) 16,21624 89.60 333.45 7,86185 700400 10.645.61 5.78028 5,kSb305.B7 311.468,01 136 12.121.3 MND+IFRAWCPZSCOI 16311.34 88.16 333.31 7,895.13 706020 10.733.61 -5.840.88 59%,381.8] 311.45.49 0,99 12216.8 MNDNFR- -CAZSC(8) 16,405,11 88.91 333,M 7,89755 7,800,70 10,015.11 -5,683.13 5,956,4]].76 31138532 0.91 12,311.0 MWBRffRAK 4rC(8) 16,SO, 84 89.31 334.52 7,89984 7,810.19 10901.3 5,94.90 5,566.56487 31I.MAS 0.92 1240713 MNDHFRAIEC L C(0) 16,598.15 8776 333.89 7901.50 7,812.65 10,98821 5,%8.80 5,9%,851.54 311.30580 194 12503.33 MWD.IFRAK-0.4250(8) 16,692.]] 8682 333.93 790432 7,815.47 ildn 15 S,008.3B 59567W,45 311.2F537 1.12 12,597.0 MWD+IFRAK-CAZSO(8) 16,]07]0 Dam 3%37 7,905.44 7,817.59 11,1595 46,04827 5,9%,02551 311,22658 258 12.692.60 MWD+IFRAECAZSC(8) 16,88287 %23 334.61 7,909.04 7,820,18 11245.82 -60875 5,856,6120 311.18134 IN 12,787.55 MWDNFRd6C C(8) 1.,97713 89.00 332.01 7,91132 7.421.47 11,330.00 5,120.06 5,955,99617 311?%.% 288 12.01.]5 MWDrIFRN(CAZSC(8) 1],0]280 a9.% 331.71 7.912,94 7,824.60 11441444 5,17522 5,957On0 31110,139 032 12977.1 MWDrIFR-N(-0.4250(8) 17,16646 8830 WI.N 7.91498 7,826.13 11,498,37 -,2584 5,95716669 311,06433 077 13.07103 MWDNFR.-CAZSC(8) 17,52.95 8883 331.33 7,9935 7.2a0 11,581.23 5,26622 5,957,25261 311,020.97 0.17 13,187.9 WN),IFR-A1E-0AZSC(8) 17,359.07 8663 331.3 7,919.64 7,030.79 11,%5.58 53125 5,957,338.05 31097.03 010 13,53.0 MW➢NFR-PI(-CA C(8) 17,454& 88.80 33202 7821.95 7.03]0 11.740.72 535751 5957423.5 310.933,81 0,62 13.359.12 MWIHIFRAA-LAL6C(9) 9,5490 Was 33162 7923,05 7,04.5 11,03144 -6.40237 5.957,508.05 3108.1.03 181 13.454.10 MVIDHFR-AK-CAZSC(8) 17.64521 93.44 33275 79WAl 7.01.5 11.917.93 5,44694 5,957.593S. 310,840.% 171 13,54883 MNO+IFRAKSAZ4IC(6) 17)4022 8655 33198 7,910.19 7,82134 12602.36 4t,48939 5,957,99.01 310,00831 553 13,644.05 MNOHFR-AN-CAZ50(0) 17,050 9673 34451 7.897.94 7,860.09 1207.48 $53035 5957,785.10 310969.60 251 13,]38.48 ~+IFRAK-CAL C(8) 17.831.22 9296 33,124 7.89029 7,801.44 12,173.47 $571.60 5957,852.06 310.730.0 342 1303.77 MWOIFR-N4CAZSC(8) 10,02531 83.0 334.01 7,80.3] ],]95,52 1225011 5,61261 595].9375] 310.691.15 05 13.827.67 MWDNFRAK-C ZSC(0) 18120.8] 9112 334.74 7,88024 ]99,39 1234405 565387 535602438 310 fi51.90 0.7 14523.00 MWD+IFRAKS CS) Annotation �FR Q I WRFS 91184018 8.52'Dow Page 9 COMPASS 600014 SuW 0 CxioCo hfflip5 Conccolthillips Definitive Survey Report Company: ConocoPpillips(Alaska) Inc-WNS Local CoarUlnafe Reference: Well MT6-D8 Project: Westem North Slope ND Reference: Actual MT64DS 0 089Sush (Actual Doyanl9) Sge: GMT)Lookout Ped MO Reference: Actuel MT6S8®00.85..%(Actua1 Doyanig) well: MT648 North Reference: Time Wellbore: MT6.09P81 Canwlled Survey Calculation Method: Minimum Curvature Design: C2P01-wp02 Database: EDT 14 Afaske Production Survey Bi 4 9/182010 3 52: 08PM Page 10 COMPASS 5000.149udd 85 Me, Map Widened MD Inc Act TVD TWSS HWS HFJaY Northing Easing OLS Section Survey To.[Nam. Annotation IM.ro Ih 17 IM+ID loam ryes( aan) (R) (N) Iv10P) MI 18,216,% 92.83 332,51 ],8]5.20 ]]08.43 12429. S6%3] 5,9WIl. is 31061163 235 14,11852 MWDHFPJ CPZSC(6) 183119 91.02 aslant ],0]1.44 ],]0259 4,513.20 -,740.40 5,958.195.05 310,569.61 1.24 14,21305 MWD IFR-AKCAZSC(8) 1840].5] 69.12 332% 7,870.65 ],]91.80 125%.61 -,78523 5.9%,28224 310,526.86 2.90 14,309A3 MWDHFR-PHCAZSC(0) 18,502.80 8805 33418 7,872.16 ],]83.31 12,683.98 882740 5,958368 fA 310,485.79 2.24 14,404.60 "D+IFR-PSCA (8) is %a.02 87,83 383,92 ],8]527 ],]06.42 12.]]703 S,ss&26 5,9584%.61 310,440.06 190 14,50065 M IFRANC4!OZSC(8) 10693% 8758 33347 ],8]9.54 ].]90.69 12,85600 6,909.35 5950.542% 310.409.04 157 14,594% MND+IFP-AKCAZSC(0) 1070902 80,51 331.78 7052" 710.92 lZ"0]] 5953.24 5,958,628% 310.36722 203 1414001 IMYD+IFR-AKCAZSC(8) 18,88337 Ba. 332.85 7,88484 ],]85.99 13,02429 5,99].0] 5,959,71292 310,32544 1.21 14,784Y3 MWDHFR-AKCAZSC(8) 10,97863 90.14 33175 7885% 7,7M.81 13,10863 -,041.35 5950,75830 310,283,23 1.W 14,079.90 MDHFRAK-0A C(8) 19,074.21 90.38 330.% 7885.28 ],]%.43 13.192.% -7,087,16 5,9W.883.3D 310239.47 0.85 14,975.59 MWD -IFR -N1 SC(8) 18.169.37 %.11 33123 7 884.59 ]19514 13,275.84 -7,133.12 5,958.967.68 310195.55 036 15,0]0]1 "DHFR- AZSO(8) 18,264,21 90.22 33301 7631.05 ],]9520 13,359.66 -7,1"46 5.959.052,55 310,153.5 189 15.165.54 MWDHFR-AHCA2SC(5) niasa50 905 333,95 7,883.% 779481 13,411,93 -7,2501 5.959,13882 310.112.80 099 15,5079 M IFR-AK-CAZ p) 19 ,0.540 9001 333.70 7.883.44 ]]94.59 13,53045 4,5198 5,09,22531 310,072.92, 0.31 15,35601 MJrl3+IFRJ OoZSC(8) 19,550.10 Said 332.51 7,884.12 7,79527 13.61550 -7,305.04 5.958311.40 310,"71.95 1.59 15451.32 M4d1+1FRAK-CAZSC(8) 18845.00 ago 33302 7805.8 ]l%.8] 13,70065 -0,340.86 5,959,39258 3[8,9905 061 15 6,1707 MhDHFRAK-0 SC(8) 19.]40.8] 91.55 311." 7,885.35 7,]%.50 13,70600 -7,39053 5,959,483.91 309,950.63 3." 15,61199 MWOHFRAKCAZSC(9) 19,83553 %A] 335,01 ],80159 7,7RK74 13,871,98 -0,429.94 5,959.5]0.(12 309,913.32 119 15,73640 MWD+FRAKL -SC(8) 19,93017 91.76 33587 7,8".63 7,78038 13.959.01 -7,46828 5.959 Sol 30B.B7l.fl 1.58 15,03129 MWD+1FRAI(-CPLSO(8) 5.638.5 9111 3330 7.875.24 ],]8.538 14,88682 -7,5%51 5,958]0521 309,838.03 342 15.92660 Mr4D+IFR-N(CA pi) 5.120.67 9198 33169 7,07270 7183.85 14,129.]9 -],551.13] 5.959 031.10 30879259 210 160209] MND+IFRAKCA26C(8) 5,215.07 9209 328.61 Tilde 2 7,78047 14,211.90 -7,599.32 5,959.914.73 309.752.5 324 16,116% AMOHFRAK-CA2SC(8) 5.31182 9140 332.94 ],86623 ],]]]40 14.295.57 -7,641 5,959,901.51 3%,707W 4.% 16,21191 MWD+IFRJJ AZSC(8) 20,406.% 89.14 335.23 7,055.01 7"8.95 14,38086 -7687.57 5.9W.0557a 308660.14 3.45 16,3%.6] MWOHFRAK ,SC (0) 20,5020 87.59 333.77 ],%&56 ],779.]0 14,46720 -7,728.75 5,960.9309 309.629.07 223 16,402.5 MWDNFRAKCAZSC(8) 20.597.52 87.0 333.12 7,67215 7,78390 14,55224 -],]715 5.960259.13 309,588.66 0.72 16,497 26 MWD+IFR-PX -SC (8) 2O.M.2 9103 332% 7,874.06 7,7855 14,65.66 -7,81154 5,%0344.5] 309.5044 391 16,592.12 MND+IFR-P ,i ZSC(8) 5187.46 Mum 333% 7.869.06 ],]8021 14,72727 -7,85748 5,960A30.20 3p85%.% 4.31 16.60699 MWD+IFR) Z4 SC(8) 5,88289 95M 333.55 7060,68 7,77183 H,MAG -T,89919 5960516.32 30],483.0 005 16182@ MNMD+IFR-AACAZSC(8) ID,97B65 955 331.99 7hSZ12 T.M.27 14,89120 -7943.43 5,%0,60216 309.1240 163 16,67].0 MNDAFRAKCAZSC(8) 210]3.9 9523 332.58 7,84353 T754.60 14,974.53 -796721 5,9 Wow. 309,383,03 0.62 1897151 MWDHFRAKCAZSC(8) Bi 4 9/182010 3 52: 08PM Page 10 COMPASS 5000.149udd 85 Survey ConocoPhillips Definitive Survey Report Local CocNinah Reference: TVD Reference: MD Reference: North Reference: Survey Calculation McIDuB: Database: Mn Inc AA TVD TI DSS 0M8 Eim Map (usn) N (1) (wn) (ustqlusty) (usnl Nanning til 21.10200 95.23 33258 ]94090 7752.05 1500002 000043 5 9f 712.31 Well MT5-o8 Actual MT6-08 ® 88.05usn (Actual Doyanlll) Actual MTB -08 C 88.85usn (Actual Doyant9) Tout, Minimum Curvature EDT 14 Alaska Production Map Vertical Easting DLS Secflen Survey Tool Name Int Plour) (n) 30'37043 Oo0 17,00022 PROJECTEDOTD Annotation Pmjection to TO Wfamis 952.98PM Page 1f COMPASS 5000.14 8.085 ConocoPhillips Compaoy: ConamPIWIipe(Alaska) Inc.-WNS Pm)ect: Madam Noon Slope Site: GMTI Lookout Pad wen: MT6-08 We118om: MTB4)8PBt_Canceletl Design: =PBI- 02 Survey ConocoPhillips Definitive Survey Report Local CocNinah Reference: TVD Reference: MD Reference: North Reference: Survey Calculation McIDuB: Database: Mn Inc AA TVD TI DSS 0M8 Eim Map (usn) N (1) (wn) (ustqlusty) (usnl Nanning til 21.10200 95.23 33258 ]94090 7752.05 1500002 000043 5 9f 712.31 Well MT5-o8 Actual MT6-08 ® 88.05usn (Actual Doyanlll) Actual MTB -08 C 88.85usn (Actual Doyant9) Tout, Minimum Curvature EDT 14 Alaska Production Map Vertical Easting DLS Secflen Survey Tool Name Int Plour) (n) 30'37043 Oo0 17,00022 PROJECTEDOTD Annotation Pmjection to TO Wfamis 952.98PM Page 1f COMPASS 5000.14 8.085 ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-08PB1 Lower Lat 50-103-20772-70 Baker Hughes INTEQ Definitive Survey Report 18 September, 2018 BAKER JUGHES GE —,,d, V �iS.4.31�lW!! Company'. CorecaPhlllps(Alaska) Inc. -MS Project: Westem North Slope Sue: GMT1 Lookout Pad WO: MT6-08 Williams: MT6-OSPB1 Canceller) Design: D2P61-wp02 project Wasiem Noun Slope, Noun Slope Alaska, United States Map System: US Stale Plane 1927 (Exact solution) System Datum Geo datum: NAD 1927 (NADCON CONUS) Map Zene: Alaska Zone 04 WeD MT6.08 Conocolphillips Definitive Survey Report Local Doondl.m. Reterence: Welt MT6-08 ND Reference: Actual MT6-08 ® 88,85usg (Actual Doyen 19) MD Reterence: Actual M76-08 @ 88.85usn (Actual Doyant9) Nunn Reference : True Survey calculation Method: Minimum Cumture Database: EDT 14 Alaska Production Well Pesi ion .NIB 0.00 usn Northing: .FFYi Dissident .Ei-W 0.00 usfl Easting: Position Uncertainty 0.00 usfl Wellhead Elevation: Missiles. MT6-0SP81 Lower Let esprwtln Modelfill Sample Who BGGM2018 7/1/2016 Design MT64)8PB1 Audit Note.: Version: 1.0 Phase: ACTUAL Vertical auction: Depth Froare [M) (gen) 0,00 Mean Sea Level Using geodetic scale factor 5,945,523.29usfl 317,003.60,10 0 09o.fl Deegnagon 1°) 16.51 ll! Latttude: 70.15' 22.749 N Leagued.: 151°28'44.555 W Ground Level: 37.20 usfl Dip Angle VI 80.70 Te On Depth: 36.55 .Nie .FFYi Dissident (wnl lum) 1°1 0.00 0,00 331.89 Fkld Strength ron $7,400 9Ha2018 3:50'59PM Pa, 2 COMPASS 5000.14 Bkohd 0 ConoeoPhillips 14 tag 4 COnocoPhlllips Definitive Survey Report Compeer.. Conocoftilips(Alaska) Inc. -MS Local C..ninam Rapine.. MH MT"a Project: Mstem North Slope TVD Reference: Actual MT"ll Q 88.85uefl(Actual Doyanl9) See: GMTI Lockout Pad MO Reference: Actual MTB -08 @ 8885u0 (Actual DDyan19) Well: MTB -0B North Reference: Tve Wellbore: MT6-08PB1_Cancelled Survey Calcubti0n Method: Minimumeuvature Design: C2PBI- p02 Radio..: EDT 14 Ali Preducli0a Surveyp"pen DeN From To some, Survey (ua t) (daft) Supply (Milhore) Tool Name Deputation Siad DeM End Date 60.00 115.00 1. Gymdata Gyro OMS 18"(MT6-0BPB1 GYD0.CT-0MS Gymdata wntdnllpipe Ws 7/1512018 7/152018 210.38 677.91 2. BHGE MWD+CA+MSA 16"(MT648PB MWD+IFRAKCAZ-SC MWD+IFR AK CAZ SCC 7/162010 71IW2018 771,90 924.00 3. Gymdata Gym OMS 16"(MT646PBI GYD-GC-MS Gynodats Wmwmpassin9 We 71252010 (1n 960.17 2,04845 4. BHGE MWD+ +MSA 16"(MT6-08PB MWD+IFRAK-CAZSC MMAFRAKCAZSCC 7116/2018 711712018 2,084.30 10,28386 S. BHGE MWD+CA+MSA 121/4'fMT64 MWD+IFRAK-CAZSC MMAFRAKCAZSCC 71192018 712312018 10.387.04 11,43059 fie. BHGE MW0+CA+MSA6 x 8314"SDL MWDNFRAK-CAZSC MWD -IFR AK CAZ SCC 7232018 71312018 Survey Map Nip Wlthad MD Inc AM TVD TVDSS +W4 +FJ41 No Eatinp OLS Section Survey Tool Name Anndtetidn (USM M (') (ualt) (daft) (dam (-am (it) ( (R) ( (1n ( owl (1n 36.55 000 OW 36.55 52.30 O[O 000 5945,5238 3A,L03fi0 000 0.00 UNDEFINED 60.00 055 72,W 6000 -2885 0.03 0.11 5,945,523.32 31700371 2.35 -0.02 GYMT-0MS(1) 115.00 0.61 6866 1159 26.15 an 0.63 5,9A5,5M,49 39.0004 0.13 411 GYDLTDMS(1) 11535 081 68.68 11535 28.50 am 064 5,945,52350 31T.M.24 9.00 -all MD+IFR-MA MSC(2) 20' 210.38 0.78 87.34 21037 12152 043 1.75 5945,523H 317005.37 0.30 -0,45 MWDHFRAK AZ-SC(2) 30140 0.79 84.73 301M 21ZW 052 300 5,945,50,74 3170W61 0.04 -0.98 MWDHFRA 4AZSC(2) Me, n42 82.05 393.89 30504 0,62 300 5,945 M,82 3174007.59 0.40 -IS2 MWD+IFRAK-0 C(2) 489.21 037 28255 48819 400.34 0.74 4.01 5,945.50.93 317007.0 OAS -134 MWDNFRAWCPZSC(2) 58384 D.51 273.65 583.81 M. 0.82 330 5945.52904 317,00692 017 -0.83 plAD+FR-AW ,SC (2) 677.91 LN 323.48 677.97 589.02 173 222 5,90.5,5X.97 317,045.88 116 0.48 M IFRAKLA2SC(2) 771.90 135 32329 7183 68298 350 0.91 5,80.5,58.77 317,04.59 n01 2.00 GYDi MS (3) ' 831.0 187 32238 800.91 742.06 4.00 -0.13 5.945.52816 317=59 1.05 4.35 GYD-0G4S(3) 924.00 2]5 32974 923.83 83498 am -223 5,945,531.40 317001,57 0.0 8.16 GYDGG14S(3) 850,17 3.29 328.86 95505 87110 969 SXI 5945,53308 317,00063 1.50 10.08 MWDHFR-A AZSC(4) 1,05506 4.75 333.42 1.054E0 M75 1554 b37 5,94553805 316,99761 157 16,71 MNDHFRAK-Cr C(4) 1,14935 6.33 33543 1.19845 165960 2376 -10.28 5,945,547.29 316,993.00 1b9 Step MWDHFRAKCPZSC(4) 1,243.45 786 33792 1241.83 1,15298 3444 -14.85 5,945,55808 316989.59 186 3737 MWDHFRAK-0AZSC(4) 1,338,74 9.05 333.92 1,334.10 1,24525 46.76 -20.82 5,9455N.X 31698393 168 51,05 MWDHfRAKCPZSC(4) 9/182018 3:50:59PM Patio 3 COMPASS 5000.14 Bob 85 C0170i4Plillips Conocolthillips Definitive Survey Report Company: Con .o0PhIlllps(Ahaka) Inc. -MS Local Coa76inate Reference: VMbll MT6-08 Prole.: Msfem North Slope TVD Reference: Actual 1475.8®9e.e5usn(Actual Ooyanl9) she GMT1 Laakout Pae MD Reference: Actual MT6-o8®8815ush(Actual Doyanl8) Well: MT64e North Reference: True Wellborn. MT6ABP61_Cancelled Survey Calculation Method Minimum Curvature Design: C2PB1- ,02 Database: EDT 14 Alaska Production Survey Annotation 134i78" A 16• 110 "Wale 3:SO:ww Page 4 COMPASS 5000.14 6udd 65 Map Map Veelcal MD Inc And TVD TVDSS aNfg .0411 NotlMny Easdnp OLS Section Survey Tool Name 1 uMD 19 1'1 luslll luslry luso ) luso) m) In) (-tied.) (n) 1,431.33 IC% 326,44 1.427.31 1.338. 60.67 Q&98 5,945,584.64 31607610 1.69 6717 MWD+IFR-A(-0AZSC(4) 1,525,76 12.70 330.41 1,519.79 1,430.94 77M d8,65 5945.601.30 316.96984 2,27 66.21 MWD+IFR-AKLPZSC(4) 1.61964 14.31 331.05 1,611.0 1,522.22 96112 19,37 5945.620.88 316,65959 1.12 108,13 MWD+IFq-Al(-0gZSC(4) 1,714.01 15.74 333.77 170221 1,613.36 11760 51.26 5,945.64233 316,945.22 1.52 13259 MND1JFR-AK-LAZ-aC(4) 1,63767 1754 333.52 1792.14 1,7MM 141.02 -7444 5,945.65,07 316,932.61 192 1594n MND+IFRAK-CAZSC(4) 1,931.92 Was 329.99 1.691.45 I'M60 16560 A906 5,945602. 31891&tit 1.54 188.91 MINC.IFRAK-CA C(4) 1.995.79 19'. 330,04 1.932.31 1,64346 181.97 57.61 5,945707.56 315,91013 093 206.65 MM)+IFR-AA- SC (4) 2011.35 19.85 32a.w 1.964.63 1,895.78 198.16 -1072) 5945 )2199 316,901,17 OM MS.34 MNDHFR CAZSL(4) 2,04815 20.12 32.85 2,01921 1,930.36 209.0 -11360 5,945.73503 316,895.12 0.70 237al MWD+IFR-PHLAZ4C(4) 2,WAO 2082 299]9 2,0310 1,954,25 219.0 -119.93 5,945,746.05 316.689.0 1.38 250.49 MNONFR.AKLALSC(5) 2, 1M99 21,M 329.09 2141.53 2,02.0 24931 -13738 5,945.77584 316,67243 1.0 264.58 MD+IFR-MI CAZSC(5) 2.27341 22,25 32&51 22M.94 2.14019 27942 -155.52 5.M.80,39 31685493 0.75 319,73 "DHFR--CAZSL(5) 2,36575 MAI 32&. 2,315.16 2226.31 31012 -174.29 5,945,WITS! 316,SX90 0.92 355.0 LIWD IFRAK -sc(5) 2,46097 24,18 32943 240147 2312.62 342.47 -19363 5,945,87035 316,818.16 1.16 393.40 MND+IFRAK-0PZSL(5) 2,5255 2511 329.50 2484.37 2395.52 375.0 313.68 5,945,90426 316,799.13 2.11 432.27 MND+IFR-A4CALSC(5) 2.645]4 27.45 32.76 2.57 .5 2,478.71 41216 -234.90 5,945.941.02 316,776.. 1.44 474.22 MAD+IFR-A(-0AZSC(5) 2,73990 27.47 329.35 2,65L02 2,562]7 44a56 -2:6.87 5,945,978.93 316,757.74 021 51758 MWO+IFR-PA-0PZSC(6) 283223 27.53 329.74 2.733.01 2,644.16 481,35 -278,50 5.946,016.24 316.73701 921 MG,21 MWD+IFRAK-LAZEC(5) 2927.35 2761 329.32 2817.34 2,Man 524.30 .300.1 5,946.04,71 316,71561 OM .4.20 MWDHFRAI(-CAZSC(5) 3.021.63 27. JM.97 2,90184 2611.99 56205 422,94 5,946,69299 316694.43 0.33 647.91 MMH)+1FRAK AZ4C(5) 3.115.47 27. 38,26 2964.82 289597 W. 345.23 5946.131.53 316,673.08 035 691.94 RMDAFR-AWLAZSC(5) 3.211.13 27.67 3ffi6l 3.053 So 2,979.80 637]6 36784 5946,169.76 316,651.39 021 73565 MWDNFR-Pl(-0AZSL(6) 3304.. 27.69 32861 3.15150 3,02.65 67190 391140 5,946307.44 316.629.73 &11 77924 MJJDHFR-0 AZSC(5) 339921 27M 328.89 3235211 3.14635 71245 413.19 5,946245.53 316.07.87 0.14 B30 MAbIFRA-CAZSC(5) 3493,50 27.63 326.52 3.318.0 3,2M.. 749.97 -036.00 5,946,28359 316,585,96 0.24 866.94 MWOHFR-A14LAZ4IC(5) 3,588,10 29.0 329.23 3.401.63 3.312.96 769.54 -059,26 5,946329.71 316.5064 1.34 91192 MWD+IFR.-CAZSC(6) 3,68263 32.13 370.36 3,403.19 3,394.34 829.90 4084 5,946.36485 316.540.10 326 999.87 MWD+ffR-AN-CAZSC(5) 377670 33,78 329.06 358.19 3,4.434 873.89 510.0 5.94,40928 316,514,0 1,76 1,011.13 M4MDOFRAK-CAZSCIS) 3,87999 3865 32915 3.E9.05 355920 92061 338,02 5,946,456.0 316408.14 327 1.0553 MND+IFR-. 4lC(51 3,964.95 3Snl San'. 3.712.76 3.62381 970.. 5 7..47 5946.507.62 316.45992 316 112374 MWD-IFR-AIA 4C(5) 4,059.60 43.21 33076 3,7063 3694.78 1,025.43 59842 5,946 562.89 319a30,31 364 1,156.43 MWDAFR--CM-SC (5) Annotation 134i78" A 16• 110 "Wale 3:SO:ww Page 4 COMPASS 5000.14 6udd 65 C000cc Phiufps ° ConocoPhillips Definitive Survey Report Company'. C*mxxaPSIIIIpe(AIa,A) Inc,-WNS Prated: Wealem NAM Slope Sde: GMT1 Lookout Pad Wall: MTB -0e Welthom: MT648P01_Cancelied Deal9n: C2PB1-,02 Survey Local Coordinate Reference' ND Amman. MD Reference'. NoMN Reference Survey Calculation Method: Database'. Wa0 MT6-08 Adds MT6-08@ 8065ustt(Actual Doyan 19) Actual MT6-08 @ 88.85us0 (Actual Doyan 19) True Minimum Curvature EDT 14 Alaska Production Annotation 911SQ018 3 S 59PM Page 5 COMPASS 500014 Build 05 Map Map Vertical MD lusnl Inc 19 /W 1'1 Wall)lusnl all Miss W4 lural +EI -W lustt Nonni" Estill., DLS (•"Da) ,Kc6en gurvey Tool Wme (R) Ira Ira <,15432 46.15 330.5 3.850. 3.762.13 1083.33 531.31 5,846,62157 316.390.83 3.15 1,25300 MWD+IFRANLPZSC(5) 4.246.89 40.67 330.J4 3,913.62 3.2077 1,142.56 560117 5.846601.62 316.360.0 2.70 1,321.12 MWDOFR- uCA!SC(51 0%108 5162 33064 3973.97 3,80.12 1,20563 -700.37 5,946,745.50 316,332n 3.13 1.39340 MW➢+IFRN4cA25C(5) 0.43515 SAM 330X1 4,03].61 3,941.76 1,270.94 -73744 5,946,811.69 31629730 2.92 1,468.48 MJv➢HFR-N(LPZSC(6) 4,52818 55.40 330.95 4.054.04 3.99519 1,33832 -77545 5046879.98 318,26094 229 1,545.83 M +IFR- -CAZSC(6) 4,624.11 55.94 33153 4.IW.20 4,047.35 1.407.88 513.61 5946,850.41 316224.49 076 1,625.14 MNOHFRAK-C L (5) 4.718.84 56.94 33160 4,10769 4,088.03 1.47170 -851.36 5,947.21.15 316,186.45 014 1,720.53 MWD+IFRAKCAZSC(5) 4,013.0 5712 331.64 4,239.48 4,15061 1,50.70 589.10 5,947.09204 31615242 0.19 1,]84.05 MWDNFR-N,-CAL9C(5) 4,807.0 STT 331.66 4290.49 420164 1fi1724 -02847 5,90,16246 31611615 020 1.0300 MWD+IFR3-CAZSC(5) 5,00042 57.12 331.32 4340.85 4,25200 1,68579 863.55 5,847231,0 M6,DB1.M 049 1,84083 MWDHFR-PKCAZSC(5) 5.095.24 5719 330.88 4392.28 4,3043 1755.62 -1002.06 5,947,302.53 31604455 0.41 2,020.58 MND+IFRJJ4 ,SC (5) 5.18945 57.16 330.09 4.44335 4,354.50 1.824.41 -1,04107 5,90.372.34 315.00722 089 2,058.72 VMD-IFR-AK-CA2SC(5) 5,26208 51.13 3X.0 4,49381 4404.76 1,891.65 -1080.24 5,90.440.51 315.9511,70 056 2,17149 MWD+IFR-AK-0Ai! C(5) 5,375.0 57.21 329.58 4.544.46 0455.61 1858.58 -1.12031 5,947.5(1 315.93138 013 2,25824 MWDHFR-AK-0AZSC(5) 5,47041 574 329.5 4.585,10 4,`✓)i 2,MCS -1,16045 5,90,520 .82 315,09284 0.08 2335-81 MWDHFRAK-041SC(5) 5.54,62 5711 3M9w 4,645.84 4,557.99 2,016.41 -1,200.32 5941,818.11 315,854.64 au 241467 MWD+IFRAK Ai!SC(51 5,658.93 5717 3260 4,69601 4,605.16 218187 -1,240.18 5,94171152 315.816.48 025 249384 MWD+IFRJJ( -SC (5) 5,753.21 5711 328,84 4,749.17 4,fisi 223332 4,260.01 5,947.786.81 315,71630 o.W 25nall MbD+IFRA-CAL-SC(5) 5.841.43 57.19 30516 1803.27 4.71142 230190 -1,319.53 5,90.85.43 31574047 021 2.52.10 MND+IFR-AH-0A2SC(5) 5.88035 57.15 330.05 Acco30 4,73145 2,320,80 -1,311.0 5,94].88370 315.72566 0+5 2,0311 MNO+IFRAK-CAZSC(6) 5,94600 57.18 333,54 4,655,35 4766,50 2.375.98 -1Mt99 5,90,931.51 315,699.91 0.83 277.40 MWD+IFRAKLA (5) 6.053.31 5705 Ml,T 4.90652 4817.67 2,44548 -1,400.45 5,948,05163 315.0305 061 2,81661 MWD+IFRAK-CA (5) 6,13675 5699 33133 4.99.36 4.868.51 251394 -1,436,13 5,948.07137 315.62105 0.15 2,895.00 MWONFRJ CA C(5) 62]10 5.99 331.99 5,059.05 4,720.20 ]56196 -147590 5.948.14219 315,59105 058 2974.51 MWDAFR-AWCAZSC(5) 6.3M.37 56.91 331,33 5005,0 4,9710 2,65308 -1,513,61 5,940.21300 31555.05 am 3,05000 MNDAFRA AZ6C(5) 8,42060 5693 331.43 5,112.07 502322 2723.21 -1$5144 5.946,28322 315,51681 0.10 3.IM98 MNDOF&PKCAZSC(5) 6.515.51 56.95 330.75 5163.84 5,07499 2792.85 -1,589.89 5,940.35377 315,48213 0.59 3,212.52 MND+IFR- CAZSC(5) 6.60945 56.99 311.23 5.21508 512023 2,0137 -16M.9 5,90.42331 315.445.0 047 3,291M MND+IFR-AK-CAZSC(5) 6.70316 58,94 38,91 5.20.19 5177.34 292944 -166788 5,948.492,21 315407.51 029 3,359.74 MNDHFRAKLAZSC(5) 8,798.31 56.96 3M.05 5.31811 5,828.26 0,996.19 -1,70830 5,940,56182 315,368.67 075 3,449A7 MWDHFRAK-0CL C(5) 6,89276 Susa 326.61 5,369,62 5.287.77 306595 -1149.20 5948630.64 315320.51 023 3528.46 MWD+IFR-AK-00.25015) Annotation 911SQ018 3 S 59PM Page 5 COMPASS 500014 Build 05 Conoeophiliips ftt( FR_ • Cmot:8�hll Ips Definitive Survey Report T�'�'� Comeshow ConocoPMllips(Abuka) In.. -VMS Local COardinate Relnaace: MlIMT6-00 phei VVeslear North Slope TVD Reference: Actual MTB -0B@ 8885uafl(Actual Oayanl9) Set CMT1 Lookout Pad MD Reference: Actual MT"S@ 88.85uaS(Acival OoyaR19) Walk. MT84)B N0n8 Reference: True WellSom MTS4)BP01 Canceled Survey Calculation Method Minimum Curvature Dedi CVSI1 avp02 Oauease: EDT 14 Alaska Production Map Map Vertical MD (Mato Inc Act TVD TVDSS +WS rV1w Monti, Said, CLS Seaton SMrvey Thal Meme Annotation PI 19 (-am (ua0) 1 -raft) (oan) m) (R) 171100) Int 6.985.81 5684 328.88 5420.41 5,331,56 3,132.59 -1,]8966 5948698.24 3152. or 014 3606.31 MAD+IFRA"CK C(5) 7,000.26 Sam 32087 5,471.95 5,383.10 3,210.30 -1,830.64 5.940.766.93 315251.36 028 3,6NN MND+IFRAKLAZSC(5) 7.94.26 %.91 328.22 S"imm 5,434.41 3,26788 -1.871.10 5.948,835.46 315,2125 0.22 3.76401 MNWIFRAKCAZSC(6) 7,50.18 %.95 330.23 5,574.51 5,485.66 3,335.85 -1,810.]] 5,948.904.37 315,174.55 090 3,64266 MN➢NFR- CAZSC al 7,38.07 50.97 326.11 565.14 5,537,26 340.71 -18%.5 5948.974.17 315,130]5 all 3,922.00 W1JDHFRr AZ4lC(5) 74%,% 56,91 330.% 5,6]726 5.58041 344MN -1,989.12 5,848,043.34 315.099.57 as A00a51 LfiNDHFR-PI(-CAZSC(5) 7550.93 56% 30.30 5]5.29 alsWi] 3,541.75 -2,028.13 5,948,1130 315.052.24 028 4,09.57 MNOHFR-AK-CAZSC(5) 784414 W.% 339th 5.779.05 5,691.00 3.61026 d%].03 5,949.10232 315,025.01 010 4,158.19 MWD.IFR-A -SC (5) ],]38.61 50.% ma17 5.831.59 5,]42.]4 3,679.0 .2,1%46 594926235 31498726 021 4,23771 MNDHFRAKC]SSC(5) 783.N 55.94 3305 5.881.26 5,70.40 3}48.08 -214593 6,949.322.17 314.0849 0.3 4,31707 MND+IFRAKC C(5) 792838 %39 3WIS 5,934.51 5,045.0 3,016.71 -2,184.71 5,949,39111 314,81239 0.59 4.395.87 MAD+IFR-AKLA2 C(5) 8,023.11 Seas 33110 5,985.16 6,80.31 3,8%.17 -2,223.19 5,919.462.9 31,87552 0.29 4.475.27 MND+IFR-M-0AZSC(5) 8,117.48 56.% 331.57 8,%]83 5,948.78 3,95560 -2,26103 5,941 314,839.43 035 4.564.36 MND+IFR-N(LPZSC(5) i� ..212]8 5894 331.% 6088.33 6,000,98 4,05.47 -228092 5,841 314,803.33 003 AMM MYDNFR✓ -CL C(5) .,30.14 5895 331.31 614pS3 6.051.68 4,094.57 -2336.% 5,949.8]39 314.767.9 0.19 4,71219 MADHFR-AK-CAZSC(5) 840.35 56.% 33,59 6,191.90 6103.05 4.10.95 -23]4.25 5,949,743" 314,31.38 am 4,791,45 MWOHFRAKC C(5) 8.49458 5'eW 330,9 6,213.32 6,154.47 4,233.14 -2,41230 5,949,81353 314,6%.% 071 4,870.41 MADHFR-AK-CAZSC(5) 0585.63 57.11 33031 6294.53 atD5.68 4,30161 -3.45107 5.949 803.14 314,657.92 046 4,84827 MVD.IFRA CAZSC(6) 8.68,& 57.07 331.02 6,345.78 6,2%.93 4370.87 -2,489.84 5.810.953.09 314.65.0 0.61 5,02843 MAD+IFRAK-CAZSC(5) 8,177]5 57.15 330.28 6,38728 6308.43 4,44029 -2,528..7 5IS0.023.43 314.583.50 0.% 5,108.05 MWD.IFR- ACAZSC(5) ' 8.871.43 5717 328.84 6.448.06 6.358.21 4,50.50 -2568.0 5,%0092.57 314.545.% 0.31 5.116.69 WAD+WRJH AZSC(5) 8,%5.40 579 328." e4%.0 6,41016 4,SM,67 -2,0793 5.950.161.69 314,%7.78 045 6255.60 Ma-1FR-M-CAZSC(5) 9%8.33 57.12 33aR 6,549.97 6.461.12 4,644.60 1.648.% 5,950.230.% 3N,N&W ads 5,34443 MYD+IFR.K -SC (5) 9154.97 STT 329.73 60,87 6,513.02 4,713.86 Q68870 5,950,30018 314,430.30 0.30 542469 MWOHFRA-CA!-SC (5) 9,2475] 5721 35.4, 0652.07 6%3.22 4,781.01 -272810 5,90 units 314,39203 0.16 5,%245 MWD+IFR-AI4CAZSC(5) 9.343.64 57% 32984 870.5 661535 4.8%.% -216880 5,950,439.60 314,353,63 0.28 5.%3.08 MIDAFRAK-0AZSC(5) 9.439.N %.04 33013 0,]53.% 6,60.81 481062 -2.806,90 5.993,509.35 314,317.15 0.30 5.659.19 MWDHFR-AK MSC(5) .,88.36 57.01 330% 6,806.39 6716.84 4,9%.]8 -2845.26 5.B%,SM." 3143]9.48 0.40 5,73875 MN➢+IFRAKLALSC(5) 983.53 564,1 330.55 6,85611 6,76].88 5,054.55 -2,885.0 5OWS4613 314.242.,9 0.0 5,817.68 kNJo+IFR--CAZSC(5) 9,7188 Seat man 6.90810 6819% 5.124.19 -2,924.16 5,8%,]1610 314,20.97 am 5.W7.% WND+IFR-MHCAZSC(5) 9,813]9 56% 33,0 6.96047 6.8]1.62 5.19370 -2962.80 5,9%,]8].18 314167.% 0,16 59]].13 MYOHFR-AK SC(5) 9/182018 3'50'59PM Pape 6 WMPA iS 500014 Sued 85 r, ConocoPhillips COnocAPhillips Definitive Survey Report Company: COn..Phllllpb(Alsske)Inc-MS Local con7dnile Reference: Prot..: mouth Nodh Slope MReference: She: GMTi Lockout Pad MD Reference Well: MT"B NORh Reference: Wellborn: MT6-08PB1_Cance1letl Survey Calculation Method: Design: C2PB1-wp02 Database: Well MTB a Actual MT6498 @ 08.05us8 (Achial Doyanl9) Actual MT6 8 Q 88.85usf1(Aclual Dayanl9) True Minimum Curvature EDT 14 Ateska Production Vertical Section survey Tool Name Iftl 605519 MAiDrIFRAK-CA25CI5) 6,133.87 h IFR -AK SC(5) 6.21266 MMDAFR-AK SC (5) 6,2161 MWDHFR-PH SC (5) 6,37043 MWDHFRJJ CAZ C(S) 8,399.98 MAiD+IFRAK-CAZSC (6) 6,457.5 MADOFR-N({p2SCht 6,454.14 MADaIFRAKL'AZSC nn 6541.25 MMDAFR-PH. SC (6) 6621.00 MWDHFR-N(-0AZSc l6) 8,699.40 MWDHFRAKC C(6) 6,718.59 MADOFR-AWDA2S0(6) 6857.90 MAaDNFR-AK-C ZSC(6) 6,93765 MNDrIFRAK{P (6) 7,01132 MM3+IFRAKC -SC (6) 7.900.87 MWD+IFRrW-CAZfiC (6) 7,183.90 MWDHFR-PH-0 C(6) 7,267.63 MWDHFR-MKCAZ C(6) 7356.10 MWDOFFAK-CA,SC (6) 1,469.59 PROJECTED CTO Annotation 5-518" x 12-114" 928710103:5 WF%# Pagel COMPASS 5000148uiM 85 Map MD Inc AM TVD MEM sW4 vm hp No Easing DES (-am (1) P) (bafll (use) (Nam (nanl (re) (e) fnoo'1 9.906.91 5596 330.861 7,01121 6922.38 5,26200 ],000.]9 595Q655.31 31,13172 0.13 10imo,80 56.5 330.65 7,06243 697358 5,330.68 4.03922 5,850.925.93 314,094.97 019 10,004.80 56.97 330.81 7,113.60 7,024.83 5,39943 S,077.73 5,950,995.56 314,050.1 012 10,10924 56.94 330.86 7,165.18 7.07633 5,466.55 4,116.31 5,9510651 314.021.26 0.05 lo,203.05 5895 33038 7,216.35 7,127.50 5,63708 3,154.89 5.951135.04 313,984.36 04,3 1031835 5674 330.60 7,235.61 7,146]9 54563.00 3.169.42 5$51.161.11 31387045 0.95 10307.04 Shun 331.20 7.273.63 Times 5,61291 3.197.22 5,951,211.87 313,94308 095 10.395.31 56.P 330.82 7,270.11 7,18876 5,61693 4.20055 5,951,21197 313.940.70 367 10.487.00 56.77 32sel 7,32.14 7240.29 5.609.02 -3,2863 5,951,2.45.96 313,904.5 1.06 10,583.20 56.R 33140 7,381.45 7,29360 5,755.46 3,277.86 519513565 313,865.73 1.11 10676.90 58h 331.1 7432.91 7,344.06 5,024.14 -3,315.71 5,951,425.80 313830.57 0.W 10.771.46 57.5 33058 7401.43 7.39550 5,893.30 3.354.31 5,951,495.97 313 71M ON 10.655]9 5733 33053 T55.46 7,446.91 5,96236 -3,393.31 5,951,565.90 313)56.5 0.12 10,210.47 5752 33055 7,56645 7,497.60 6,03184 3,43254 5.051,16.37 313,710.02 0.2 11,54,40 58.5 32911 7,93630 7,54715 6,10006 3,472.19 5,9517ol 313.650.65 1.19 11.140]9 61.46 332.14 7683.61 7,594.76 6,mDa .7511.85 5,951 ]78.66 313,1290 3.95 11,2M.22 6L50 33261 77268. 7,63005 6,247.43 -3,5$181 5.951,051" 313,E0s. 3.27 11,335.83 67.57 33268 T.71.1 7,675.19 84321.63 3,590.2 5.851,029.89 313.55607 3.31 11430.59 70.53 333.5 7.797.92 7,709.07 6,40R" 4i65.60 5.952.009.66 313.5E979 317 1155100 70.53 33325 7,838.90 7.74931 650193 4,681]0 5.52,11224 313.481.17 0.00 Vertical Section survey Tool Name Iftl 605519 MAiDrIFRAK-CA25CI5) 6,133.87 h IFR -AK SC(5) 6.21266 MMDAFR-AK SC (5) 6,2161 MWDHFR-PH SC (5) 6,37043 MWDHFRJJ CAZ C(S) 8,399.98 MAiD+IFRAK-CAZSC (6) 6,457.5 MADOFR-N({p2SCht 6,454.14 MADaIFRAKL'AZSC nn 6541.25 MMDAFR-PH. SC (6) 6621.00 MWDHFR-N(-0AZSc l6) 8,699.40 MWDHFRAKC C(6) 6,718.59 MADOFR-AWDA2S0(6) 6857.90 MAaDNFR-AK-C ZSC(6) 6,93765 MNDrIFRAK{P (6) 7,01132 MM3+IFRAKC -SC (6) 7.900.87 MWD+IFRrW-CAZfiC (6) 7,183.90 MWDHFR-PH-0 C(6) 7,267.63 MWDHFR-MKCAZ C(6) 7356.10 MWDOFFAK-CA,SC (6) 1,469.59 PROJECTED CTO Annotation 5-518" x 12-114" 928710103:5 WF%# Pagel COMPASS 5000148uiM 85 Cement Detail Repoli MTG-08 String: Conductor Cement Job: DRILLING ORIGINAL, 7/14/2018 12:00 Cement Details Description Conductor Cement Cementing Start Date 2/6/201674:00 Cementing End Date 2/6/20161600 Wellbore Name MT6-08 Comment Cement Stages Stage # 1 Description Conductor Cement Objective I Cement Conductor Top Depth (ftKB) 36.6 Bottom Depth (ftKB) 115.0 Full Return? No Vol Cement... I Top Plug? No Btm Plug? No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 ReportPrinted: 9/24/2018 a I Cement Detail Report MT6-08 13 & String: Surface Casing Cement Job: DRILLING ORIGINAL, 7/14/2018 12:00 Cement Details Description Surface Casing Cement Cementing Start Date 7/18/2018 07:15 CementingEnd Date 7/18/2018 1100 Wellbore Name MT6-08 Comment Cement Stages Stage 01 Description Surface Casing Cement jObjective Cement Surface Casing Top Depth (ftKB) 38.0 Bottom Depth (ftKB) 2,010.6 F Retum4 N Vol Cement... 55.0 Top Plug. Yes " Btm Plug? Yes " Q Pump (nit (bbl/m... 8 Q Pump Final (bbil... 4 Q Pump Avg (bbl/... 6 P Pump 440.0 Final (psi) P Plug Bump (psi) 1,000.0 Recip9 Yes Stroke (ft) 20.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill out Diameter (in) 12114 Comment 55 bible good cement to surface ` Cemeld Fluids & Additives Fluid Fluid Type Lead Cement Fluitl Description Estimated Top (ftKB) 38.0 Est Bim (ftKB) JAMount 1,510.0 (sacks) 1,040 Class LIteCRETE V mead (bbl) 24.8 Yield (ft/sack) 1.92 ✓ Mix H2O Ratio (gal/sa... 16 88 Free Water (%) Density (lb/gal) 11.00 Plastic Viscosity (cP) 258,000.0 Thickening Time (hr) 4.40 Cmprstr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Tail Cement Flufd Description Estimated Top (ftKB) 1,510.0 Est Btm (ftKB) 2,010.6 Amount (sacks) 350 Class G umped (bbl) 72.7 Yield (ft /sac) 1.16 Mix H2O Ratio (gal/sa... 5. Free Water (%) Density (Ib/gal) 1 15.80 Plastic Viscosity (cP) 145,000.0 Thickening Time (hr) 4.01 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 111 ReportPrinted: 9/24/2018 Cement Detail Report MTG-08 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 7/14/2018 12:00 Cement Details Description Cementing Start Date Cementing En Date Date Wellbore Name Intermediate Casing Cement 81030 7/26/201810 30 7/26/2018 14:15 MT6-08 Comment Full returns through job, plug did not bump, Floats held. Cement Stages Stage # 7 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug. Btm Plug? Intermediate Casing Cement Intermediate 9,330.0 10,330.0 Yes Yes as Cement casing O Pump Init (bbl/m... Q Pump Final (bbl/... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 3 8 6 600.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Plug did not bump, Floats held. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Lead 9,330.0 9,830.0 100 G 39.0 Cement Yield (ft/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP)Thickening Time (hr) CmprStr 1 (psi) 2.31 13.02 12.20 23.7 5.10 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) I Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Tail 9,830.0 10,330.0 222 G 46.0 Cement Yield (ft' /sack) Mix H2O Ratio (gal/sa... Free Water I%) Density (Ib/gal) Plastic Viscosity (0) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.0 1 129.0 5.00 Additives Additive Type Concentration Conc Unit label Page 1/1 ReportPrinted: 9/24/2018 r Cement Detail Report MT6-08 String: 7 Liner Cement Job: DRILLING ORIGINAL, 7/1412018 12:00 Cement Details Description T' Liner Cement Cementing Start Date 8/16/2018 04:00 Cementing End Date 8/16/2018 0715 Wellbore Name MT6-08 Comment Cement Stages Stage # 1 Description T' Liner Cement Objective I Cement Liner Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug.. Btm Plug? 11,158.0 12,469.0Yes No No D Pump Init (bbl/m... 2 O Pump Final (bbl/... 1 O Pump Avg (bbl/... 2 P Pump Final (psi) 650.0 P Plug Hump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment 62.2 bbls of 15.8 ppg Cement. CIP = 7:10 Hrs yJ GQL ,Se- AI Cement Fluids & Additives Fluid Fluid Type G-blend Tail Fluid Description Estimated Top (ftKB) 10,502.0 Est Btm (ftKB) 112,469.0 Amount (sacks) 301 Class G Volume Pumped (bbl) 62.2 Yield (Wlsack) 1.16 Mix H2O Ratio (gal/sa... Free Water I%) Density (Ib/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) 5.75 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 111 Report Printed: 9/24/2011 Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax 03-20772-00 Delivered to: AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 .41. Anchorage, AK 99501 E57Z-00003 I Greater Mooses Tooth I MEMORY I Cement Eva]-SCMT :1 TRANSMITTAL 25 -Sep -18 TRANSMITTALp FINAL FIELD T nsmittal Recei . ptl. I A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X package have been verified to match the media noted above. The rint a Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy too hlumberger and CPAI. point. Alaska PTSPrintCenter@slb.com Tom.Osterkamp@conocoohillips.com SLBAuditor- -'U Weekly Progress Report 9/4/18 Well: MT6-08 Field: Lookout API: 5010320772 Hole Depth vs. Day 10,000 u 5 10 15 20 25 30 35 40 45 50 Day Report Start Report End Oats Date General Remarks Ia924Hour Summry 8/27/2018 8/28/2018 No AIS. Camp on High Line @COS. Rig RIH with BHA #14 to shoe. Cut/slip,install MPD, Displace to 9.2 FP RIH to TD, CBU, 12:00 AM 12:OOAM on High Line. DOPE Tested 8/20/18, drill ahead Alpine Clateril to 18,535'MO, 7,873' TVD. Dalry loss to formation=40 bbl, 775 bbl cumulative, 8/28/2018 8/29/2038 No AIS. Camp on High Lina@ CDS. Rig Continue geostearing In lower Alpine C lateral f/28,535'to 20,019' MO, 7,876' NO 12:00 AM 12:00 AM on High Line. DOPE Tested 8/20/18. Daily loss to formation=220 bbl., 995 bbl, rum ilative. 8/29/2018 8/30/2018 No AIS. Camp on High line@COS. Rig Condnue geosteering in lower Alpine C lateral f/20,019- to TO of 21,102' MD, 7,841' 12:00 AM 12:00 AM on High Line. DOPE Tested 8/20/18. TVD. Circ & cond. Rack bad 1 stand Per B/U to 20,960 - 0,960'O/AB=100 D/A B = 100psi/OAC=2W psi Dally loss to formation= 196 bbls, — 1191 bots cumuledve. 8/30/2018 8/31/2018 No AIS. Camp on High Line @COS. Rig Circ hole clean for 4.5 BN. Displace to 9.5+vis brine. Strip OOH f/20,626' to -0. 12:00 AM 12:00AM on High line. DOPE Tested 8/20/18. Pulling tight Wash in hole to 19,579'. BROOH f/19,S79' to 18,055'. Com hole clean for 0/AB=100 psi/OA C•20 psi 2D/U. Strip OOH 1/38,055'to 12,435'. Circ hole dean. Dally loss to formatbn= 220 bbls, 1411 obis cumulative. 8/31/2018 9/1/201812:00 No AIS. Camp on High Line@CDS. Rig Cont to circ casing clean. Strip OOH to 4,735'pull RCD bearing St install trip nipple. 12:00 AM AM on High Line. DOPE Tested 8/20/18. POOH &L/D BHA. RN toren 4-1/2"liner. Run liner as per to lly to 7,993' O/AD=100 ps1/OAC=O psi Daily lou to formation= 71 bbls,1482 bbl.cumulatiis. 9/1/201812:00 9/2/201B 12:00 No AIS. Camp on High Line @COS. Rig M/U SCMT tools& liner hanger packer. RIH liner on OP to 20,350'. Hang liner &set AM AM on High Line. DOPE Tested 8/20/18. packer as per Baker POOH& Cement Bond Log to 9,950'. Slip& Cut drill line. POOH O/AB=300 ps1/OAC=0ps1 L/O DP Deily loss to formation- 23 bbl,,1505 bbls cumulative. 9/2/201812:00 9/3/201812:00 No AIS. Camp on High Line @ CDS. Rig Cont. to POOH & L/D DR L/D liner running tools & SCMT. Test DOPE. R/U to run AM AM on High Line. DOPE Tested 9/2/18. completion. Run 4-1/2 upper completion m 5,135' O/AB=110 psi/CIA C=O Psi Daily loss to formation=47 bbb,1552 bots cumuledve. 9/3/201812:00 9/4/201812:00 No AIS. Camp on High Line @Cos. Rig Cont. to RIH wAubing to 12,294'. MN hanges, landing it& head pin, Displace to 9.5 AM AM on High Line. DOPE Tested 9/2/18. ppg Mbrine w/ Corrosion Inhibitor. Land tubing on hanger@ 12,328'. Test hanger O/AD=100 psl/OAC=10 art seals, tubing &IA. Set BPV&test. i/C Daily lou to fswun =26 bbls, 1578 bblscumuladve, ziS-o4g Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, August 30, 2018 10:20 AM To: 'Polasek, Tom G' Subject: RE: MT6-08 Weekly Progress Report 8-27-18 Thanks Tom... so MT6-08L1 is dropped. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 1 or (Guv Schwartz@alasko.aov). From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Monday, August 27, 2018 1:06 PM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Mutasim Elganzoory <melganzoory@blm.gov>; Jessie Chmielowski <jchmielowski@blm.gov>; Quinn Sawyer <gsawyer@blm.gov> Cc: Doyon 19 Company Man <doyonl@conocophillips.com> Subject; RE: MT6-08 Weekly Progress Report 8-27-18 om Please find the attached Weekly Well Progress Report for MT6-08, dated 8-27-18. Reminder: attached days vs. depth chart still shows the original duel lateral, but the well has been changed to a single lateral and should be finished in -10-11 days. Thank You and please let me know if you have any questions, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, August 03, 2018 2:30 PM To: 'Polasek, Tom G' Subject: RE: MT6-08 (PTD 218-048) 7" SDL Liner Stuck, Fishing and Plugback Operations Tom, As per our discussion you have approval to proceed with cutting 7" and abandoning the well section as proposed below. BTW.. good job on the provided wellbore schematics that are very clear and concise on your plan forward. The abandoned hole section should be named -PB1 and use API suffix of -70. All OH and directional data should be captured under these. Good luck with the rest of the program... if there are issues pulling the liner contact me by cell phone this weekend. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC(, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ( or (Guv.schwartz@alaska pou). From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Friday, August 03, 2018 11:44 AM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: MT6-08 (PTD 218-048) 7" SDL Liner Stuck, Fishing and Plugback Operations Hi Guy History: • On Tuesday July 31s` 11:30pm we had a BHA tool failure and had to trip out of hole for new tools • We ran back in and latched up to our 7" liner • Last night we were not able to free liner and lost all circulation after we had been able to circulate up to 5 BPM • We released from liner at 1:45 am Current Ops: • Stripping out of hole and preparing for fishing and plugback operations Path Forward: 0 Continue to strip out of hole • RIH with CIBP cement retainer and set inside 7" liner, ^200 ft below 9-5/8" shoe • PU casing cutter and HRDE liner running tool (will latch into top of liner after casing cut) • RIH to —150' below 9-5/8" shoe, cut 7" liner, slack off and latch into top of liner, Pull -1450' ft of liner to surface o Contingency if can't pull liner: • Release HRDE tool from liner • Come up into 9-5/8" casing ('50 ft) and re -cut. • POOH (cant re -latch with HRDE after release) • RIH with new HRDE • Latch 7" liner and pull out of hole with 1250 ft of liner • RIH with Spear, spear liner and pull out of hole with —200 ft of liner • RIH with Cement stinger and place 17 ppg KO plug on top of CIBP to up inside 9-5/8" casing • Perform Full BLM BOP test, forecasted to be "Aug 7`h at the time • RIH with 8.75" Motor KO BHA and KO • RIH with SDL Number 2 and drill to TD in the Alpine C Sand I would like to speak with you regarding our cementing plug back and kick off and sidetrack. Please see attached proposed cement plan schematics. We have no open hydro carbon bearing zones. We are currently forecasted to RIH with a casing cutter tomorrow Saturday—1500hrs and pump cement KO plug Monday 0200 hrs. I will follow this email up with a call. Thank You Guy, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com MT6-OgwpO6B P&A Schematic Auci 3rd. 2018 20" 94# H-40 Welded Conductor to 115' __... .............. 13-3/8" 68# L-80 x BTC -M 2,011' MD / 1,984' TVD Top of 7" Liner 9,030' MD 9-5/8" 40# L-80 BTC -M Liner TOC - 9330' MD Lead w/ 2040ft 9-5/8" 40# L-80 Tenaris UP HS on TOC - 9817' MD Tail bottom .......... I ........... 1 10,318' MD 17,236- TVD i ...... i Casing Cut - 10,477'MD 152' Below Shoe 15.8 ppg Class G Cement to -16,000' MDRetainer- 10,542' MD i 224' Below Shoe Bottom of 7" 26# L-80 Tenaris Blue Liner 11,434' MD ............................ i I I I Bottom of 8.75" hole (UR blades 67.26' back flbit, closed reamer at 11,546) � I 11,479' MD Bottom of 6" hole 11,550' MD MT6-OtswpO6B P&A Schematic Aua 3rd. 2018 Top of 7" Line= 9,030' MC TOC - 9330' MD Lead TOC - 9817' MD Tail 100' Cement L inside Shoe 1 15.8 ppg Class G Cement to -16,000' MD Bottom of 7" 26# L-80 Tenaris Blue Liner 11,4 .....34...' ...... MD............................ Cement outside shoe Bottom of 6" hole 11,550' MD 20" 94# H-40 Welded Conductor to 115' ...................................... 13-3/8" 68# L-80 x BTC -M 2.011' MD / 1.984' TVD 9-5/8" 40# L-80 BTC -M Liner wl 2040ft 9-5/8" 40# L-80 Tenaris TXP HS on bottom 10,318' MD 17,236- TVD ,-asing Cut - 10,477' MD - 152' Below Shoe Retainer - 10,542' MD - 224' Below Shoe . Bottom of 8.75" hole (UR blades 67.26' back obit, closed reamer at 11,546) 11,479' MD GMT1 MT6-08 wp06B as of 8-03-18 Stuck 7" liner schematic 20" H40 Welded Qondudor 116 ........................................... IS" Open Hole 2,0 1 MD66984'ND (Actual) Top of 7" Liner 9,030' MD HRZ 10,419 - 10,480' MD Top Kalubik 10,480' MD! xxxx' TVD Bottom of 7" 26# L-80 Tenaris Blue Liner 11,434' MD ........................................................ TOC - 9330' MD Lead TOC - 9817' MD Tail 112-1/4" Open Hole 9-5/8" 40# L-80 BTC -M Liner w/ 2040ft 9-5/8" 40# L-80 Tenaris TXP HS on bottom 10,318' MD / 7,236' TVD Bottom of 8.75" hole (UR blades 67.26' back obit, closed reamer at 11,646) 11,479' MD ...1 ................_.._......._...._.__.............. Bottom of 6" hole 11,550' MD MT6—OtswpO6B P&A Aua 3rd. 2018 Top of 7" Line, 9,030' MD TOC - 9330' MD Lead TOC - 9817' MD Tail i i 15.8 ppg Class G Cement to -16,000' MD i i i i Bottom of 7" 26# L-80 Tenaris Blue Liner i 11,434' MD I I I I 1 I I I Schematic 20" 94# H-40 Welded Conductor to 115' 13-3/8" 68# L-80 x BTC -M 2,011' MD / 1,984' TVD . ........................ 9-5/8" 40# L-80 BTC -M Liner w/ 2040ft 9-5/8" 40# L-80 Tenaris TXP HS on bottom 10,318' MD / 7,236' TVD I Casing Cut - 10,477' MD -- i - 152' Below Shoe i Retainer - 10,542' MD - 224' Below Shoe -' Bottom of 8.75" hole (UR blades 67.26' back flbit, closed reamer at 11,546) 11,479' MD _ I Bottom of 6" hole 11,550' MD Weekly Progress Report 8/6/18 Well: MT6-08 Field: Lookout API: 5010320772 Hole Depth vs. Day 10,000 14,000 U b lU lti LU Ln 3U d] 4U 45 SU Day Report start Report End Date Date General Remarks Last 24 Hour summry 7/27/2018 7/28/2018 No AIS Camp on High Line@ Install T' casing spool, re -test packoB.N/U BOP, set test plug.(SIMOPSFlush and FP 12:OOAM 12:00AM CDS. Rig on generators@annulus.) Mange rams and test HOPE. Pull storm Packer, Set wea r ring, M/U&3/4" 05:307/9/101-Irs. HOPE Tested BHA e3, RM to 8,418'MD. 7/27/18. 7/28/2018 7/29/2018 No AIS. Camp on High Line @ Drill out 9-5/8" shoe tack rathole and 20' formation. FIT to 14.0 ppg. Drill 58' mote 12:00 AM 12:00 AM CDS. Rig on generators Whole for SOL pilot assy. C&C, POOH to 32'. 05:50 7/9/1814n. HOPE Tested 7/27/18. 7/29/2018 7/30/2018 No AIS. Camp on High Line@ LID BHA 13,P/U6" Autotrak inner BHA 44, stand back. P/U and run 7" TN Blue. M/U 12:00 AM 12:OOAM CDS. Rig on generators@ inner BHA, space out. PIH with SOL BHA a4 to 3,642' MD. 05:307/9/1BHm. HOPE Tested 7/27/18, 7/30/2018 7/31/2018 No A15. Camp on High Line@ Continue RIH to 10,043'MD. PI5M,Change Put Oynamatic electric bake. Install MPO, 12:00 AM 12:00 AM COS Rig on generators RIH to 10,408' MD. Drill to 10,468' MO, 7,318' TVD. _ (15:307/9/18Hrs. HOPE Tested 7/27/18. 7/31/2018 8/1/201812:00 No AIS Camp on High Line@ Drill ahead 6"%8-3/4" SDI f/I0,468' to 11,537'. Rotary stalled @ 11,530' & lost 12:00 AM AM CDS. Rig on High Line. HOPE communication with directional tools) Trouble shoot communication with directional Tested 7/27/18. tools & stand pipe pressure loss. 8/1/201812:00 8/2/201812:00 No AIS. Camp on High Line@ Cont. to trouble shoot DTF&blind drill to 11,5501. No success with communication AM AM CDs. Rig on High Line. HOPE with directional tools. Wt up to 11.1 ppg. StrIpOOH as Per MPD to 2,605'. Pull RCD & Tested 7/27/18. Install trip nipple. LID flow dlvero r & quick conned. POOH w/4" DP & nick back in derrick. LID BHA 84 8/2/201812:00 9/3/201812:00 No AIS. Camp on High Line@ LID BHA a4. M/U BHA R5. RIH to 8,815'. Install RCD bearing. Con. to RM to 11,548'& AM AM CDS. Rig an High Line. HOPE latch up with liner Attempt to work liner free S, move liner up hole to 11,5351 Circ & Tested 7/27/18 cut mud wt to 10.5 ppg Attempt to move liner. Pack off. Liner stuck in hole with no circulation. 8/3/201812:00 8/4/201812:00 No A15. Camp on High Line@ Attempt W pin circulation & work liner free with no success. Drop ball &release from AM AM CDS. Rig on High Line. DOPE liner. Liner shoe 11.494'/ TOIL 9,030'. Circ& mnd mud to 10.5 M. F/C. Slip &cut drill Tested 7/27/18. line. F/C. Wt up to 10.8 ppg. Strip OOH to 2,510'. Pull RCD bearing & install trip nipple. LID flaw cgu ner & Uner run tools. POOH to BHA. 8/4/201812:00 8/5/201812:00 No AIS. Camp on High Line @ LID BHA k5. M/U cement retainer BHA. RIH to 10,542'& set. Circ B/U. Install RCD AM AM CDS. Rig on High Line. HOPE bearing. Strip OOH. to 2,292'. install trip nipple & Cont. to POOH to 1,728' Tested 7/27/18. 8/5/201812:00 8/6/201812:00 No AIS. Camp on High Line@ Cont. POOH &L/D CIBP running tool. WU Baker MSC BHA& RIH to cut liner@ AM AM COS. Rig on High Line. HOPE 10,469'. Cont. to RIH W 10,525'& latch up to liner. Strip OON to 10,275'. Circ & mnd Tested 7/27/18. mud. F/C. Strip OOH f/10,275'to 10,002' —.. 0 0 x Weekly Progress Report 8/3/18 Well: MT6-08 Field: Lookout API: 5010320772 Hole Depth vs. Day 0 5 10 15 20 25 30 35 40 45 50 Day Report Start Report End Date Date General Remarks 7/24/2018 7/25/2018 No AIS. Camp on High Line go 12:00 AM 12:00 AM CDS. Rig on generators as 05:30 7/9/18Hrs. ROPE Tested 7/19/18. Agencies notified far.. 7/25/2018 7/26/2018 No AIS. Camp on High Line @ 12:00 AM 12:00AM CDS. Rig an generators as 05:307/9/I8fln. ROPE Tested 7/19/18. AOGCC.,dated for ... 7/26/2018 7/27/2018 No AtS. Camp on High Line @ 12:00 AM 12:00 AM CD5. Rig on generators as 05:3D 7/9/1SH ra. ROPE Tested 7/19/18. Daily cost reflects 9- 7/27/2018 7/28/2018 No AI&Camp on High Line@ 12:W AM 12:00 AM CDS. Rig on generators@ 05:307/9/1BHrs. ROPE Tested 7/27/18. 7/28/2018 7/29/2018 NO AIS. Camp oa High Line@ 12:OOAM 12:00 AM CDS. Rig on generators@ 05:307/9/18H is. ROPE Tested 7/27/18, 7/29/2018 7/30/2018 No AIS. Cramp on High Line @ 12:00 AM 12:WAM CDs. Rig on generators@ 05:307/9/1814m. ROPE Tested 7/27/18. 7/30/2018 7/31/2018 No AIS. Camp oa High Line @ 12:00AM 12:00 AM CDs. Rig on laminators IS, 05:30 7/9 ISH rs- BO PE Tested 7/27/18. 7/31/2018 8/1/201812:00 No AIS Camp on High Line @ 12:00 AM AM CDS. Rig on High Line. ROPE Tested 7/27118. 8/1/2018120D 8/2/201812:00 No AIS. Camp on High Line @ AM AM CD5. Rig on High Line. BOPE Tested 7/27/18. 8/2/201812:W 8/3/201812:00 No AIS. Camp on High Line@ AM AM CD5. Rig on High Line. ROPE Tested 7/27/18. 14st24Hour Sunani POOH W4,650- MD. BROOH Withal CBD .2. POOH & L/D BHA 112. Change upper rams to 9-5/8" SBR, test. R/U to run casing. Continue poll with 9-S/8" Tl. P/U and RIH 9-5/8"Casing per detail to 8,846' MD, clrculadngasneeded. Run casing to 10,317', C&C for cement, pump Intermediate 1 cement job per program, Flag did not bump, floats held. Set and test packof, F/C, set'L' Storm packer. N/D ROPE, prep to install 7" casing spool. Install 7" casing spool, re -bot packoff. N/U BOP, set test Plug. ISIMOPS-Flush and FP annulus.) Change rams and and ROPE. Pull storm packet Sat wear ring, WU 8-3/4" BHA 83, RIH to 8,410' MD. Drill out 9-5/8" shoe track, Whole and 20' form m... FIT to 14.0 ppg. 0,11158' more mthole for SDL pilot ass, C&C, POOH to 32'. UD BHA 83, P/U 6" Autotrak Inner BHA R4, stand back. P/U and run 7" TN Blue. M/U Inner BHA, spare at. RIH with SOL BHA M to 3,642' M0. Continue RIH to 10,043' MD. PJSM, Change out Dynamitic electric brake. Install MPD, RIH to 10,408' MD. CHIP to 10A68' M0, 7,318' TVD. Drill ahead G" %8-3/4" 5D1 f/10,40- to 11,537'. (Rotary stalled @ 11,530' & lost communication with directional tools) Trouble shoot communication with directional tools & sound pipe pressure loos. Cont. to trouble shoot DTT & blind drill to 11,550'. No success with communication with directional tools. Wt up to 11.1 ppg. StrIpOOH as per MPD to 2,605'. Pull PCD & Insane 11 trip nipple. t/0 Flow diverter & quick connect. POOH w/4" DP & rack back in derrick. L/D BHA 44 LID BHA 84. M/U BHA as. RIH to 8,815'. Install RCD bearing. Cont, to RIH to 11,548' & Inch up with liner. Attempt to work liner free & move liner up hole to 11,535'. Circ & sat mud wt to 10.5 ppg. Attempt to move liner Pack off. Liner stuck In hole with no —. clro.lim.n. IT 2,000 4,000 6,000 is 10,000 r ---b a 18 - 0'-1 � Weekly Progress Report 7/30/18 Well: MT6-08 Field: Lookout API: 5010320772 Hole Depth vs. Day 12,000 14,000 16,000 18,000 20,000 0 5 10 15 20 25 30 35 40 45 50 Day Report Start Report End Date Date 7/18/2018 7/19/2018 12:00 AM 12:00 AM 7/19/2018 7/20/2018 12:00 AM 12:00 AM 7/20/2018 7/21/2018 12:00 AM 12:00 AM 7/21/2018 7/22/2018 12:00AM 12:00 AM 7/22/2018 7/23/2018 12AO AM 12:00 AM 7/23/2018 7/24/2018 12:00 AM 12:00 AM 7/24/2018 7/25/2018 12:00 AM 12:00 AM 7/25/2018 7/26/2018 12:00 AM 12:00 AM 7/26/2018 7/27/2018 12:00 AM 12:00AM 7/27/2018 7/28/2018 12:00 AM 12:00 AM 7/28/2018 7/29/2018 12:00 AM 12:00 AM 7/29/2018 7/30/2018 1200AM 12:00 AM General Remarks Last 24 Hour Summry No AIS. Camp on High Line@ Cont. to run casing &land on hanger @ 2,010'. Circ & Gond for cementjob. Cement CDS. Rig an generators as "sing as per SLB. CIP @ 11:00 Mrs. N/D riser & annular. N/U BOPE & MPD. 05:30 7/9/18Hrs, No AIS. Camp on High Line @ N/U MPD equipment & test. R/U & test ROPE. M/U 12-1/4" BHA & RIM W 1,747'. Tea CDS. Rig on generators as "sing. Drill out to 2,D41'. FIT to ISO ppg. Drill ahead L12,041' to 2,124' 05:307/9/18Hrs. BOPE Tested 7/19/18 No AIS. Camp on High Line@ Drill ahead f/2,1241 to 2,487'. MWO issues. Start BROOM to shoe (/2,487' to 2,2151. CDS. Rig an generators as Tool started working. RIM to 2,487'. Resume drilling. Drill ahead f/2,487 —446' 05:30 7/9/181+rs. ROPE Tested 7/19/18 No AIS. Camp on High Line@ Drill ahead f/4,046'to 6,415' CDS. Rig on generators as 05:30 7/9/18Hrs. ROPE Tested 7/19/18 No AIS. Camp on High Line @ Drill ahead f/6,415' W 9,008' CDS. Rig on generators as 05:307/9/181irs. ROPE Tested 7/19/18 No AIS. Camp on High Une @ Drill ahead f/9,008'to TD 10,330'. Circ hole clean. Rack back stand after each 2 8/U t CDS. Rig on generators as 30,132' F/C. POOH f/10,132- to 6,277' 05:307/9/181irs. BOPE Tested 7/19/18 No AIS. Camp on High Line @ PODH to 4,650' MD. BROOM to shoe, CBU x 2. POOH& L/D BHA #2. Change upper CDS. Rig on generators as rams to 9-5/8" SBR, test. R/U to run casing. 05:307/9/IBHrs. ROPE Tested 7/19/18. Agencies notified for... No AIS. Camp on High Line@ Continue testing with 9-5/8"Tl.P/U and RIM 9-5/9" casing per detail to 8,846'MD, COS. Rig on generators as circulating as needed. 05:307/9/181firs. BOPE Tested 7/19/18. AOGCC updated for .. No AIS. Camp on High Line @ Run "sing to 10,317', C&C for cement, pump Intermediate 1 cement jo' �,ogra CDS. Rig on generators as plug did net bump, floats held. Set and test packoN F/C, set 'L' Storm p 1/0 05:307/9/18Nrs. BOPE Tested ROPE, prep to install 7" causing spool. 7/19/18. Daily cost reflects 9-... No AIS. Camp on High Une @ Install 7" casing spool, re -test packa#. N/U BOP, set test plug. (SIMOP&Flush and FP CDS. Rig on generators@ annulus.) Change rams and test ROPE. Pull storm packer. Set wear ring, WU 8-3/4" 05:307/9/181frs. BOPE Tested BHA#3, RIM to 8,418'MD. 7/27/18, No AIS. Camp on High Line@ Drill out 9-5/8" shoe track, rathole and 20'formation. ITT to 14.0 ping. Drill 58' more CDS. Rig on generators@ "thole for SDL pilot assy.0&C, POOH to 32'. 05:30 7/9/18Hrs. ROPE Tested 7/27/18. No AIS. Camp on High Line @ LID 814A #3, P/U 6" Autotrak inner BHA #4, stand back. P/U and run 7" TN Blue. M/L CDS. Rig on generators @ inner BHA, space out. RIM with SOL BHA #4 to 3,642' MD, 05:307/9/18Hrs. ROPE Tested 7/27/18. Hole Depth vs. Day Weekly Progress Report 7/23/18 Well: MT6-08 Field: Lookout API: 5010320772 Report Stat Report End Data Date General Remarks Last 24 Hour Summery 7/14/2018 7/15/2018 No AIS. Camp on High Line@ Prep for move. Skid Floor. Move sub atl of wall. Pull mat boards& herculite. Inspect E, 12:00 PM 12:00 AM COS. Rig on Extension as grade pad. Spot MPD equipment. Set herculite & mats. 05:307/9/1&X11. 7/15/2018 7/16/2018 No AIS. Camp on High Line@ Set herculite&Tell, Spot sub over well, Spot pits& motors complex. Spot ball mill. 12:00 AM 12:00 AM CDS. Rig on generators as Rig up on well. Rig acceptance check list Load pipe shed w/BHA, DP&casing. Take on 05:307/9113H is. Rig accepted spud mud. Pre -Spud Meeting. M/U Is- BHA, Fill conductor& check for leaks. 08:00 His 7/16/2018 7/17/2018 No AIS Camp on High Line Bit Fix leaking rise, Fill hole &check leaks]good). DHII 16" Surface to 1,621Y (Had issues 1200 AM 12:00 AM CDS. Rig on generators as with piny attacks and packing off Row line) 05:307/9/181firs. 7/17/2018 7/18/2018 Incident - First Aid. Camp on Drill foto of2,021'. Circ hole clean&wt upto9.9 ppg P00H&L/OBHA.R/U1orun 12:00 AM 12:00 AM High Line @ CDS. Rig on casing. RIH 13d/8" casing to 1,425' generators as 05:307/9/18Mm. 7/18/2018 7/19/2018 No All. Camp on High Lt.. Bit Cont to run using &land on hanger @ 2,010'. Circ& cond for cement job, Cement 12:00 AM 12:00AM CDS. RIg on generators as casing as per SLB. CIP@11:00 Mrs. N/D rider &annular. N/U&OPE&MPD. 05:307/911BHn. 7/19/2018 7/20/2018 No AIS. Camp on High Line @ N/U MPD equipment & test. R/U & test BOPS. MN 12-1/4" BHA & RIH to 1,747'. Test 12:00 AM 12:DOAM CDS. Rig on genenatpri as casing. Drill out to 2,041'. FIT to 18.0 PPE. Drill ahead 1/2,041'to 2,124' 05:307/9/1814rs. ROPE Tested 7/19/18 7/20/2018 7/21/2018 No AIS. Camp on High Line@ Drill ahead 1/2,124' to 2,487'. MWD issues. Sun BROOM to shoe f/2,48Tto 2,215'. 12:00 AM 12:00 AM CDS. Rig on generators as Tao[ started working. RIH to 2,487'. Resume drilling. Drill ahead f/2.487' to 4,046 05:30 7/19/181111. BODE Tested 7/19/18 7/21/2018 7/22/2018 No AIS. Camp on High Line g) Drill ahead F/4,046' to 6,415 12:00 AM 12:00 AM CD5. Rig on generators as 05:307/9/18Hn. ROPE Tested 7/19/18 7/22/2018 7/23/2018 No AIS. Camp an High Line Bis Drill ahead 1/6,415' to 9,008' 12:010 AM 12:00 AM CDS. Rig on generators as 05:307/9/1814n. ROPE Tested 7/19/18 0 5 10 15 20 25 30 35 40 45 50 Day Weekly Progress Report 8/13/18 Well: MT6-08 Field: Lookout API: 5010320772 Hole Depth vs. Day 0 5 30 15 20 25 30 35 40 45 50 Day Report gad Report End Data Date General Remarks 8/2/201812:00 8/3/201812:00 No AIS. Camp on High Line AM AM CVS. Rig on High Una. BOPE Tested 7/27/18. 8/3/201812:00 8/4/201812:00 No AIS. Camp on High Line@ AM AM COS. Rig on High Line. ROPE Tested 7/27/18, 8/4/201812:00 8/5/2018 12:W No AIS. Camp on High Line @ AM AM CD5, ftig on High Lina. BOPE Tested 7/27/18. Last 24 Hour Summry L/D BHA g4. M/U BHA 85. RIH to 8,815'. Install RCD bearing. Cont. to PIH to 11,548'8, latch up with liner. Attempt to work liner free & move liner up hole to 11,5351. Grc & cut mud wt to 10.5 ppg. Attempt W more liner. Peck off. Uner stuck in hole with no circuNdon. Attempt to gain circulation & work liner free with no success. Drop ball & release from liner. Liner shoe Estimate ^11,434'/ TOL 9,030'. Circ & cond mud to 10.5 ppg. F/C. Slip & cut drill line. F/C. Wt up to 10.8 ping. Strip OOH to 2,510'. Pull RICO bearing & install trip nipple. L/D flow dNerter & liner run tools. POOH to BHA. L/D BHA g5. M/U cement retalm r BHA. RIH W 10,542' &set. Circ 8/U. Install RCD beadn& Strip OOH. to 2,292'. Install trip nipple & Cont to POOH to 1,228' 8/5/201812:00 8/6/201812:00 No AIS. Camp on High Line @ Cont POOH & L/D CIBP running tool. M/U Baker MSC BHA & RIH to cut liner @ AM AM CDS. Rig on High Une. BOPE 10,469'. Cont m RIH to 10,525'& latch up to liner. Strip OOH to 10,275'. Circ & cond _ Tested 7/27/18. mud.F/C. Strip OOH f/10,275'to 10,002' 8/6/201812:00 8/7/201812:00 No AIS. Camp on High Une @ Strip OOH 1/10,1202' to 1,491'. Install trip nipple. L/D HRDE. R/U false table & POOH AM AM CDS. Rig on generators as of winner string. R/U using running th ip.POOH& VO SOL 40 upper rams&tett. 15:30 H. 8/6/16. ROPE Tested WU cement stinger asst'&RIH to 521- 7/27/18. 8/7/201812:00 8/8/201812:00 No AIS. Camp on High Line Its RIH to 10,542'. Circ & cond for cement fob. Set KOP as per SLB. POOH to TOC @ AM AM CD5. Rig on generators as of 10,218. Circ clean. POOH to 3,658' 15:30 His 8/6/16. BOPE Tested 8/8/18. 8/8/201812:00 8/9/201812:00 Hydraulic spill In cellar Camp POOH& L/D cement stinger May. C/O upper rams to 4.1/2"g7". Tart ROPE. M/U AM AM on High line@CDs. Rig on motor kkk off 8HA. High Une at 0623 him 8/8/18. BOPE Tested 8/8/18. 819/201812:00 8/10/2018 No AIS. Camp on High Line@ Cont. to M/U BHA. RIH w/ kick off BHA &tag TOC@ 10,221'. Drill out &kick off to TD AM 12:00 AM CD5. Rig on High Line. BOPE of 10,491'. Displace to new 10.8 ping LSND. EPOCH f/10,491'to 9,020' Tested 8/8/18. 8/10/2018 8/11/2018 No AIS. Camp on High Line@ Strip OOH to HWDP. Install VIP nipple. POOH & L/D OP. R/U to run SOL. M/U&RIH 12:00 AM 32:00 AM CDS. Rig on High UM. ROPE w/7" SOL to 2,406'. WU SOL inner string to 82' Torted 8/8/18. 8/11/2018 8/12/2018 No AIS. Camp on High Line@ Cont/M/U inner string &RIH w/4" OP to 2,488.. M/U liner OC, running tools, &flow 12:00 AM 12:OOAM CDS. Rig on High Line. BOPE diverter. RIH w/SDL to 10,163'. Install RCD bearing. MH to 10.257'. Circ&cond &W&R Tested 8/8/18. to 10, 491'. Drill ahead w/SDL f/10,491' to 10,565' _ 8/12/2018 8/13/2018 No AIS. Camp on High Line@ Drill ahead 1/10,585' to 11,388' 12:00 AM 12-0 AM CDS. Rig on High Line. ROPE Tested 8/8/18. Hole Depth vs. Day 10,0C Weekly Progress Report 8/20/18 Well: MT6-08 Field: Lookout API: 5010320772 Reportstart Report End Data Data General Remarks last 24 Hour Summry 8/12/2018 8/13/2018 No AIS. Camp on High Line@ Drill ahead f/10,565'to 11,388' 12:00 AM 12: W AM COS. Rig on High Une. BOPE Tested 8/8/18. 8/13/2018 8/14/2018 No AIS. Camp an High Line@ Drill ahead f/11,388' to 12,265 12:01) AM 12:00 AM COS. Rig on High Una. BOPE Tested 8/8/18. 8/14/2018 8/15/2018 No AIS. Camp on High Line BID Drill ahead with SOL from 12,265'to TO at 12,5SDIFlow diverter washed-out at 12:00 AM 12:00AM CDS. Rig on High Line. BOPE 12,506'). Wt. up to 30.8 on. Release from linmg OWFF and Strip OOH from 12,329' to Tested 8/8/18, 2,661' 8/15/2018 8/16/2018 No AIS. Camp on High tine@ POCH W BHA and lay down same.0&C Boor and PU cement retainer, spaccout pups 12:01) AM 12:00 AM CDS. Rig on High Une. ROPE and equipment MU and RIH with cement retainer BHA to 2,343'. MU seal assembly, Tested 8/8/18. space -out pups to 2,385'and circulate) string volume. Wash down TOL and OC ata bpm and continue RIH to 10,302'. Obtain parameters and observe seals engage M 12,4131. RB stand and MU cementing equipment 6/16/2018 8/17/2018 No MS. Camp on High Line® Continue C&C staging up in 0.5 bpm to 2.5 bpm max for cement job. Release from 12:00 AM 12:00 AM CDS. Rig on High Llne. BOPE liner with 1.75" release ball and set cement retainer 12,406'. CBU at 8 bpm, sting into Tested 8/8/18, cement rotaber and cement liner with 62.2 bbls of 15.8# cement. Set packer, OWFF and C&C with 15.5 bpm. POOH with running tool assembly to 2,630' (check and clean cement rings - more substantial from std #35) 8/17/2018 8/18/0018 No AIS. Camp an High Line@ Run 7"BTCM Tie Back to TOL, bate and spam out. MU hanger and reverse circulate 12:00 AM 12:W AM CDS. Rig on High Una (lost High 9.0 ppg Cl brine line power from 14:00 to 16:30). BOPE Tested 8/8/18. 8/18/2018 8/19/2018 No AIS. Camp on High Line@ C/O UPRs and test same to 3,500 psi for 5 min w/4"TJ. PU/MU 6" clean out BHA and 12:00 AM 12:OOAM CDS. Rig on High Line (Off high RIH to 10,453' line power from 15:35 to 15:55). BOPE Tested 8/8/18. 8/19/2018 8/20/2018 No AIS. Camp on High Line@ RIH with 6" clean out BHA on 4" DP to 12.256'. RU and test T' call W 3.500 psi. W/R 12:0 AM 12:00 AM CDS. Rig an High Une. BORE and tag CICR at 12,406'. Drill cart CICR, share back and put hate. Fir to 12.6 ppg. SOON Tested 8/8/18. and UD BHA Day `s 10,00 0 x 12,00 Weekly Progress Report 8/27/18 Well: MT6-08 Field: Lookout API: 5010320772 Hole Depth vs. Day Report Start Report End Date Oate General Remarks Last 24 Hour Sammy, 8/19/2018 8/20/2018 No AIS. Camp on High Line@ RIH with 6"clean out BHA an 4" DP to 12,256'. RU and test 7" asg to 3,500 PsL W/R 12,00AM 12:00 AM CDS. Rig an High Une. BOPE and rag OCR at 12,406'. Drill outOCA, shoe track and mt hole. FIT to 12.6 pull. SOON Tested 8/8/18. and L/D BHA 8/20/2018 8/21/2018 No AIS. Camp on High Line@t L/D 6" Clean out BHA. RU and test SOPE.PU&MU 6" Alp C drilling BHA and MH to 12:OO AM 12:00 AM CDS. Rig on High Line. BOPE 25'abows Int 2 shoe at 12,469'.5&C drilling line. Displace to 9.2 FIoPmand OWFF Tested 8/20/18. 8/21/2018 8/22/2018 No AIS. Camp on High Line@ Install RCD bearing. Wash and log from Int 2 shoe at 12,469'to bon at 12,570'. Drill 12:00 AM 12:00 AM CDS. Rig on High Line. ROPE ahead 6" hole as per program and gem to 13,905' MD, 7,965'; TVD. Tested 8/20/18. Daily tort reflects 7" Tie -back -- tangibles 8/21/2018 8/23/2018 No AIS. Camp on High Line @ Continue geosteering in lower Alpine C lateral from 13,905'MO m 15,655' MD, 7,92- 12;00 AM 12,00 AM CDS. Rig on High Line. BOPS TVD. Tested 8/20/18. _ 8/23/2018 8/24/2018 No AIS. Camp on H lgh Line® Continue gemsteering In lower Alpine C lateral W 16,229' MD. Obseme minor packing 12:00 AM JN- 12:00 AM CDs. Rig on High Line. BOPE oft after out of zone for 600'. Decision to BROOH to 15,625' MD. CSU, Strip in hole to Tested 8/20/18. 16,065' MO. W/R to 16,229' MD and resume drilling down @ SW to better sand. 8/24/2018 8/25/2018 No AIS. Camp on High Line@ Continue geosteering in lower Alpine C lateral to 17,923' MD holding 400 psi an 12,0DAM 12:00 AM COS. Rig on High Line. ROPE connectors. Brief losses 30-40 bph, pump LCM pill and antyam pill to clear floats. Tested 8/20/18. Resume drilling to 17,693'whlle holding 200 psi on connections. 8/25/2018 8/26/2018 No AIS. Camp on High Line 0 Continue geasteering in lower Alpine C lateral to 18,383'MD. MWD failure, CBU x2 12:00 AM 12:00 AM COS. Rig on High Line. BOPE prep to 500H. Tested 8/20/18. Dally loss to farmatimm 260 bbl, Cumulative loss t0 ... 6/26/2018 8/27/2018 No AIS. Camp on High Une@ Continue condition hole with 4 BU, SOON W shoe, displace to 9.6 Vis Brine. POOH, L/D 12:00 AM 12:00AM COS. Rig on High Une. DOPE BHA #13, P/U BHA 014 and RIH Teased 8/20/18. Deily loss to farmaton=95 bbl, Cumulative loss to formation.... Day THE STATE °fALASKA GOVERNOR BILL WALKER Tom Polasek Drilling Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Greater Mooses Tooth Field, Lookout Oil Pool, MT6-08 Permit to Drill Number: 218-048 Sundry Number: 318-317 Dear Mr. Polasek: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aogcc.ala5ka.gav 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, Hollis S. French Chair +t. DATED this R day of August, 2018. ABDMSJ�A b 0 9 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED JUL 2 5 2013 A0Q` Q 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ BHA Abandonment w/ RA Source ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Exploratory ❑ Development Stratigraphic ❑ Se ice 218-048 . 3. Address: 6. API Number: 700 G St, ATO 1702, Anchorage, AK 99501 -7 gam, /� 50-103-20772-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A MT6-08 " Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): AA081798, AA081818, AA081819 Greater Mooses Tooth Unit, Lookout 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): 10330 7242 10330 7242 3019 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 115' 115' Surface 1975' 13.375" 2011' 1984' Intermediate 1 Intermediate 2 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): None 12. Attachments: Proposal Summary j Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Slratigraphic ❑ Development ❑� Service ❑ 14. Estimated Date for 8/6/2018 - 8/10/2018 15. Well St lus after proposed work: Commencing Operations: OIL,r1 W NJ ElWDSPL F]Suspended 1-116. GAS ❑'7" AG ❑✓ GSTOR ❑ SPLUG ❑ 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: Tom Polasek Contact Name: Tom Polasek Authorized Title: illing Engineer Contact Email: tom. olasek o CO .cOm Contact Phone: 907-263-3740 Authorized Signature: ZI& Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: / Post Initial Injection MIT Yes No ❑ F-1 Yes ❑ Nod Subsequent Form Required: /0- y0,1 Spacing Exception Required? �►�" Jy}�� APPROVED BY Approved COMMISSIONER THE COMMISSION Date: 1 `� t/" y�O ��Y RBDMS�AUG 0 9Ss26Wormand �r Form 10-403 Revised 4/2017 !/•f Approved application X/ddlliiddFF h!F date of approval. Attachmen n Duplicate 7, 3P /8 ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 July 24, 2018 Commissioner Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, Alaska 99501 RE: Sundry Approval Request for MT6-08 (218-048) Dear Commissioners: ConocoPhillips Alaska, Inc hereby requests approval to extend the lower lateral Total Depth by -1100 feet. Neighboring well MT6-05 found the reservoir edge to be slightly further out than initially modelled. To ensure ConocoPhillips will find the edge of the reservoir on MT6-08, ConocoPhillips will extend the Total Measured Depth of the lower lateral by -1100' MD. The new TD will stay in the same lease and geologic formation as the original TD. 9 Original APD stated TD of MT6-08 lower lateral TD to be NAD27 Northing: 5960270, Easting: 309581, Total Measured Depth: 20506' MD, True Vertical Depth: 7890' TVD, Formation: Alpine C r Sand, Lease Number: AA081819 k j,r New lower lateral TD of MT6-08 lower lateral TD to be NAD27 Northing: 5,961,173, Easting: �/ 309,152, Total Measured Depth: 21603' MD, True Vertical Depth: 7903' TVD, Formation: Alpine C Sand, Lease Number: AA081819 If you have any questions or require further information, please contact me at (907) 263-3740. sincere � / / Tom Polasek Drilling Engineer MT6-08 Multi -Lateral Injer `or wp06B DRAFT Comple'" -m Schematic as of 7-24-18 3 Top Alpine C 11,969' MD / 7904' TVD 0 0 0 0 0 0 0 7" 26 ppf L-80 Tenaris Blue Liner to 12,169' MD / 7930' TVD @ 83 deg Upper Lateral 6" Hole, TD at at 20,600' MD / 7,880' TVD 4-'/." 12.6# L-80 TXP Liner With Perf Pups 0 0 0 0 0 4-'/." 12.6# L-80 TXP Liner With Perf Pups 0 0 0 0 0 0 6" Hole, TD at at 21,603' MD / 7903' TVD 20" 79 ppf H-00 Insulated Conductor 79 feet, cemented to surface Tubing / Liner Completion: 1) 4-1/2' X Landing Nipple (3.813" ID) O 2) Liner Top Packer / Hanger w/ Tie Back sleeve 3) 4-'/" x 1" GLM w/DCK2 SOV 13-3/8" 68 ppf L-80 TXP 4) 4-%" DB Landing Nipple vv/RHC Plug Surface Casing Body Installed (3.75" ID) 2,011' MD / 1,984' TVD (actual) cemented to surface 5) Liner Top Packer/ Hanger w/ Tie Back Sleeve 6) 4-1/2' DB Landing Nipple (3.562") 4-1/2" 12.6 ppf L-80 Blue to 7) 4'/z' Blue Blank Pipe -11,900' MD 8) LEM and Hook Hanger 7" 26 ppf L-80 Tenaris BTC Tieback to 9,985' MD / 6,986' TVD @ 57" TOL @ between 9,235'- 9,985' MD / 6,646' - 7,054' TVD @ 57" 9 5/8" 40 ppf L-80 H563 (Surface to 1270'MD' MD) 9 5/8" 40 ppf L-80 TXP (1270' MD to 8235' MD) 9 5/8" 40 ppf TN-80HS (8235' MD to TD) @ 10,319' MD / 7236' TVD (updated plan) .. Tnr of a F/R -. a )qr ft hAn 3 Top Alpine C 11,969' MD / 7904' TVD 0 0 0 0 0 0 0 7" 26 ppf L-80 Tenaris Blue Liner to 12,169' MD / 7930' TVD @ 83 deg Upper Lateral 6" Hole, TD at at 20,600' MD / 7,880' TVD 4-'/." 12.6# L-80 TXP Liner With Perf Pups 0 0 0 0 0 4-'/." 12.6# L-80 TXP Liner With Perf Pups 0 0 0 0 0 0 6" Hole, TD at at 21,603' MD / 7903' TVD Davies, Stephen F (DOA) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Monday, July 30, 2018 12:25 PM To: Davies, Stephen F (DOA) Subject: RE: [EXTERNAL]FW: MT6-08 (PTD #218-048) - Extension Steve, I apologize for the confusion, I am the one that checked the wrong boxes. I misunderstood the definitions within class and status. The well is an injector. It will not be pre -produced. It will only be flowed back enough to clean up the well (Less than 30 days, likely only two or three wellbore volumes. I can get a more accurate estimate of flowback volume and time if needed). It will be injected with water alternating with gas. Correct Class and Status Well Class: Service Well Status after proposed work: WAG Thanks Steve and let me now if this didn't clear thing up, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Monday, July 30, 2018 12:03 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: RE: [EXTERNAL]FW: MT6-08 (PTD #218-048) - Extension Tom, Thank you for providing the directional survey data in electronic format. Another question: On the Application for Sundry Approvals for MT6-08, in the section of the form labeled "Current Well Class," someone at CPAI checked box marked "Development." In the section of the form labeled "Well Status after proposed work," the boxes labeled "Oil" and "WAG" are both checked. The Permit to Drill application indicated that this well will be a water -alternating -gas injector. Which class and status will apply to MT6-08? Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesfdalaska.gov. From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Friday, July 27, 2018 7:22 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]FW: MT6-08 (PTD #218-048) - Extension Steve, Please see attached directional files for MT6-08 Lower Lateral Extension. Files are NAD27. Thanks, tom From: Davies, Stephen F (DOA) <steve.davies@alaska.xov> Sent: Thursday, July 26, 2018 10:13 AM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]FW: MT6-08 (PTD #218-048) - Extension Tom, Could CPAI please provide the proposed directional survey data for the extended wellbore in spreadsheet or ASCII table format? Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. THE STATE °fALASKA GOVERNOR BILL WALKER Graham Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.olaska.gov Re: Greater Moose's Tooth Field, Lookout Oil Pool, MT6-08 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-048 Surface Location: 283' FNL, 3227' FEL, SEC. 6, TI ON, R3E, UM Bottomhole Location: 1564' FNL, 712' FEL, SEC. 23, Tl IN, R2E, UM Dear Mr. Alvord: Enclosed is the approved application for the permit to drill the above referenced service well. 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. 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 s % DATED this i day of May, 2018. RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 2 4 2018 PERMIT TO DRILL 20 AAr. 21 nos 1a. Type of Work: 111b. Proposed Well Class: Exploratory - Gas Service - WAG + Service - Disp ❑ 1c. Specify if well is proposed for: Drill 0 . Lateral []I Stratigraphic Test ❑ Development -Oil ❑ Service - Winj ❑ Single Zone Q ' Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry []I Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. . 5952180 MTS -08 ' r Alill 3. Address: 6. Proposed Depth: 12. Field/Pool(s): CkM c P.O. Box 100360 Anchorage, AK 99510-0360 MD: 20506 TVD: 7890 Greater Mooses Tooth Unit . glpine�HndeFnerd QI 4a. Location of Well (Governmental Section): 7. Property Designation: B- ri 'Iyv , Surface: 283' FNL, 3227' FEL, Sec. 6, T10N, R3E, UM AA081818, 6, AA081798, AA081819 • Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 3980' FNL, 2091' FEL, Sec. 25, T11 N, R2E, UM 932553 340760 932533 932554 7/12/2018 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1564' FNL, 712' FEL, Sec. 23, T11 N, R2E, UM 1208, 3837, 607, 1923 1564'to AA094421 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 70 15. Distance to Nearest Well Open Surface: x- 317004 • y- 5945523 . Zone -4 GL / BF Elevation above MSL (ft): 34 to Same Pool: 3503' to Lookout 1 1 16. Deviated wells: Kickoff depth: 1036 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90.4 degrees, Downhole: 3810 ✓ Surface: 3019 v 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) 42" 20" 94 H-40 Welded 80 34 34 115 115 10 yds 16" 13.375" 68 L-80 H563 2022 34 34 2056 2035 72 ax IIo ppg peepereie, a26 sx 15.6 ppg G 12.25" 9.625" 40 L-80 BTC -M 10201 34 34 10235 7130 a5 sx 12.2 ppg Gass G, 216 sx 15.8 ppg Class G 8.75" 7.0" 26 L-80 Blue 12046 rioltil 34 34 12080 7911 380 sx 15.8 ppg G 6" 4.5" 12.6 L-80 TXP 8576 JjQae 7852 20506 7890 uncemented pert pup liner 19. PRESENT WELL CONDITION SUMMARY (To be complet or Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): / Hydraulic Fracture planned? Yes[] No v -Iii 20. Attachments: Property Plat El BOP Sketch Drilling Program ✓ Time v. Depth Plo[ Shallow Hazard Analysis Diver er Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Tom Polasek Authorized Name: Graham Alvord (265-6120) Contact Email: tom. q.polasek O0conocephillios.com Authorized Title: Drilling Manager// Contact Phone: 907-263-3740 4 QA. Date: +( L3 Its ( ll Authorized Signature: �,4 Commission Use Only Permit to Drill API Number: rov: Permit App See cover letter for other Number: - Q 50- 1b J- Q - (Y)-OQ Date l requirements. _94 - 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: h Other: vi' 35SoD Si rJQ P -reS Samples req'd: Yes N,y Mud log req'd: Yes,❑ No5r P V) I (/ �� 7 4 ( G s - H2S measures: Yes No,❑,/ Directional svy req'd: Yes Lv� No r C66et 4N�-�-� Spacing exception req'd::: YYe's ❑ NOUV Inclination -only svy req'd: Yes ❑ NOR (J Dy L"49 f1-�- z S^O s s Post initial injection MIT req'd: Yes❑ No[-] +r L�,vr��M to•�� t A Ck)(2 1 APPROVED BY Is _ Approved by: COMMISSIONER THE COMMISSION Date. Submit Form and Farm 10-001 Revised 5/2017 This permit is vaiOf t t Of approval pe 20,n4AC 25.005(8) AUachrt�gns ` Duplicate r:o, c ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 April 16, 2018 Alaska Oil and Gas Conservation Commission 333 West 7" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT6-08 Dear Sir or Madam: f ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine C -Sand dual lateral injection well from the MT6 drilling pad. The intended spud date for this well is July 12, 2018. It is intended that Doyon Rig 19 be used to drill the well. MT6-08 is planned to have 2 laterals in the Alpine C sand; with the upper Alpine C lateral covered in the MT6-081_1 PTD. The 16" surface hole will TO above the C-30 sand and then 13-3/8" casing will be set and cemented to surface. The intermediate hole will be drilled in two sections to mitigate issues with shale instability over the long interval. The 12-1/4" intermediate #1 section will be drilled into the top of the HRZ and landed at an inclination of — 55°. A 9-5/8" casing string will be set and cemented from TD to secure the shoe and cover 500' above any hydrocarbon -bearing zones. A planned 8-3/4" pilot hole (P131) will tlfdn be drilled out of the 9-5/8" shoe down to the Alpine C sand to locate the formation top and assess the pay thickness an quality. The decision to drill MT6-08L1 lateral, or not, will be dependent on logs acquired during the drilling of this section. The pilot hole will subsequently be plugged back to the 9-5/8" liner shoe with a bottom e' founded stacked cement plug. - The second intermediate will be drilled with a 7" steerable liner drilling assembly, ultimately landing in the Alpine C sand. This assembly will consist of a 6" pilot BHA ahead of the casing shoe and incorporate a 8-3/4" underreamer for increased annular clearance. Managed Pressure Drilling technology will also be utilized to assist with providing stability through the HRZ, Kalubik, and Miluveach formations. This interval will build from 55° to 830 inclination. The drilling assembly inner string will then be tripped and a cement assembly run into the hole to cement the 7" drilling liner annulus. The production interval will be comprised of a 6" horizontal hole that will be geo-steered in the Alpine C sand. The well will be completed as a unstimulated injector with 4.5" liner with pre -perforated pup joints and tied back to surface with a 4.5" tubing upper completion string. A second lateral, MT6-08L I, dependent on logs acquired in the pilot hole section, will then be drilled in the upper Alpine C Sand, with the upper completion covered in the corresponding PTD application. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: I. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Tom Polasek at 263-3740 (tom.g.polasek@conocophillips.com) or Chip Alvord at 265-6120. Sine ly, cc: MWell File/ Ann Haggerty -Sherrod ATO 1530 Johnson Njoku ATO 1720 Tom Polasek Chip Alvord ATO 1570 Drilling Engineer John Cookson ATO 1750 Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 MT6-08 Application for Permit to Drill Document E Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (Z))............................................................3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ............................................3 Requirements of20 AAC 25.050(b).............................................................................................................3 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) .........................4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 (c) (5)).......................................................................................................................... 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6))...........5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) ..........................5 8. Drilling Fluid Program (Requirements of20 AAC 25.005(c)(8)) ....................................6 9. Abnormally Pressured Formation Information (Requirements of20 AAC 25.005 (c)(9)) ................................................................................................................................... 8 10. Seismic Analysis (Requirements of20 AAC 25.005 (c)(10)) ..........................................8 11. Seabed Condition Analysis (Requirements of20 AAC 25.005 (c)(11)) .........................8 12. Evidence of Bonding (Requirements of20AAC 25.005 (c)(12)) ...................................8 13. Proposed Drilling Program (Requirements of 20AAC 25.005 (c)(13)) .........................8 14. Discussion of Mud and Cuttings Disposal and Annular Disposal.....................10 (Requirements of 20 AAC 25.005 (c)(14))...........................................................................10 15. Attachments..............................................................................................................11 Attachment 1 Cement Summary ................................................................................................................11 MT6-08 APD Page 1 of 15 Printed. 18 -Apr -18 Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 Attachment 2 Drilling Hazards Summary ..................................................................................................11 Attachment 3 Completion Schematic......................................................................................................... 11 Attachment 4 Directional Plan.................................................................................................................11 MT6-08 APD Page 2 of 15 Punted. 18 -Apr -18 Application for permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 1. Well Name (Requirements of20 AAC 25.005 (/)) The well for which this application is submitted will be designated as MTU MT6-08 2. Location Summary (Requirements of20AAC25.005(c)(2)) Location at Surface 283' FNL, 3227' FEL, Sec. 6, T10N, RIE, UM NAD 1927 RKB Elevation 70.0' AMSL Northings: 5,945,523 Eastings: 317,003 Pad Elevation 34.0'A.MSL Top of Productive Horizon Heel 3980' FNL, 2091' FEL, Sec. 25, TI IN ' R2E' UM NAD 1927 Measured De th, RKB: I 1 873' Northings: 5,952,479 Total Vertical Depth, RKB: 7 884' Eastings: 313,292 Total Vertical Depth, SS: 7,814' Total Depth Toe 1564' FNL, 712' FEL, Sec. 23, Tl 1N, R2E, UM NAD 1927 Northings: 5,960,270 Eastings: 309,581 Measured Depth, RKB: 20,506' Total Vertical Depth, RKB: 7,890' Total Vertical Depth, SS: 7,820' Requirements q(20 AAC 25.050(6) Please see Attachment 4: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of20AAC25.005(c)(3)) Please reference BOP and diverter schematics on file for Doyon. 19. MT6-08 APD Page 3 of 15 Printed: 18 -Apr -18 Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 4. Drilling Hazards Information (Requirements of20AAC25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient(psi) Pore pressure ASP Drilling (psi) 20 1151115 10.9 52 54 13.375 2056/2035 14.5 910 1331 9.625 10235/7130 16.5 3176 3019 7 12080/7911 12.5 3810 / 2984 4.5 20506/7890 12.5 3773 N/A PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP= [(FGx0.052)-0.1]*D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 =Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS Drilling below 20" conductor ASP= [(FG x 0.052) - 0.1] D =[(10.9x0.052) -0.1]x115=54 psi OR ASP = FPP - (0.1 x D) = 910 - (0.1 x 2035') = 706.5 psi 2. Drilling below surface casing (13-3/8") ASP = [(FG x 0.052) - 0.1] D = [(14.5 x 0.052) - 0.11 x 2035'= 1331 psi OR ASP = FPP - (0.1 x D) = 3176 - (0.1 x 7130') = 2463 psi 3. Drilling below first intermediate casing (9-5/8") ASP = [(FG x 0.052) - 0.11 D = [(16.5 x 0.052) - 0.1 ] x 7130 = 5405 psi OR ASP = FPP -(0.1 xD) = 3810- (0.1 x 7911') = 3019 psi MT6-08 APD Page 4 of 15 Printed: 18 -Apr -18 4. Drilling below production liner (7") M ASP = [(FG x 0.052) — 0.1 ] D = [(12.5 x 0.052) — 0.1 ] x 7911 = 4351 psi ASP = FPP — (0.1 x D) = 3773 — (0.1 x 7890) = 2984 psi Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 (B) data on potential gas zones, The well bore is not expected to penetrate any gas zones. / (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC25.005 (c)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT / FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) v", Casing and Cementing Program Csg7Tbg Hole Sine Weight Grade Conn. Length Top MD7TVD Bim MD!(VD Cement Program OD (in) (it) (h) (k) (lam) 20 42 79 H-40 Welded 80 Surf 115/115 Cemented to surface with 10 yds slurry H563/ Cement to Surface with 13-3/8 16 68 L-80 TXP 2,021 Surf 2,056 / 2,035 942 sx DeepCrete Lead at 11.0 ppg, 328 sx Class G Tail Slurry at 15.8 ppg 9-5/8 12-1/4 40 L-80 TXP/ TN -80 10,200 Surf 10,235 / 7,130 95 sx Class G Lead at 12.2 ppg HC 216 sx Class G Tail at 15.8 ppg n/a Plug 1: 169 sx Class G at 12.2 ppg (Pilot) 8-3/4 n/a n/a n/a 1665 10,235 / 7,130 12,065 / 8,046 Plug 2: 169 sx Class G at 12.2 ppg Plu 3: 377 sx Class G at 17.0 ppg 7 6 x 8- 26 L-80 BTC/ 12,045 Surf 12,080 / 7,911 380 sx Gass G 15.8 ppg cemented to liner 3/4 Blue top at 9,985' MD 4-1/2 n/a 12.6 L-80 563 11,895 Surf 11,930 / 7,892 n/a 4 1/2 6 12.6 L-80 TXP 9,906 11,930 / 7,892 20,506 / 7,890 Uncemeneted open hole liner w/ pre - perforated pup joints 7. Diverter System Information(Requirements of20 AAC 25-005(c)(7)) A diverter will be rigged up while drilling the surface hole as per 20 AAC 25.035 (h)(2). Z MT6-O8 APD Page 5 of 15 Printed: 18 -Apr -18 Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 8. Drilling Fluid Program (Requirements uf20AA(725.005(c)(8)) x Ir M PC> tA.PD Surface Hole: A mixed -metal oxide fresh water drilling fluid (Drilplex) will be used for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight 510.0 ppg by use of solids control system and dilutions where necessary. Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.4-10.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Pilot Hole: Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight from 10.0 – 10.5 ppg. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.3 ppg or higher before pulling out of the hole, if not already at weight. — Intermediate #2: Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight from 10.0-11.0 ppg. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.3 ppg or higher before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. `" MT6-08 APD Page 6 of 15 Printed: 18 -Apr -18 Surface Intermediate Pilot Hole Intermediate Production #1 #2 Hole Size in. 16 12.25 8.75 6.0 x 8.75 6.0 Casing Size in. 13.375 9.625 n/a 7 4.5 Density PPG 9.0-10.0 ' 9.4 - 10.0 10.0-11.0 10.0-11.0 8.8 PV cP 13 10 10 10 15 YP Ib'/ift2 35-50 20-28 20-28 20-28 15-20 Funnel s/qt. 200 40-50 40-50 40-50 60-80 Viscosi Initial Gels Ib./100 50 10 10 10 10 10 Minute Ib./100 60 15 20 20 15 Gels ftz API Fluid cc/30 Loss min. N.C. – 15.0 5.0 5.0 5.0 4.0 Fluid c n/a 8.0-12.0 8.0-12.0 8.0-12.0 10.0 S in. Lo min. Loss min. PH 11.0 9.5-10.0 9.5-10.0 9.5-10.0 9.0-9.5 Surface Hole: A mixed -metal oxide fresh water drilling fluid (Drilplex) will be used for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight 510.0 ppg by use of solids control system and dilutions where necessary. Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.4-10.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Pilot Hole: Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight from 10.0 – 10.5 ppg. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.3 ppg or higher before pulling out of the hole, if not already at weight. — Intermediate #2: Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight from 10.0-11.0 ppg. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.3 ppg or higher before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. `" MT6-08 APD Page 6 of 15 Printed: 18 -Apr -18 Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 Production Hole: The horizontal production interval will be drilled with a water-based mud drill -in fluid FloPro weighted to 8.8-9.5 ppg with calcium carbonate. MPD will be used to hold back pressure, keeping the well dynamically balanced. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. MT6-08 APD Page 7 of 15 Punted: 18 -Apr -18 Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 9. Abnormally Pressured Formation Information(Regadrementsof20AAC25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of20AAC25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20AAC25.005 (c)(/1)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20AAC25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program(Requirements of20AAC 25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. MIRU Doyon 19 onto MT6-08 over pre-installed 20" insulated conductor. Install diverter and function test. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 16" hole to the surface casing point as per the directional plan. (LWD Program: GR/RES).V/ 4. Run and cement new 13-3/8" 68 ppf L-80 surface casing to surface. 5. Install BOPE with the following equipment/configuration: 13-5/8" annular preventer, 3-1/2" x 6" VBR, blind ram and 3-1/2" x 6" VBR.. 6. Test BOPE to 250 psi low/ 3500 psi high (24-48 hr. AOGCC notice). 7. Pick up and run in hole with 12-1/4" drilling BHA to drill intermediate 41. Zi 8. Chart casing pressure test to psi foror 30 30 mutes. 13 $ •�� 9. Drill out shoe track and 20' of new hole. t 10. Perform LOT to maximum EMW of 18.0 ppg. Minimum LOT required to drill ahead is 12.5 ppg EMW. 9 y ..� C QTR i� 11. Displace well to 9.4 ppg LSND mud. T" r� fE�GjC c 12. Drill 12-1/4" hole to the casing point - 10,235 ft MD / 7,130 ft TVD. (LWD Program: GR/RES). t/ 13. Circulate wellbore clean and POOH. 14. Change upper VBRs to 9-5/8" solid body rams. Test same to 250 psi low / 3,500 psi high. 15. Run 9-5/8" intermediate casing to TD. 16. Pump single stage cement job to isolate the casing shoe or 500' MD above uppermost hydro -carbon bearing zone. �IJL'. -lit V 6K/o.U' ?A n( 17. Change upper 9-5/8" solid body rams to Test BOPE to 250/3500 psi LJ y18. Pick up and run in hole with 8-3/4" drilling BHA to . SimOps, perform annulus LOT with Ball mill and freeze protect. 19. Chart casing pressure test to 3500 psi for 30 minutes. 20. Drill out shoe track and 20' of new hole. 21. Perform FIT to 14 ppg EMW. Minimum required to drill ahead is 12.5 ppg EMW. '.. MT6-08 APD Page 8 or 15 Printed: 18 -Apr -18 f26 . . . . . 28. 9. Application for Permit to Drill, Well MTU MT6-08 ` Ial /Saved: 18 -Apr -18 Drill 8-3/4" hole to section TD _ 12,065' MD. (LWD Program: GR/RES/ DEN�U �✓ a. Note: Decision to drill MT6- 1, or not, will be made after vi ng logs from this section Circulate wellbore clean and POOH. P&A 8-3/4" pilot open hole with a continuous bort nded stacked cement plug (step 24 and 25) by pumping 15.8 ppg Class G cement plugs from T 550 below 9-5/8" casing shoe Pump 17.0 ppg cement kick-off plug on of a 12.2 ppg cern t plug to bring cement 200ft inside of casing. POOH with P&A assembly. Run in hole with 8-3/4" ' -off BHA. Drill off cement plug and -100' proration for SDL pilot assembly. POOH with same. nic logging tool will be used to log top of cement in In ediate #1 casing on the way e 1' I O 1 Cha out upper rams to 4-1/2" x 7" VBRs. �� G S� .S'�0" BOPE to 250 psi low/ 24 hr. AOGCC notice 30. Pick up and run in hole with the 7" steerable drilling liner. Pick up and stab in 6" pilot BHA assembly'(LWD Program: GR/RES). ' 31. RIH to bottom with 7" SDL on 5" drill pipe. 32. Drill 6" x 8-3/4" SDL hole to production casing point into the Alpine C sand using Managed Pressure Drilling to maintain constant bottom hole pressure on connections. (LWD Program: GR/RES). 33. Land 7" liner at TD. Disconnect SDL and POOH to surface with inner string and pilot. 34. Run in hole with inner string cementing BHA. Stab into liner. Circulate and condition mud in preparations for cementing. 35. Cement 7" liner to top of liner. Set liner top packer. Circulate excess cement from top of liner. POOH laying down 5" drill pipe. 36. Run 7" tie -back aQngage seals. Space out to land hanger. 37. Displace 9-5/8" x 7" annulus to corrosion inhibited brine and diesel freeze protect. Land the 7" tie back hanger and pressure test annulus ands s to 2000 psi for 30 min and chart. µ I -r- 38. - 38. Pick up 4" DP. Test BOPE to 250 psi low/3,500 psi high. 39. Pick up and RIH with 6" drilling assembly. (LWD Program: GR/Azimuthal RES). 40. Chart casing pressure test to 3500 psi for 30 minutes and record results. ,< S 41. Drill out and perform FIT to 12.5. Minimum acceptable leak -off for drilling ahead is 11.0 ppg EMW. 42. Drill 6" horizontal hole to section TD (LWD Program: GR/Azimuthal RES). ' (. '1 43. Circulate the hole clean and POOH. ��. hZ4. `u'j� C G 44. Run in hole with 4.5" liner with pre -perforated pup joints on 4" drillpipe. 45. Set hanger and liner top packer and POOH. 46. Run and set whipstock system and space out to place window in top Alpine C sand and orient whipstock using MWD. ti p 47. Mill window and at least 20 feet of new formation. 48. POOH and lay down milling BHA. )T 7 PPa 49. End PTD for MT6-08 and begin PTD for MT6-08L1. a. Note: Decision to drill MT6-08L1, or not, based off logs acquired instep 22. MT6-08 APD Page 9 of 15 Pnnted: 18 -Apr -18 Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well MT6-08 will be injected into a permitted annulus on MT6 or dedicated Class 1 disposal well CDI-01 A. The MT6-08 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1100' TVD. Significant hydrocarbon zones include the Alpine. There will be 500' of cement placed above the top of the Alpine reservoir. Once MT6-08 has been drilled and completed, consideration may be given to permit this well for annular injection. An application Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no ---- USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,0351) + 1,500 psi = 2770 psi Pore Pressure = 910 psi Therefore Differential = 2770 — 910 = 1860 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt Grade Range Connection Collapse 85% of Burst 85% of (ppf) Type Collapse Burst 13-3/8" 68 L-80 3 BTC -M 2260 psi 1921 psi 5020 psi 4267 psi 9-5/8 40 L-80 3 BTC -M 3090 psi 2626 psi 5750 psi 4887 psi MT6-O8 APD Page 10 of 15 Printed: 18 -Apr -18 15. Attachments Attachment 1 Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Area of Review Attachment 5 Directional Plan Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 MT6-08 APD Page i l of 15 Printed.18-Apr-18 Attachment i - Cement Summary GMTU MTS -08 wp04 Proposed Casing & Cementing Schematic for Pilot Hole 16. Open Hole Plug SS: 174 Mg Cl. 0Kk3 Plug PMmeOTWOCNmli®10.0 MDI1,015N RanneOe dCNIMnI®10.T MDI>.CWTVD PIU9 S1:12.2 WS CIOR G WOIi On PIUS RannM TW MOenx411 010,70a MDr),4W TVD ftp C Top@ 1 I.VT MD I T.W TVD) Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 20" H a0 1SdM ML-SO18TF 9318" 40N LSO BTCM H w18000h 9-L6" A3 L80 T�aft WD On OeRan tO,T]5 MD I ],190' ND 53•Inc/000•azl �-A 422 �s� c Syr Open Hole 1],065 MD/ 8.616TVD CwVL MT6-08 APD Page 12 of 15 Printed. 18 -Apr -18 Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 GMTU MT6-08 wp04 MT6-08 APD Page 13 of 15 Printed: 16 -Apr -18 Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 13-3/8" Surface Casing run to 2,056' MD / 2,035' TVD. Cement from 2,056' MD to 1,556'(500' of tail) with Class G + Adds. @ 15.8 PPG, and from 1,554' to surface with 11.0 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1,350' MM), zero excess in 20" conductor. Lead slurry from 1,556' MD to surface with DeepCrete @ 11.0 ppg Conductor (115'— 36') X 1.0190 ft3/ft X 1.0 (0% excess) = 81 ft3 Permafrost to Conductor (1,100'— 115') X 0.4206 ft3/ft X 3.5 (250% excess) = 1,450 ft3 Top of Tail to Permafrost (1,556'— 1,100 X 0.4206 ft3/ft X 1.5 (50% excess) = 288 ft3 Total Volume = 81 + 1,450 + 288 = 1,819 ft3 => 942 sx of 11.0 ppg DeepCrete @ 1.93 ft3 /sk Tail slurry from 2,056' MD to 1,556' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,056'-1,5561 X 0.4206 ft3/ft X 1.50 (50% excess) = 316 ft3 Shoe Joint (80� X 0.8407 ft3/ft X 1.0 (0% excess) = 68 ft3 Total Volume = 316 + 68 = 384 ft3 => 328 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.17 ft3/sk 9-5/8" Intermediate casing to 10,235' MD / 7,130' TVD Cement 1000' up from 9-5/8" casing shoe from 10,235' MD to 9,235' MD. Assume 40% excess annular volume. Lead slurry from 9,735' MD to 9,235' MD with 12.2 ppg Class G + additives Base of Lead to Top of Lead I (9,735' — 9,235') X 0.3132 ft3/ft X 1.40 (40% excess) = 219 ft3 Total Volume = 219 ft3 => 95 sx of 12.2 ppg Class G + 0.2% D046 antifoamer, 3.0% D079 Extender and 0.3% D110 Retarder @ 2.30 ft3/sk Tail slurry from 10,235' MD to 9,735' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (10,235'— 9,735') X 0.3132 ft3/ft X 1.40 (40% excess) = 219 ft3 Shoe Joint (80') X 0.4257 ft3/ft X 1.0 (0% excess) = 34 ft3 Total Volume = 219 + 34 = 253 ft3 => 216 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.17 ft3/sk 8-3/4" Pilot Hole to 12,065' MD / 8046' TVD — P&A Open Hole Section Cement from TD to 500' below casing shoe with Class G + Adds. @ 12.2 PPG as per 20 AAC 25.112 (a) (1) (B). Use 40% excess annular volume to account for washout. Pump 17.0 ppg Class G kick-off cement from top of 15.8 isolation plug to 200ft inside the 9-5/8' casing shoe. Use 40% excess annular volume to account for washout. II MT6-08 APD Page 14 of 15 Printed: 18 -Apr -18 IWA 317- 1543t -S Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 Plug #1 (Isolation) from 12,065' MD to 11,400' with 12.2 ppg Class G + additives 8-3/4" Open Hole (12,065'— 11,400 X 0.4176 ft3/ft X 1.4 (40% excess) = 389ft3 Total Volume = 389 ft3 => 169 sx of 15.8 ppg Class G @ 2.3 ft3 /sk (10,235'-9,985') X 0.1584 ft3/ft X 1.0 (0% excess) = 40 ft3 Plug #2 (Isolation) from 11,400' MD to 10,735' with 12.2 ppg Class G + additives 8-3/4" Open Hole (11,400'— 10,735') X 0.4176 ft3/ft X 1.4 (40% excess) = 389ft3 Total Volume = 389 ft3 => 169 sx of 15.8 ppg Class G @ 2.3 ft3 /sk Plug #3 (Kick-off) from 10,735' MD to 10,035' MD with 17.0 ppg Class G + additives 8-3/4" Open Hole (10,735'— 10,2351 X 0.4176 ft3/ft X 1.4 (40% excess) = 292 ft3 9-5/8" Casing (10,235'— 10,035) X 0.4257 ft3/ftX 1.0 (0% excess) = 85 ft3 Total Volume = 292 + 85 = 377 ft3 => 377 sx of 17.0 ppg Class G + additives @ 1.00 ft;/sk 7" Intermediate liner run to 12.080' MD / 7,911' TVD Top of slurry is designed to be at liner top at 9,985' MD. Assume 40% excess annular volume. 6" x 8-3/4" underreamer to be 100ft behind the drill bit. Tail slurry from 12,080' MD to 9,985' MO with 15.8 ppg Class G + additives 8-3/4" Hole to Casing shoe (12,080'— 10,235') X 0.1503 ft3/ft X 1.40 (40% excess) = 388 ft3 Liner Lap (10,235'-9,985') X 0.1584 ft3/ft X 1.0 (0% excess) = 40 ft3 Shoe Joint (80') X 0.2148 ft3/ft X 1.0 (0% excess) = 17 ft3 Total Volume = 388+ 40 + 17 = 445 ft3 => 380 sx of 15.8 ppg Class G + 0.20/a D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.17 ft3/sk MT6-08 APD Page 15 of 15 Printed: 18 -Apr -18 Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 Attachment 2 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16" Hole 113-3/8" Casino Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low 3rd well on Pad, traveling cylinder diagrams Gas Hydrates Low If observed — control drill, reduce pump rates and Hole swabbing on trips Medium circulating time reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, Increase mud weight, use weighted sweeps, Abnormal Pressure in Low reduce fluid viscosity,control ROP Abnormal Pressure in Low Diverter drills, increased mud weight. Shallow Surface Formations hazard study noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost Abnormal Reservoir Low circulation material, use of low density cement Pressure slurries port collar, control pipe running seeds 12-1/4" Hole / 9-5/8" Casino Interval Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time hole ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, Lost circulation Medium proper hole filling, pump out of hole, real time ECD monitoring,MPD stripping ractices Abnormal Pressure in Low Well control drills, check for flow during Overburden Formations Medium connections, increase mud weight. Shallow hazard study noted minimal risk Hole Cleaning Low Monitor ECD and torque/drag trends, control drill Abnormal Reservoir Low and use best hole cleaning radices 8-3/4" Pilot Hole - Casino Interval Event Risk Level Mitigation Strategy Sloughing shale, Tight High MPD pressure control for shale stability, increase hole mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating densi ECD monitorin Lost circulation Medium Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring,MPD stripping radices Abnormal Reservoir Low Well control drills, check for flow during Pressure connections increase mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers MT6-08 APD Page 16 of 15 Pnnted: 18 -Apr -18 Application for Pennit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 6" x 8-3/4" Hole / 7" Liner - Casino Interval Event Risk Level Mitigation Strate Sloughing shale, Tight High MPD for shale stability, Steerable Drilling Liner, hole Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent Hole swabbing on trips Medium circulating density (ECD) monitoring, run casing as liner Lost circulation Medium Reduce pump rates, reduce trip speeds, real time Abnormal Reservoir Low ECD monitoring, mud rheology, add lost circulation Pressure material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD Hydrogen Sulfide gas Low monitoring,Liner will be in place at TD Abnormal Reservoir Low Well control drills, check for flow during Pressure connections increase mud weight Hydrogen Sulfide gas Low HzS drills, detection systems, alarms, standard well control practices, mud scavengers 6" Hole / 4-1/2" Pre -Perforated Liner - Horizontal Production Hole Event Risk Level Miticiation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Low Well control drills, check for flow during Pressure connections increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low HzS drills, detection systems, alarms, standard well control practices mud scavengers MT6-08 APD Page 17 of 15 Printed: 18 -Apr -18 Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 Well Proximitv Risks: MT6-08 will be the third well drilled on the pad. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: i Reservoir Pressure: Offset production has the potential to reduce the reservoir pressure. LCM material will be on location to deal with losses. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach in the pilot and intermediate #2 hole sections will require higher mud weights than historically used to enhance wellbore stability. Steerable Drilling Liner and Managed Pressure Drilling will be used in conjunction with a 4 -string casing design to mitigate shale instability in the aforementioned formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks MT6-O8 APD Page 18 of 15 Printed: 18 -Apr -18 Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 Attachment 3 — Completion Schematic MT6-08 Multi -Lateral Injector wp04 DRAFT Completion Schematic as of 4-13-18 'A 11,873' MD I 7884' TVD Pilot Hole (PE 12,065' MO 8,046 TVD L� I'.f ' 7" 26 ppf L-80 Tenaris Blue Liner 6" Rote, TD at 5�' S to 12,68D MD 1791 1'TVD @ 83 deg at 20,506' MD / 7890' TVD 1 G� 04/13I201s -TGP 20" 79 ppf H-40 Insulated Page 19 of 15 a Conductor li 79 feet, cemented to surface Tubing f Liner completion: ` i) 4-W* Landing Hippie(3.813' ID) 2) VW x 1' GLM 3) 4-Wxl*GLM 4) 4-112 x 1• GLM `'. 13318" 68 ppf L-80 TXP Surface casing 5) Liner Top Packer I Hanger @ 2056' MD 12035' TVD wl Tie Back sleeve cemerded to surface O 6) LEM and Hook Hanger 7) Liner Top Packer I Hanger wl Te Back Sleeve 41-111TA2 ppf L-80 Blue to -1 1,930 MD 8) 4-W Landing Nipple (3.725' NoGo) -1 %r Ir s i ` ' ° 0- 9) 414' Blue Blank Pipe 7" 26 ppf i Tenaris BTC Tieback 10) 4 %' Blue Liner with Pad Joints to 9,985' MD 16,986' TVD @ 55' IE7 'i:!G) TOL @ 9,985' MD 16,986' TVD @ 55' 6r # �. 9 S'6" 40 ppf L-80 UP (to 5847' MD) 9 5.r8" 40 ppf TIN .80 HC (to TD) I, Q 10,235' MD 17130' TVD TOC of 95f8 -9,2351t MD L� I'.f ' 7" 26 ppf L-80 Tenaris Blue Liner 6" Rote, TD at 5�' S to 12,68D MD 1791 1'TVD @ 83 deg at 20,506' MD / 7890' TVD 1 G� 04/13I201s -TGP MT6 08 APD Page 19 of 15 Printed: 18 -Apr -18 In"A�Ij 901A_ _ Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 Attachment 4 —Area of Review MT608 and MT6081_1 Area of Review: This Area of Review is required as MT6-08 and MT6-08L1 are being permitted as and Alpine C sand injector. There are no wells the fall with % mile of the well's entry point into the Alpine C sand. Existing wells are colored red. Future wells scheduled to be drilled prior to MT6-08 in blue. MTS-08-wp04 Lower Lat Quarter Mile View 15000 11-00 *1 c N O 9000 L 0 O Z 6000 Y rR 3000 0- _15000 -12000 -9000 -6000 -3000 0 3000 6000 9000 West( -)/East(+) (3000 usfUin) MT6-08 APD Page 20 of 15 Printed: 18 -Apr -18 8 t �Q MT6-08 APD Page 20 of 15 Printed: 18 -Apr -18 oK�1—MT6-OS-wp04 Lower Lat Na M6A. MOUO_Vptl II Pn Ytt9�, Nf64! Application for Permit to Drill, Well MTU MT6-08 Saved: 18 -Apr -18 3D Quarter Mile View .,m. I I.., 18000 1 6flOO 1 4 aqq +zaao +0000 8000 Attachment 5— Directional Plan MT6-08 and MT6-08PBI MT6-08vvil Objective: Planned final wellpath for Injector GMTU MT6-08 MT6-08PB1wg04 Objective: Planned intermediate pilot hole for GMTU MT6-08 to access Alpine C reservoir top, thickness and quality. MT6-08 APD Page 21 of 15 Printed. 18 -Apr -18 *111 ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope Plan: GMT1 Lookout Pad Plan: Well #8_GMT1-C2 Wellbore #8 Plan: MT6-08-wp04 Lower Lat Directional Summary Report 23 January, 2018 ill Wellbore #8 gnstics Model Name Sample Date Declination Dip Angle Field Strength 11) (°) (nT) BGGM2017 8/6/2018 16.38 80.71 57,415 Design ConocoPhillips ConocoPhillips Audit Notes: Well Directional Summary Report Version: Company: ConocePhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #8_Glvl Project: Western North Slope TVD Reference: WELL aQ 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MD Reference: WELL @ 70.00usft (Original Well Elev) Well: Plan: Well #e_GMT1-C2 North Reference: True Wellbore: Wellbore #8 Survey Calculation Method: Minimum Curvature Design: MT6-08-wp04 Lower Let Database: EDT Alaska Prod Project Western North Slope, North Slope Alaska, United States Ground Level: 34.00 usft Map System: US State Plane 1983 - _ � System Datum: Mean Sea Level Geo Datum: North American Datum 1983 / Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale (actor Site Plan: GMT1 Lookout Pad Site Position: Northing: 5,945,316.00 usft Latitude: 70728!*52.049W From: Map Easting: 1,457,169.00 usft Longitude: 151° Position Uncertainty: 0.00 usft Slot Radius: 0 " Grid Convergence: ill Wellbore #8 gnstics Model Name Sample Date Declination Dip Angle Field Strength 11) (°) (nT) BGGM2017 8/6/2018 16.38 80.71 57,415 Design MT608-wp04 Lower Lat Audit Notes: Well Plan'. Weil #B GMT1-C2 Version: Phase: PLAN Tie On Depth: 36.00 Well Position +N/ -S 0.00 usft Northing: 5,945,268.00 usft Latitude: 70° 15'21.503 N (usft) +E/ -W 0.00 usft Easting: 1,457,038.00 usft Longitude: 151° 28'55.825 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 34.00 usft ill Wellbore #8 gnstics Model Name Sample Date Declination Dip Angle Field Strength 11) (°) (nT) BGGM2017 8/6/2018 16.38 80.71 57,415 Design MT608-wp04 Lower Lat Audit Notes: Version: Phase: PLAN Tie On Depth: 36.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 36,00 0.00 0.00 331.89 1/23/2018 10.22:16AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConomPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: Plan: GMT1 Lookout Pad Well: Plan: Well #8_GMT1-C2 Wellbore: Wellbore #8 Design: MT6-08-wp04 Lower Let Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: Well #8_GMTt-C2 WELL @ 70.00usft (Original Well Elev) WELL @ 70.00usft (Original Well Elev) True Minimum Curvature EDT Alaska Prod Survey Tool Program Date 1/23/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 36.00 300.00 MT6-08-wp04 Lower Lat (Wellbore #8) BLIND Blind drilling 300.00 2,056.00 MT6-08-wp04 Lower Lat (Wellbore #8) MWD MWD -Standard 300.00 2,056.00 MT6-08-wp04 Lower Let (Wellbore #8) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 2,056.00 10,236.00 MT6-08-wp04 Lower Let (Wellbore #8) MWD MWD - Standard 2,056.00 10,236.00 MT6-08-wp04 Lower Lat (Wellbore #8) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 10,236.00 12,080.00 MT6-08-wp04 Lower Let (Wellbore #8) MWD MWD -Standard 10,236.00 12,080.00 MT6-08-wp04 Lower Let( Wellbore #8) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 12,080.00 20,506.42 MT6-08-wp04 Lower Let (Wellbore #8) MWD MWD -Standard 12,080.00 20,506.42 MT&08-wp04 Lower Let (Wellbore #8) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. See Northing Easgng (usft) (°) (°) (usft) (usft) (11100usft) (°) Wait) (usft) (usft) 36.00 0.00 0.00 36.00 -34.00 0.00 0.00 0.00 5,945,268.00 1,457,038.00 100.00 0.00 0.00 100.00 30.00 0.00 0.00 0.00 5,945,268.00 1,457,038.00 200.00 0.00 0.00 200.00 130.00 0.00 0.00 0.00 5,945,268.00 1,457,038.00 300.00 0.00 0.00 300.00 230.00 0.00 0.00 0.00 5,945,266.00 1,457,038.00 400.00 0.00 0.00 400.00 330.00 0.00 0.00 0.00 5,945,268.00 1,457,038.00 500.00 0.00 0.00 500.00 430.00 0.00 0.00 0.00 5,945,268.00 1,457,038.00 600.00 0.00 0.00 600.00 530.00 0.00 0.00 0.00 5,945,268.00 1,457,038.00 700.00 0.00 0.00 700.00 630.00 0.00 0.00 0.00 5,945,268.00 1,457,03B.00 800.00 0.00 0.00 800.00 730.00 0.00 0.00 0.00 5,945,268.00 1,457,036.00 900.00 0.00 0.00 900.00 830.00 0.00 0.00 0.00 5,945,268.00 1,457,038.00 1,000.00 0.00 0.00 1,000.00 930.00 0.00 0.00 0.00 5,945,268.00 1,457,038.00 1,036.00 0.00 0.00 1,036.00 966.00 0.00 0.00 0.00 5,945,268.00 1,457,038.00 Start Build 2.00 1,100.00 1.28 330.00 1,099.99 1,029.99 2.00 330.00 0.71 5,945,268.63 1,457,037.66 1,200.00 3.28 330.00 1,199.91 1,129.91 2.00 0.00 4.69 5,945,272.12 1,457,035.75 1,300.00 5.28 330.00 1,299.63 1,229.63 2.00 0.00 12.15 5,945,278.67 1,457,032.18 123/2018 10:22:16AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #8 GMT1-C2 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MD Reference: WELL @ 70.00usft (Original Well Elev) Well: Plan: Well #e_GMT1-C2 North Reference: True Wellbore: Wellbore #8 Survey Calculation Method: Minimum Curvature Design: MT6-08-wp04 Lower Let Database: EDT Alaska Prod Planned Survey MD Inc Azl(azimuth) TVD TVDSS DLeg TFace V. Sec Northing Essgng (usft) (°) (°) (usft) (usft) (°/100usft) (') (usft) (usft) (-ft) 1,400.00 7.28 330.00 1,399.02 1,329.02 2.00 0.00 23.08 5,945,288.27 1,457,026.94 1,500.00 9.28 330.00 1,497.97 1,427.97 2.00 0.00 37.47 5,945,300.92 1,457,020.05 1,600.00 11.28 330.00 1,596.36 1,526.36 2.00 0.00 55.31 5,945,316.58 1,457,011.51 1,700.00 13.28 330.00 1,694.07 1,624.07 2.00 0.00 76.57 5,945,335.25 1,457,001.33 1,800.00 15.28 330.00 1,790.98 1,720.98 2.00 0.00 101.22 5,945,356.91 1,456,989.52 1,900.00 17.28 330.00 1,886.96 1,816.96 2.00 0.00 129.23 5,945,381.51 1,456,976.10 2,000.00 19.28 330.00 1,981.91 1,911.91 2.00 0.00 160.58 5,945,409.05 1,456,961.08 2,029.81 19.88 330.00 2,010.00 1,940.00 2.00 0.00 170.57 5,945,417.82 1,456,956.30 Start 80.00 hold at 2029.81 MD 2,056.00 19.88 330.00 2,034.63 1,964.63 0.00 0.00 179.46 5,945,425.63 1,456,952.04 13-3/8" x 16" 2,100.00 19.88 330.00 2,076.01 2,006.01 0.00 0.00 194.42 5,945,438.77 1,456,944.88 2,109.61 19.88 330.00 2,085.23 2,015.23 0.00 0.00 197.75 5,945,441.70 1,456,943.28 Start DLS 2.00 TFO 0.58 2,123.97 20.16 330.01 2,098.54 2,026.54 2.00 0.58 202.60 5,945,445.95 1,456,940.96 C-30 2,200.00 21.68 330.05 2,169.55 2,099.55 2.00 0.58 229.73 5,945,469.79 1,456,927.98 2,300.00 23.68 330.10 2,261.81 2,191.81 2.00 0.54 268.26 5,945,503.66 1,456,909.56 2,400.00 25.68 330.14 2,352.68 2,282.68 2.00 0.49 310.00 5,945,540.36 1,456,889.65 2,500.00 27.68 330.17 2,442.02 2,372.02 2.00 0.46 354.87 5,945,579.83 1,456,868.26 2,514.58 27.97 330.18 2,454.92 2,384.92 2.00 0.43 361.68 5,945,585.81 1,456,865.02 C-10 2,600.00 29.68 330.20 2,529.75 2,459.75 2.00 0.42 402.84 5,945,622.03 1,456,845.42 2,700.00 31.68 330.23 2,615.75 2,545.75 2.00 0.40 453.84 5,945,666.91 1,456,821.16 2,600.00 33.68 330.25 2,699.92 2,629.92 2.00 0.38 507.81 5,945,714.42 1,456,795.52 2,900.00 35.68 330.27 2,782.15 2,712.15 2.00 0.36 564.68 5,945,764.49 1,456,768.51 3,000.00 37.66 330.29 2,862.34 2,792.34 2.00 0.34 624.39 5,945,817.07 1,456,740.17 3,100.00 39.68 330.31 2,940.40 2,870.40 2.00 0.33 686.86 5,945,872.09 1,456,710.54 1/232018 10:22:16AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #8_GMT1-C2 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MD Reference: WELL @ 70.00usft (Original Well Elev) Well: Plan: Well #8_GMT1-C2 North Reference: True Wellbore: Wellbore #8 Survey Calculation Method: Minimum Curvature Design: MT6-08-wp04 Lower Let Database: EDT Alaska Prod Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TPace V. Sec Northing Easting (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) (usft) 3,200.00 41.68 330.33 3,016.24 2,946.24 2.00 0.31 752.01 5,945,929.48 1,456,679.66 3,300.00 43.68 330.34 3,089.75 3,019.75 2.00 0.30 819.77 5,945,989.18 1,456,647.55 3,400.00 45.68 330.36 3,160.85 3,090.85 2.00 0.29 890.06 5,946,051.11 1,456,614.27 3,500.00 47.68 330.37 3,229.45 3,159.45 2.00 0.28 962.78 5,946,115.19 1,456,579.85 3,600.00 49.68 330.38 3,295.48 3,225.48 2.00 0.27 1,037.86 5,946,181.35 1,456,544.33 3,700.00 51.68 330.39 3,358.84 3,288.84 2.00 0.26 1,115.19 5,946,249.51 1,456,507.75 3,763.09 52.94 330.40 3,397.41 3,327.41 2.00 0.25 1,165.09 5,946,293.50 1,456,484.16 K-3 3,800.00 53.68 330.40 3,419.47 3,349.47 2.00 0.25 1,194.68 5,946,319.59 1,456,470.17 3,855.70 54.79 330.41 3,452.02 3,382.02 2.00 0.25 1,239.86 5,946,359.41 1,456,448.81 Start 7113.89 hold at 3855.70 MD 3,900.00 54.79 330.41 3,477.56 3,407.56 0.00 0.00 1,276.05 5,946,391.32 1,456,431.71 4,000.00 54.79 330.41 3,535.21 3,465.21 0.00 0.00 1,357.73 5,946,463.32 1,456,393.11 4,100.00 54.79 330.41 3,592.86 3,522.86 0.00 0.00 1,439.41 5,946,535.33 1,456,354.51 4,200.00 54.79 330.41 3,650.52 3,580.52 0.00 0.00 1,521.09 5,946,607.34 1,456,315.90 4,300.00 54.79 330.41 3,708.17 3,638.17 0.00 0.00 1,602.77 5,946,679.35 1,456,277.30 4,400.00 54.79 330.41 3,765.82 3,695.82 0.00 0.00 1,684.45 5,946,751.36 1,456,238.70 4,500.00 54.79 330.41 3,823.48 3,753.48 0.00 0.00 1,766.13 5,946,823.36 1,456,200.10 4,600.00 54.79 330.41 3,881.13 3,811.13 0.00 0.00 1,847.81 5,946,895.37 1,456,161.49 4,688.55 54.79 330.41 3,932.18 3,862.18 0.00 0.00 1,920.14 5,946,959.14 1,456,127.31 Albian 97 4,700.00 54.79 330.41 3,938.78 3,868.78 0.00 0.00 1,929.49 5,946,967.38 1,456,122.89 4,800.00 54.79 330.41 3,996.43 3,926.43 0.00 0.00 2,011.17 5,947,039.39 1,456,084.29 4,900.00 54.79 330.41 4,054.09 3,984.09 0.00 0.00 2,092.85 5,947,111.40 1,456,045.69 5,000.00 54.79 330.41 4,111.74 4,041.74 0.00 0.00 2,174.53 5,947,183.40 1,456,007.08 5,100.00 54.79 330.41 4,169.39 4,099.39 0.00 0.00 2,256.21 5,947,255.41 1,455,968.46 1232018 10:22:16AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #8_GMT1-C2 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plana GMT1 Lookout Pad MD Reference: WELL @ 70.00usft (Original Well Elev) Well: Plan: Well #8_GMT1-C2 North Reference: True Wellbore: Wellbore #8 Survey Calculation Method: Minimum Curvature Design: MT6-08-wp04 Lower Let Database: EDT Alaska Prod Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Fasting (usft) (•) (°) (usft) (usft) (°1100usf) (°) (usft) (usft) (usft) 5,133.28 54.79 330.41 4,188.58 4,118.58 0.00 0.00 2,283.40 5,947,279.38 1,455,955.63 Albian 96 5,200.00 54.79 330.41 4,227.05 4,157.05 0.00 0.00 2,337.89 5,947,327.42 1,455,929.88 5,300.00 54.79 330.41 4,284.70 4,214.70 0.00 0.00 2,419.57 5,947,399.43 1,455,891.27 5,400.00 54.79 330.41 4,342.35 4,272.35 0.00 0.00 2,501.25 5,947,471.44 1,455,852.67 5,500.00 54.79 330.41 4,400.00 4,330.00 0.00 0.00 2,582.94 5,947,543.44 1,455,814.07 5,600.00 54.79 330.41 4,457.66 4,387.66 0.00 0.00 2,664.62 5,947,615.45 1,455,775.47 5,700.00 54.79 330.41 4,515.31 4,445.31 0.00 0.00 2,746.30 5,947,687.46 1,455,736.86 5,724.80 54.79 330.41 4,529.61 4,459.61 0.00 0.00 2,766.56 5,947,705.32 1,455,727.29 Albian 95 5,800.00 54.79 330.41 4,572.96 4,502.96 0.00 0.00 2,827.98 5,947,759.47 1,455,698.26 5,900.00 54.79 330.41 4,630.62 4,560.62 0.00 0.00 2,909.66 5,947,831.48 1,455,659.66 6,000.00 54.79 330.41 4,688.27 4,618.27 0.00 0.00 2,991.34 5,947,903.48 1,455,621.06 6,100.00 54.79 330.41 4,745.92 4,675.92 0.00 0.00 3,073.02 5,947,975.49 1,455,582.45 6,200.00 54.79 330.41 4,803.57 4,733.57 0.00 0.00 3,154.70 5,948,047.50 1,455,543.85 6,300.00 54.79 330.41 4,861.23 4,791.23 0.00 0.00 3,236.38 5,948,119.51 1,455,505.25 6,400.00 54.79 330.41 4,918.88 4,848.88 0.00 0.00 3,318.06 5,948,191.52 1,455,466.64 6,500.00 54.79 330.41 4,976.53 4,906.53 0.00 0.00 3,399.74 5,948,263.52 1,455,428.04 6,600.00 54.79 330.41 5,034.19 4,964.19 0.00 0.00 3,481.42 5,948,335.53 1,455,389.44 6,700.00 54.79 330.41 5,091.84 5,021.84 0.00 0.00 3,563.10 5,948,407.54 1,455,350.64 6,800.00 54.79 330.41 5,149.49 5,079.49 0.00 0.00 3,644.78 5,948,479.55 1,455,312.23 6,900.00 54.79 330.41 5,207.15 5,137.15 0.00 0.00 3,726.46 5,948,551.56 1,455,273.63 7,000.00 54.79 330.41 5,264.80 5,194.80 0.00 0.00 3,808.14 5,948,623.56 1,455,235.03 7,100.00 54.79 330.41 5,322.45 5,252.45 0.00 0.00 3,889.82 5,948,695.57 1,455,196.43 7,200.00 54.79 330.41 5,380.10 5,310.10 0.00 0.00 3,971.50 5,948,767.58 1,455,157.82 7,300.00 54.79 330.41 5,437.76 5,367.76 0.00 0.00 4,053.18 5,948,839.59 1,455,119.22 7,400.00 54.79 330.41 5,495.41 5,425.41 0.00 0.00 4,134.87 5,948,911.60 1,455,080.62 123/2018 10:22:16AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #8_GMT7-C2 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plan: GMTt Lookout Pad MD Reference: WELL @ 70.00usft (Original Well Elev) Well: Plan: Well #8_GMT1-C2 North Reference: True Wellbore: Wellbore #8 Survey Calculation Method: Minimum Curvature Design: MT6-0"p04 Lower Let Database: EDT Alaska Prod Planned Survey MD Inc AN (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (°) (°) (usft) (usft) (°/100usft) V) (usft) (usft) (usft) 7,500.00 54.79 330.41 5,553.06 5,483.06 0.00 0.00 4,216.55 5,948,983.60 1455,042.01 7,600.00 54.79 330.41 5,610.72 5,540.72 0.00 0.00 4,298.23 5,949,055.61 1,455,003.41 7,700.00 54.79 330.41 5,668.37 5,598.37 0.00 0.00 4,379.91 5,949,127.62 1,454,964.81 7,800.00 54.79 330.41 5,726.02 5,656.02 0.00 0.00 4,461.59 5,949,199.63 1,454,926.21 7,812.75 54.79 330.41 5,733.37 5,663.37 0.00 0.00 4,472.00 5,949,208.81 1,454,921.29 Albian 94 7,900.00 54.79 330.41 5,783.67 5,713.67 0.00 0.00 4,543.27 5,949,271.64 1,454,887.60 8,000.00 54.79 330.41 5,841.33 5,771.33 0.00 0.00 4,624.95 5,949,343.64 1,454,849.00 8,100.00 54.79 330.41 5,898.98 5,828.98 0.00 0.00 4,706.63 5,949,415.65 1,454,810.40 8,200.00 54.79 330.41 5,956.63 5,886.63 0.00 0.00 4,788.31 5,949,487.66 1,454,771.80 8,300.00 54.79 330.41 6,014.29 5,944.29 0.00 0.00 4,869.99 5,949,559.67 1,454,733.19 8,400.00 54.79 330.41 6,071.94 6,001.94 0.00 0.00 4,951.67 5,949,631.68 1,454,694.59 8,500.00 54.79 330.41 6,129.59 6,059.59 0.00 0.00 5,033.35 5,949,703.68 1,454,655.99 8,600.00 54.79 330.41 6,187.24 6,117.24 0.00 0.00 5,115.03 5,949,775.69 1,454,617.38 8,700.00 54.79 330.41 6,244.90 6,174.90 0.00 0.00 5,196.71 5,949,847.70 1,454,578.78 8,760.78 54.79 330.41 6,279.94 6,209.94 0.00 0.00 5,246.36 5,949,891.47 1,454,555.32 Ahlian 93 8,800.00 54.79 330.41 6,302.55 6,232.55 0.00 0.00 5,278.39 5,949,919.71 1,454,540.18 8,900.00 54.79 330.41 6,360.20 6,290.20 0.00 0.00 5,360.07 5,949,991.72 1,454,501.58 9,000.00 54.79 330.41 6,417.86 6,347.86 0.00 0.00 5,441.75 5,950,063.72 1,454,462.97 9,100.00 54.79 330.41 6,475.51 6,405.51 0.00 0.00 5,523.43 5,950,135.73 1,454,424.37 9,200.00 54.79 330.41 6,533.16 6,463.16 0.00 0.00 5,605.12 5,950,207.74 1,454,385.77 9,300.00 54.79 330.41 6,590.81 6,520.81 0.00 0.00 5,686.80 5,950,279.75 1,454,347.17 9,400.00 54.79 330.41 6,648.47 6,578.47 0.00 0.00 5,768.48 5,950,351.76 1,454,308.56 9,500.00 54.79 330.41 6,706.12 6,636.12 0.00 0.00 5,850.16 5,950,423.76 1,454,269.96 9,542.41 54.79 330.41 6,730.57 6,660.57 0.00 0.00 5,894.80 5,950,454.30 1,454,253.59 Top Fill 1232018 10:22:16AM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: Con000Phillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #B GMT1-C2 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MD Reference: WELL @ 70.00usft (Original Well Elev) Well: Plan: Well #B_GMTt-C2 North Reference: True Wellbore: Wellbore #8 Survey Calculation Method: Minimum Curvature Design: MT6-08-wp04 Lower Let Database: EDT Alaska Prod Planned Survey MD Inc Azl(azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easfing (usft) (°) (°) (usft) (usft) (°1100usft) (°) (usft) (usft) (usft) 9,600.00 54.79 330.41 6,763.77 6.693.77 0.00 0.00 5,931.84 5950,495.77 1,454,231.36 9,700.00 54.79 330.41 6,621.43 6,751.43 0.00 0.00 6,013.52 5,950,567.76 1,454,192.76 9,800.00 54.79 330.41 6,679.08 6,809.08 0.00 0.00 6,095.20 5,950,639.79 1,454,154.15 9,900.00 54.79 330.41 6,936.73 6,866.73 0.00 0.00 6,176.88 5,950,711.80 1,454,115.55 10,000.00 54.79 330.41 6,994.38 6,924.38 0.00 0.00 6,258.56 5,950,763.80 1,454,076.95 10,100.00 54.79 330.41 7,052.04 6,982.04 0.00 0.00 6,340.24 5,950,855.81 1,454,038.34 10,200.00 54.79 330.41 7,109.69 7,039.69 0.00 0.00 6,421.92 5,950,927.82 1,453,999.74 10,235.31 54.79 330.41 7,130.05 7,060.05 0.00 0.00 6,450.77 5,950,953.25 1,453,986.11 HRZ Slump - 94118" x 12-1/4" 10,300.00 54.79 330.41 7,167.34 7,097.34 0.00 0.00 6,503.60 5,950,999.83 1,453,961.14 10,400.00 54.79 330.41 7,225.00 7,155.00 0.00 0.00 6,585.28 5,951,071.84 1,453,922.54 10,500.00 54.79 330.41 7,282.65 7,212.65 0.00 0.00 6,666.96 5,951,143.84 1,453,883.93 10,600.00 54.79 330.41 7,340.30 7,270.30 0.00 0.00 6,748.64 5,951,215.85 1,453,845.33 10,700.00 54.79 330.41 7,397.96 7,327.96 0.00 0.00 6,830.32 5,951,287.86 1,453,806.73 10,732.44 54.79 330.41 7,416.66 7,346.66 0.00 0.00 6,856.82 5,951,311.22 1,453,794.20 LCU 10,800.00 54.79 330.41 7,455.61 7,385.61 0.00 0.00 6,912.00 5,951,359.87 1,453,768.13 10,900.00 54.79 330.41 7,513.26 7,443.26 0.00 0.00 6,993.68 5,951,431.88 1,453,729.52 10,969.59 54.79 330.41 7,553.38 7,483.38 0.00 0.00 7,050.52 5,951,481.98 1,453,702.66 Start US 3.00 TFO 6.07 11,000.00 55.70 330.51 7,570.72 7,500.72 3.00 5.07 7,075.50 5,951,504.02 1,453,690.87 11,100.00 58.69 330.81 7,624.89 7,554.89 3.00 5.01 7,159.53 5,951,578.26 1,453,651.49 11,200.00 61.66 331.10 7,674.60 7,604.60 3.00 4.84 7,246.27 5,951,655.10 1,453,611.24 11,300.00 64.67 331.37 7,719.72 7,649.72 3.00 4.70 7,335.49 5,951,734.34 1,453,570.23 11,400.00 67.66 331.63 7,760.12 7,690.12 3.00 4.58 7,426.95 5,951,815.76 1,453,528.57 11,500.00 70.65 331.88 7,795.70 7,725.70 3.00 4.47 7,520.40 5,951,899.12 1,453,486.37 11,600.00 73.64 332.12 7,826.35 7,756.35 3.00 4.39 7,615.57 5,951,984.22 1,453,443.75 11,700.00 76.64 332.35 7,852.00 7,782.00 3.00 4.31 7,712.22 5,952,070.80 1,453,400.83 123/2018 10:22:16AM Page 8 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #8 GMT1-C2 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MD Reference: WELL @ 70.00usft (Original Well Elev) Well: Plan: Well #8_GMT1-C2 North Reference: True Wellbore: Wellbore #8 Survey Calculation Method: Minimum Curvature Design: MT6-08-wp04 Lower Let Database: EDTAlaska Prod Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (°) (°) (usft) (usft) (°1100usft) (°) (usft) (usft) (usft) 11,800.00 79.63 332.58 7,872.56 7,802.56 3.00 4.25 7,810.06 5,952,158.64 1,453,357.72 11,873.19 81.82 332.74 7,884.36 7,814.36 3.00 4.21 7,882.28 5,952,223.58 1,453,326.12 Alpine C 11,898.01 82.50 332.79 7,887.47 7,817.47 3.00 4.18 7,904.89 5,952,243.93 1,453,316.27 Start 50.00 hold at 11896.01 MD 11,900.00 82.50 332.79 7,887.99 7,817.99 0.00 0.00 7,908.84 5,952,247.49 1,453,314.54 11,946.01 82.50 332.79 7,894.00 7,824.00 0.00 0.00 7,954.46 5,952,288.55 1,453,294.68 Start 212.80 hold at 11946.01 MD 12,000.00 82.50 332.79 7,901.05 7,831.05 0.00 0.00 8,007.97 5,952,336.73 1,453,271.37 12,080.00 82.50 332.79 7,911.49 7,841.49 0.00 0.00 8,087.28 5,952,408.13 1,453,236.94 7" z 8.314" 12,100.00 82.50 332.79 7,914.10 7,844.10 0.00 0.00 8,107.11 5,952,425.98 1,453,228.20 12,158.81 82.50 332.79 7,921.78 7,851.78 0.00 0.00 6,165.41 5,952,478.46 1,453,202.81 Start DLS 2.72 TFO -5.96 12,200.00 83.61 332.67 7,926.75 7,856.75 2.72 -5.96 8,206.29 5,952,515.25 1,453,184.97 12,300.00 86.32 332.39 7,935.53 7,865.53 2.72 -5.95 8,305.89 5,952,604.71 1,453,141.20 12,325.23 87.00 332.32 7,937.00 7,867.00 2.72 -5.92 8,331.08 5,952,627.30 1,453,130.05 Start DLS 4.00 TFO 14.17 12,400.00 89.90 333.05 7,939.02 7,869.02 4.00 14.17 8,405.80 5,952,694.51 1,453,097.39 12,411.53 90.35 333.16 7,939.00 7,869.00 4.00 14.15 8,417.32 5,952,704.91 1,453,092.43 Start 8094.92 hold at 12411.63 MD 12,500.00 90.35 333.16 7,938.46 7,868.46 0.00 0.00 8,505.77 5,952,784.80 1,453,054.43 12,600.00 90.35 333.16 7,937.86 7,867.86 0.00 0.00 8,605.75 5,952,875.10 1,453,011.47 12,700.00 90.35 333.16 7,937.25 7,867.25 0.00 0.00 8,705.72 5,952,965.39 1,452,968.52 12,800.00 90.35 333.16 7,936.65 7,866.65 0.00 0.00 8,805.69 5,953,055.69 1,452,925.57 12,900.00 90.35 333.16 7,936.04 7,866.04 0.00 0.00 8,905.67 5,953,145.99 1,452,882.61 13,000.00 90.35 333.16 7,935.44 7,865.44 0.00 0.00 9,005.64 5,953,236.28 1,452,839.66 1/23/2018 10:22:16AM Page 9 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #e GMT1-C2 Project: V& -stem North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MD Reference: WELL (a3 70.00usft (Original Well Elev) Well: Plan: Well #8_GMT1-C2 North Reference: True Wellbore: Wellbore #8 Survey Calculation Method: Minimum Curvature Design: MT6-08-wp04 Lower Let Database: EDT Alaska Prod Planned Survey MD Inc Aid (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (°) (°) (usft) (usft) (1100usit) (°) (usft) (usft) (usft) 13,055.89 90.35 333.16 7,935.10 7,865.10 0.00 0.00 9,061.52 5,953,286.75 1,452,815.65 UJU 13,100.00 90.35 333.16 7,934.83 7,864.83 0.00 0.00 9,105.61 5,953,326.58 1,452,796.71 13,200.00 90.35 333.16 7,934.22 7,864.22 0.00 0.00 9,205.59 5,953,416.87 1,452,753.75 13,300.00 90.35 333.16 7,933.62 7,863.62 0.00 0.00 9,305.56 5,953,507.17 1,452,710.80 13,400.00 90.35 333.16 7,933.01 7,863.01 0.00 0.00 9,405.53 5,953,597.47 1,452,667.84 13,500.00 90.35 333.16 7,932.41 7,862.41 0.00 0.00 9,505.51 5,953,687.76 1,452,624.89 13,540.44 90.35 333.16 7,932.16 7,862.16 0.00 0.00 9,545.94 5,953,724.28 1,452,607.52 uJU 13,600.00 90.35 333.16 7,931.80 7,861.80 0.00 0.00 9,605.48 5,953,778.06 1,452,581.94 13,700.00 90.35 333.16 7,931.20 7,861.20 0.00 0.00 9,705.45 5,953,868.35 1,452,538.98 13,800.00 90.35 333.16 7,930.59 7,860.59 0.00 0.00 9,805.43 5,953,958.65 1,452,496.03 13,900.00 90.35 333.16 7,929.99 7,859.99 0.00 0.00 9,905.40 5,954,048.95 1,452,453.08 14,000.00 90.35 333.16 7,929.38 7,859.38 0.00 0.00 10,005.37 5,954,139.24 1,452,410.12 14,100.00 90.35 333.16 7,928.78 7,858.78 0.00 0.00 10,105.35 5,954,229.54 1,452,367.17 14,200.00 90.35 333.16 7,928.17 7,858.17 0.00 0.00 10,205.32 5,954,319.83 1,452,324.21 14,300.00 90.35 333.16 7,927.57 7,857.57 0.00 0.00 10,305.29 5,954,410.13 1,452,281.26 14,400.00 90.35 333.16 7,926.96 7,856.96 0.00 0.00 10,405.27 5,954,500.43 1,452,238.31 14,500.00 90.35 333.16 7,926.36 7,856.36 0.00 0.00 10,505.24 5,954,590.72 1,452,195.35 14,600.00 90.35 333.16 7,925.75 7,855.75 0.00 0.00 10,605.21 5,954,681.02 1,452,152.40 14,700.00 90.35 333.16 7,925.15 7,855.15 0.00 0.00 10,705.19 5,954,771.31 1,452,109.45 14,800.00 90.35 333.16 7,924.54 7,854.54 0.00 0.00 10,805.16 5,954,861.61 1,452,066.49 14,900.00 90.35 333.16 7,923.94 7,853.94 0.00 0.00 10,905.13 5,954,951.91 1,452,023.54 15,000.00 90.35 333.16 7,923.33 7,853.33 0.00 0.00 11,005.11 5,955,042.20 1,451,980.58 15,100.00 90.35 333.16 7,922.72 7,852.72 0.00 0.00 11,105.08 5,955,132.50 1,451,937.63 15,200.00 90.35 333.16 7,922.12 7,852.12 0.00 0.00 11,205.05 5,955,222.79 1,451,894.68 15,300.00 90.35 333.16 7,921.51 7,851.51 0.00 0.00 11,305.03 5,955,313.09 1,451,851.72 1123/2 0 18 10:22:16AM Page 10 COMPASS 5000.14 Build 85 I ConocoPhillips ConocoPhillips Directional Summary Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #B GMT1-C2 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pao MD Reference: WELL @ 70,00usft (Original Well Elev) Well: Plan: Well #8_GMT7-C2 North Reference: True Wellbore: Wellbore #8 Survey Calculation Method: Minimum Curvature Design: MT6-08-wp04 Lower Let Database: EDT Alaska Prod Planned Survey MD Inc Azl (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) (usft) (usft) 15,400.00 90.35 333.16 7,920.91 7,850.91 0.00 0.00 11,405.00 5,955,403.39 1,451,808.77 15,500.00 90.35 333.16 7,920.30 7,850.30 0.00 0.00 11,504.97 5,955,493.68 1,451,765.82 15,600.00 90.35 333.16 7,919.70 7,849.70 0.00 0.00 11,604.95 5,955,583.98 1,451,722.86 15,700.00 90.35 333.16 7,919.09 7,849.09 0.00 0.00 11,704.92 5,955,674.27 1,451,679.91 15,800.00 90.35 333.16 7,918.49 7,848.49 0.00 0.00 11,804.89 5,955,764.57 1,451,636.95 15,900.00 90.35 333.16 7,917.88 7,847.88 0.00 0.00 11,904.87 5,955,854.87 1,451,594.00 16,000.00 90.35 333.16 7,917.28 7,847.28 0.00 0.00 12,004.84 5,955,945.16 1-051,551.05 16,100.00 90.35 333.16 7,916.67 7,846.67 0.00 0.00 12,104.81 5,956,035.46 1,451,508.09 16,200.00 90.35 333.16 7,916.07 7,846.07 0.00 0.00 12,204.79 5,956,125.75 1,451,465.14 16,300.00 90.35 333.16 7,915.46 7,845.46 0.00 0.00 12,304.76 5,956,216.05 1,451,422.19 16,400.00 90.35 333.16 7,914.86 7,844.86 0.00 0.00 12,404.73 5,956,306.35 1,451,379.23 16,500.00 90.35 333.16 7,914.25 7,844.25 0.00 0.00 12,504.71 5,956,396.64 1,451,336.28 16,600.00 90.35 333.16 7,913.65 7,843.65 0.00 0.00 12,604.68 5,956,486.94 1,451,293.32 16,700.00 90.35 333.16 7,913.04 7,843.04 0.00 0.00 12,704.65 5,956,577.23 1,451,250.37 16,800.00 90.35 333.16 7,912.43 7,842.43 0.00 0.00 12,804.63 5,956,667.53 1,451,207.42 16,900.00 90.35 333.16 7,911.83 7,841.83 0.00 0.00 12,904.60 5,956,757.83 1,451,164.46 17,000.00 90.35 333.16 7,911.22 7,841.22 0.00 0.00 13,004.57 5,956,848.12 1,451,121.51 17,100.00 90.35 333.16 7,910.62 7,840.62 0.00 0.00 13,104.55 5,956,938.42 1,451,078.56 17,200.00 90.35 333.16 7,910.01 7,840.01 0.00 0.00 13,204.52 5,957,028.71 1,451,035.60 17,300.00 90.35 333.16 7,909.41 7,839.41 0.00 0.00 13,304.49 5,957,119.01 1,450,992.65 17,400.00 90.35 333.16 7,908.80 7,838.80 0.00 0.00 13,404.47 5,957,209.31 1,450,949.69 17,500.00 90.35 333.16 7,908.20 7,838.20 0.00 0.00 13,504.44 5,957,299.60 1,450,906.74 17,600.00 90.35 333.16 7,907.59 7,837.59 0.00 0.00 13,604.41 5,957,389.90 1,450,863.79 17,700.00 90.35 333.16 7,906.99 7,836.99 0.00 0.00 13,704.39 5,957,480.20 1,450,820.83 17,800.00 90.35 333.16 7,906.38 7,836.38 0.00 0.00 13,804.36 5,957,570.49 1,450,777.88 17,900.00 90.35 333.16 7,905.78 7,835.78 0.00 0.00 13,904.33 5,957,660.79 1,450,734.92 18,000.00 90.35 333.16 7,905.17 7,835.17 0.00 0.00 14,004.30 5,957,751.08 1,450,691.97 1/232018 10:22:16AM Page 11 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #8_GMT1-C2 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MD Reference: WELL Q 70.00usft (Original Well Elev) Well: Plan: Well #$_GMT1-C2 North Reference: True Wellbore: Wellbore #8 Survey Calculation Method; Minimum Curvatura Design: MT&08-wp04 Lower Let Database: EDT Alaska Prod Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (°) (°) (usft) (usft) (°I100usft) (°) (usft) (usft) (usft) 18,100.00 90.35 333.16 7,904.57 7,834.57 0.00 0.00 14,104.28 5,957,841.38 1,450,649.02 18,200.00 90.35 333.16 7,903.96 7,833.96 0.00 0.00 14,204.25 5,957,931.68 1,450,606.06 18,300.00 90.35 333.16 7,903.36 7,833.36 0.00 0.00 14,304.22 5,958,021.97 1,450,563.11 18,400.00 90.35 333.16 7,902.75 7,832.75 0.00 0.00 14,404.20 5,958,112.27 1,450,520.16 18,500.00 90.35 333.16 7,902.14 7,832.14 0.00 0.00 14,504.17 5,958,202.56 1,450,477.20 18,600.00 90.35 333.16 7,901.54 7,831.54 0.00 0.00 14,604.14 5,958,292.86 1,450,434.25 18,700.00 90.35 333.16 7,900.93 7,830.93 0.00 0.00 14,704.12 5,958,383.16 1,450,391.29 18,800.00 90.35 333.16 7,900.33 7,830.33 0.00 0.00 14,804.09 5,958,473.45 1,450,348.34 18,900.00 90.35 333.16 7,899.72 7,829.72 0.00 0.00 14,904.06 5,958,563.75 1,450,305.39 19,000.00 90.35 333.16 7,899.12 7,829.12 0.00 0.00 15,004.04 5,958,654.04 1,450,262.43 19,100.00 90.35 333.16 7,896.51 7,828.51 0.00 0.00 15,104.01 5,958,744.34 1,450,219.48 19,200.00 90.35 333.16 7,897.91 7,827.91 0.00 0.00 15,203.98 5,958,834.64 1,450,176.53 19,300.00 90.35 333.16 7,897.30 7,827.30 0.00 0.00 15,303.96 5,958,924.93 1,450,133.57 19,400.00 90.35 333.16 7,896.70 7,826.70 0.00 0.00 15,403.93 5,959,015.23 1,450,090.62 19,500.00 90.35 333.16 7,896.09 7,826.09 0.00 0.00 15,503.90 5,959,105.52 1,450,047.66 19,600.00 90.35 333.16 7,895.49 7,825.49 0.00 0.00 15,603.88 5,959,195.82 1,450,004.71 19,700.00 90.35 333.16 7,894.88 7,824.88 0.00 0.00 15,703.85 5,959,286.12 1,449,961.76 19,800.00 90.35 333.16 7,894.28 7,824.26 0.00 0.00 15,803.82 5,959,376.41 1,449,918.80 19,900.00 90.35 333.16 7,893.67 7,823.67 0.00 0.00 15,903.80 5,959,466.71 1,449,875.85 20,000.00 90.35 333.16 7,893.07 7,823.07 0.00 0.00 16,003.77 5,959,557.00 1,449,832.90 20,100.00 90.35 333.16 7,892.46 7,822.46 0.00 0.00 16,103.74 5,959,647.30 1,449,789.94 20,200.00 90.35 333.16 7,891.85 7,821.85 0.00 0.00 16,203.72 5,959,737.60 1,449,746.99 20,300.00 90.35 333.16 7,891.25 7,821.25 0.00 0.00 16,303.69 5,959,827.89 1,449,704.03 20,400.00 90.35 333.16 7,890.64 7,820.64 0.00 0.00 16,403.66 5,959,918.19 1,449,661.08 20,500.00 90.35 333.16 7,890.04 7,820.04 0.00 0.00 16,503.64 5,960,008.46 1,449,618.13 20,506.44 9035 333.16 7,890.00 7,820.00 0.00 0.00 16,510.08 5,960,014.30 1,449,615.36 TD at 20506.44 - 4-1/2" x 6" 1232018 10.22:16AM Page 12 COMPASS 5000.14 Build 85 ConocoPhillips Company: Project: Site: Well: Wellbore: Design: Casing Points Formations ConomPhillips(Alaska) Inc. -WNS Western North Slope Plan: GMT1 Lookout Pad Plan: Well #8 GMT1-C2 Wellbore #8 MT6-08-wp04 Lower Let Measured Vertical Depth Depth (usft) (usft) Name 2,056.00 2,034.63 13-3/8" x 16" 10,235.31 7,130.05 9-5/8" x 12-1/4" 12,080.00 7,911.49 7" x 8-3/4" 20,506.44 7,890.00 4-1/2" x 6" Measured Vertical Depth Depth (usft) (usft) Name 3,763.09 3,39741 K-3 4,688.55 3,932.18 Albian 97 5,724.80 4,529.61 Albian 95 13,540.44 7,932.16 UJU 10,732.44 7,416.66 LCU 5,133.28 4,188.58 Albian 96 9,542.41 6,730.57 Top Fill 10,235.31 7,130.05 HRZ Slump 11,873.19 7,884.36 Alpine C 8,760.78 6,279.94 Ablian 93 13,055.89 7,935.10 UJU 7,812.75 5,733.37 Albian 94 2,123.97 2,098.54 C-30 2,514.58 2,454.92 C-10 ConocoPhillips Directional Summary Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Casing Hole Diameter Diameter Name (") (") 13-3/8 16 9-5/8 12-1/4 7 8-3/4 4-1/2 6 Dip Dip Direction Lithology (°) P) Well Plan. Well #8_GMT1-C2 WELL @ 70.00usft (Original Well Elev) WELL @ 70.00usft (Original Well Elev) True Minimum Curvature EDT Alaska Prod 1/23/2018 10:22:16AM Page 13 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: Conocoi hillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #8_GMT1-C2 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MO Reference: WELL @ 70.00usft (Original Well Elev) Well: Plan: Well #8_GMT1-C2 North Reference: True Wellbore: Wellbore #8 Survey Calculation Method: Minimum Curvature Design: MT6-08-wp04 Lower Let Database: EDTAlaska Prod Plan Annotations Measured Vertical Local Coordinates Depth Depth +N1 -S +E1 -VV (usft) (usft) (usft) (usft) Comment 1,036.00 1,036.00 0.00 0.00 Start Build 2.00 2,029.81 2,010.00 147.79 -85.33 Start 80.00 hold at 2029.81 MD 2,109.81 2,085.23 171.35 -98.93 Start US 2.00 TFO 0.58 3,855.70 3,452.02 1,076.81 615.62 Start 7113.89 hold at 3855.70 MD 10,969.59 7,553.38 6,131.32 -3,485.86 Start US 3.00 TFO 5.07 11,896.01 7,887.47 6,863.67 -3,890.71 Start 50.00 hold at 11896.01 MD 11,946.01 7,894.00 6,927.76 -3,913.38 Start 212.80 hold at 11946.01 MD 12,158.81 7,921.78 7,115.39 -4,009.85 Start US 2.72 TFO -5.96 12,325.23 7,937.00 7,262.42 -4,086.21 Start US 4.00 TFO 14.17 12,411.53 7,939.00 7,339.10 4,125.72 Start 8094.92 hold at 12411.53 MD 20,506.44 7,890.00 14,562.11 -7,779.94 TD at 20506.44 123/2018 10:22:16AM Page 14 COMPASS 5000.14 Build 85 ConocoPhillips Project: Western North Slope Site: Plan: GMT1 Lookout Pad Well: Plan: Well #8_GMT1-C2 Wellbore: Wellbore #8 Design: MT6-08-wp04 Lower Lat 1000 13-3/8" x 16" �O O ^O� 9-5/8" x 12-1/4" �O 0� 7" x 8-3/4" Tm� o0 0 wo ti HRZ Alpine C 4-1/2" x 6" 12500 G1 C�M(0 p8p0A C � 10000- 7500— t: 0000 7500: 7" x 8-3/4" Z ��p0 5000 t 9-5/8" x 12-1/4" gp0, 0 <n y0p0 2500 0.pp0 13-3/8" x 16"_ _ 300 -12500 -10000 -7500 -5000 -2500 0 2500 5000 West( -)/East(+) (5000 usft/in) v d i m m 6000 7500 9000 10500 12000 13500 15000 16500 Vertical Section at 331.89° (3000 usft/in) ConocoPhillips(Alaska) Inc. -WNS Western North Slope Plan: GMT1 Lookout Pad Plan: MT6-08 MT6-08 MT6-08-wp04 Lower Lat ConocoPhillips Clearance Summary Anticollision Report 13 April, 2018 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Plan: GMT1 Lookout Pad - Plan: MT6-08 - MT6-08 - MT6-O8-wp04 Lower Let Well Coordinates: 5,945,268.15 N, 1,457,038.09 E (70° 15'21.50" N, 151° 28' 55.82" W) Datum Height: WELL @ 70.00usft (Original Well Elev) Scan Range: 0.00 to 20,506.37 usft. Measured Depth. Scan Radius is 2,247.04 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85 Scan Type: GLOBAL FILTER APPLIEDAll wellpaths within 200'+100/1000 of reference Scan Type: 25.00 ConocoPhillips `� ConocoPhillips 780.42 ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: MT6-08 - MT6-08-wp04 Lower Lat 82.80 800.00 Trev. Cylinder North Proximity Scan on Current Survey Data (North Reference) Centre Distance Pass - Major Risk Reference Design: Plan: GMT1 Lookout Pad - Plan: MT6-08 - MT6-08 - MT6-08-wp04 Lower Let 1,030.33 95.75 Scan Range: 0.00 to 20,506.37 usft. Measured Depth. 80.02 1,050.00 Scan Radius is 2,247.04 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Clearance Factor Pass - Major Risk 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 Plan: GMT1 Lookout Pad MT6-03-MT6-03-MT6-03 780.42 94.84 780.42 82.80 800.00 7.877 Centre Distance Pass - Major Risk MT6-03 - MT6-03 - MT6-03 1,030.33 95.75 1,030.33 80.02 1,050.00 6.087 Clearance Factor Pass - Major Risk MT6-03-MT6-03-MT6-03 wp05 1,031.30 100.00 1,031.30 73.26 1,050.00 3.740 Centre Distance Pass - Major Risk MT6-03 - MT6-03 - MT6-03 Wp05 1,105.93 100.50 1,105.93 72.79 1,125.00 3.627 Clearance Factor Pass - Major Risk MT6-03 - MT6-03PB1 - MTe-03PB1 780.42 94.84 780.42 82.80 800.00 7.877 Centre Distance Pass - Major Risk MT6-03-MT6-03PB1-MT6-03PB1 1,030.33 95.75 1,030.33 80.02 1,050.00 6.087 Clearance Factor Pass - Major Risk MT6-03-MT6-03PB1-MT6-03PB1 wp05 1,031.30 100.00 1,031.30 73.26 1,050.00 3.740 Centre Distance Pass - Major Risk MT6-03 - MT6-03PB1 - MT6-03PB1 wp05 1,105.93 100.50 1,105.93 72.79 1,125.00 3.627 Clearance Factor Pass - Major Risk Plan: MT6-01 - MTB -01 - F-wp02 1,025.00 139.97 1,025.00 123.15 1,025.00 8.319 Centre Distance Pass- Major Risk Plan: MT6-01 - MT6-01 - F-wp02 1,074.72 140.22 1,074.72 122.74 1,075.00 8.023 Clearance Factor Pass- Major Risk Plan: MT6-02 - MT6-02 - E-wp02 1,025.00 120.05 1,025.00 103.23 1,025.00 7.135 Centre Distance Pass - Major Risk Plan: MT6-02 - MT6-02 - E-wp02 1,223.56 121.13 1,223.56 101.62 1,225.00 6.208 Clearance Factor Pass - Major Risk Plan: MT6-04 - MT6-04 - Cl-wp02 1,370.65 72.36 1,370.65 50.95 1,375.00 3.380 Clearance Factor Pass - Major Risk Plan: MT6-05 - MT6-05 - MT6-05-wp04_Lower Let 1,918.68 20.17 1,918.68 14.78 1,925.00 3.737 Clearance Factor Pass- Minor 1/10 Plan: MT6-05-MT6-05_Upper Let -MT6-05-wp04 1,918.68 20.17 1,918.68 13.06 1,925.00 2.835 Clearance Factor Pass -Minor 1110 Plan: MT6-O6-MT6-06-81-WP02_Drill South 774.93 39.72 774.93 26.92 775.00 3.105 Centre Distance Pass - Major Risk Plan: MT6-06 - MT6-06- B1-Wp02_Drill South 949.64 41.03 949.64 25.42 950.00 2.629 Clearance Factor Pass- Major Risk Plan: MT6-07-MT6-07-A1-wp02 1,224.26 17.84 1,224.26 13.38 1,225.00 3.998 Clearance Factor Pass - Minor 1/10 Plan: MT6-08 - MT6-08PB7 - MT6-08PB1-wp04 10,722.09 36.36 10,722.09 25.12 10,725.00 3.237 Clearance Factor Pass- Major Risk Plan: MT6-08-MT8-08_Upper Let -MT6-08-wp04 20,506.55 30.00 20,506.55 29.56 20,504.06 68.414 Clearance Factor Pass - Minor 1/10 Plan: MT6-09 - MT6-09 - A2-wp02 1,025.00 19.95 1,025.00 15.67 1,025.00 4.664 Centre Distance Pass - Minor 1/10 Plan: MT6-09 - MT6-09 - A2-wp02 1,050.01 19.97 1,050.01 15.67 1,050.00 4.638 Clearance Factor Pass - Minor 1/10 13 April, 2018 - 14:38 Page 2 of 5 COMPASS ConocoPhillips Anticollision Report for Plan: MT6-08 - MT6-08-wp04 Lower Lat Survey tool oroaram From To Survey/Plan Survey Tool (usft) (usft) 36.00 300.00 MT6-08-wp04 Lower Let GYD-GC-MS 300.00 2,056.00 MT6-08-wp04 Lower Let MWD 300.00 2,056.00 MT6-08-wp04 Lower Let MWD+IFR-AK-CAZ-SC 2,056.00 10,236.00 MT6-08-wp04 Lower Let MWD 2,056.00 10,236.00 MT6-O8-wp04 Lower Let MWD+IFR-AK-CAZ-SC 10,236.00 12,080.00 MT6-08-wp04 Lower Let MWD 10,236.00 12,080.00 MT6-08-wp(34 Lower Let MWD+IFR-AK-CAZ-SC 12,080.00 20,506.37 MT6-OB-wpO4 Lower Let MWD 12,080.00 20,506.37 MT6-08-wp04 Lower Let MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface emors. 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. ConocoPhillips(Alaska) Inc. -WNS Western North Slope 13 April, 2018 - 14:36 Page 3 of 5 COMPASS ConocoPhil lips Anticollision Report for Plan: MT6-08 - MT6-08-wp04 Lower Lat Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to WELL @ 70.00usft (Original Well Elev). Northing and Easting are relative to Plan: MT6-08. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergenceat Surfaceis: -1.40*. Ladder Plot F. N 1950- 0 r9 c O `6 1300- 650 0 300- 6500 ------ -- I I - - - I I I I 1�y I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I f I I I I I I I I I I I __________I___ 11 I I I I 1 I I I I 1 I I I I 1 I I i I I I I I I I I I I I I I 0 0 r i t I I 3500 7000 10500 14000 17500 Measured Depth (3500 usft/in) ConocoPhillips(Alaska) Inc. -WNS Western North Slope LEGEND —0— MTS -03, MT6-03,MT6-03 VO —W MT6-03, MT6-03, MT6-03vop05 V0 ♦— MT5-03,MT6-03PB1,MT6-03PB1 VO —dr MT13-03, Itil B1,MT6-03PB1 vp05V0 ♦— Plan: MT6-01, MTS-01,F-wp02V0 $ Plan: MT6-02, MT6-02,E-vpO2VO $ Plan: MT6-04, MT604,C1-vlp02 V0 -+- Plan:MT6-05, MT6-05, MT6-05-wp04_LovterLffiVO $ Plan:MT6-05, MT6-05_UpperLet, MTS-05-wp04VO $ Plan: Ml Mr6-06, 131-wp02_Drill South VO —ifir- Plan: MTS07, MT6-07,A1-vvp02VO —A— Plan: Mt606, MT6-08PB1, MT6-08PB1-Ai VO —X— Plan: MT608, MT8-08_UpperLat, Mf6-08-tW04 V0 $ Plan: MTS -09, MT6-09,A2-wpO2V0 $ MT6-08Awp04LamrLat 13 April, 2018 - 14:36 Page 4 ors COMPASS ConocoPhillips Anticollision Report for Plan: MT6-08 - MT6-08-wp04 Lower Lat Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor ConocoPhillips(Alaska) Inc. -WNS Western North Slope LEGEND -0-- MT6-03, MT6-03, KM -03 VO $ MT6-03, MT6-03, MT6-03MP05VO -t- MT6-03,MT6.03PB1,MT6-03PB1 VO -�- MT6-03, MT6-03PB1, MT6-03PB1 wp05 VO -!f Plan: MT6-01,MT6-01,F-w4)02 VO $ Plan: MT6-02, M76-02,E-wpO2VO $ Plan: M76-04, MT6-04,C1-wp02 VO -)t- Plan:MT6-05, MT6-05, MT6-05-wp04_LowerLatVO T6 $ Plan: MM -05, MT6-05_UpperLat MT6-05-wpO4VO $ Plan:MT6-O6, MT6-06,B1-wp02_Dnll South VO -�- Plan: M76-07, MT6-07,A1-wpO2 Vo $ Plan:MT6-08, MT6-08PB1,MT6-08PB1-wp04V0 $ Plan:MT6-08, MT8-08_Upper Lat MT6-08-wp04 VO $ Plan: M76-09, KM-09,A2-WO2V0 $ MT6-08-wp04 Lower Lat 13 April, 2018 - 14:36 Page 5 o15 COMPASS 10.00- 0.00 8.75 8.75 .. --. -_ -_ 7.50 i .. o ' N �N.. 6.25 - - --- -__ - 0 U _ c 5.00- .0c 7g g m (D 3.75 2.50- .501.25 I 1.25- 0.00- 0.000 0 1750 3500 5250 7000 8750 10500 12250 14000 15750 17500 19250 21000 Measued Depth (3500 usftln) ConocoPhillips(Alaska) Inc. -WNS Western North Slope LEGEND -0-- MT6-03, MT6-03, KM -03 VO $ MT6-03, MT6-03, MT6-03MP05VO -t- MT6-03,MT6.03PB1,MT6-03PB1 VO -�- MT6-03, MT6-03PB1, MT6-03PB1 wp05 VO -!f Plan: MT6-01,MT6-01,F-w4)02 VO $ Plan: MT6-02, M76-02,E-wpO2VO $ Plan: M76-04, MT6-04,C1-wp02 VO -)t- Plan:MT6-05, MT6-05, MT6-05-wp04_LowerLatVO T6 $ Plan: MM -05, MT6-05_UpperLat MT6-05-wpO4VO $ Plan:MT6-O6, MT6-06,B1-wp02_Dnll South VO -�- Plan: M76-07, MT6-07,A1-wpO2 Vo $ Plan:MT6-08, MT6-08PB1,MT6-08PB1-wp04V0 $ Plan:MT6-08, MT8-08_Upper Lat MT6-08-wp04 VO $ Plan: M76-09, KM-09,A2-WO2V0 $ MT6-08-wp04 Lower Lat 13 April, 2018 - 14:36 Page 5 o15 COMPASS ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope Plan: GMT1 Lookout Pad Plan: Well #8_GMT1-C2 Wellbore #8 PBI Plan: MT6-08PB1-wp04 Directional Summary Report 23 January, 2018 '1`1 ConocoPhillips ConocoPhillips Directional Summary Report Northing: Company: ConocoPhillips(Alaska) Inc. -WNS Local Corordinate Reference: Well Plan: Well #8—GMT1-C2 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MD Reference: WELL @ 70.00usft (Original Well Elev) Well: Plan: Well #8—GMT1-C2 North Reference: True Wellbore: Wellbore #8_PB1 Survey Calculation Method: Minimum Curvature Design: MT6-08PB1-wp04 Database: EDT Alaska Prod Project Western North Slope, North Slope Alaska, United States 36.00 Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor SHO Plan: GMT1 Lookout Pad Plan: Well#8 GMTi-C2 Site Position: Northing: 5,945,316.00 usft Latitude: 70° 15'22,006 N From: Map Easting: 1,457,169.00 usft Longitude: 151° 28'52.049 W Position Uncertainty: 0,00 usft Slot Radius: 0 " Grid Convergence: -1.39 ` Longitude: 151' 28'55.825 Position Uncertainty 0.00 usft Well Plan: Well#8 GMTi-C2 Audit Notes: Well Position +N/ -S 0.00 usft Northing: 5,945,268.00 usft Latitude: 70° 15'21.503 PLAN +EI -W 0.00 usft Easting: 1,457,038.00 usft Longitude: 151' 28'55.825 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 3 Wellbore Wellbore#8 PBI Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1°) (°) (nT) BGGM2017 8/62018 16.38 80.71 57,415 Design MT6-08PB1-wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 10,400.00 Vertical Section: Depth From (TVD) +N/ -S +E7 -W Direction (usft) (usft) (usft) (°) 36.00 0.00 0.00 324.67 1232018 10:30:35AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Company: ConocoPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: Plan: GMT1 Lookout Pad Well: Plan: Well #B GMT1-C2 Wellbore: Wellbore#B PB1 Design: MT6-08PBl-wp04 Survey Tool Program Date 1/23/2018 From To (usft) (usft) Survey (Wellbore) 36.00 300.00 MT6-08-wp04 Lower Let ( Wellbore #8) 300.00 2,056.00 MT6-08-wp04 Lower Let (Wellbore #6) 2,056.00 10,236.00 MT6-08-wp04 Lower Let (Weloore#B) 10,236.00 10,400.00 MT6-08-wp04 Lower Lat (Wellbore #8) 10,400.00 12,065.00 MT6-08PB1-wp04(Wellbore #8 Pal) 10,400.00 12,065.00 MT6-08PB1-wPO4(Wellbore #8_PB1) Planned Survey Blind drilling MD Inc MWD+IFR AK CAZ SCC (usft) (1) MWD+IFRAKCAZSCC 10,400.00 54.79 KOP MWD - Standard 10,420.00 54.79 Start DLS 4.60 TFO 286.00 10,500.00 55.86 10,600.00 57.38 10,700.00 59.10 10,720.00 59.47 Start DLS 4.50 TFO -92.31 5,951,071.84 10,754.19 59.42 Lou 7,166.53 10,800.00 59.39 10,900.00 59.48 11,000.00 59.78 11,100.00 60.28 11,200.00 60.98 11,300.00 61.87 11,331.75 62.19 Start 426.39 hold at 11331.75 MD ConocoPhillips Directional Summary Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Tool Name Description BLIND Blind drilling MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Well Plan: Well #8_GMT1-C2 WELL @ 70.00usft (Original Well Elev) WELL Q 70.00usft (Original Well Elev) True Minimum Curvature EDT Alaska Prod Azi (azimuth) TVD TVDSS DLeg TFace V. Sac Northing Basting VI, (usft) (usft) (°1100usft) (') (usft) (usft) (usR) 330.41 7,225.00 7, 155.00 0.00 0.00 6,554.89 5,951,071.84 1,453,922.54 330.41 7,236.53 7,166.53 0.00 0.00 6,571.15 5,951,086.24 1,453,914.62 326.23 7,282.05 7,212.05 4.50 -74.00 6,636.78 5,951,143.02 1,453,881.64 321.16 7,337.10 7,267.10 4.50 -71.62 6,720.23 5,951,211.43 1,453,833.85 316.26 7,389.75 7,319.75 4.50 -68.83 6,804.75 5,951,276.61 1,453,779.32 315.31 7,399.97 7,329.97 4.50 -66.25 6,821.73 5,951,289.22 1,453,767.63 313.52 7,417.35 7,347.35 4.50 -92.31 6,850.70 5,951,310.33 1,453,747.11 311.13 7,440.67 7,370.67 4.50 -91.41 6,889.22 5,951,337.57 1,453,718.62 305.90 7,491.55 7,421.55 4.50 -90.19 6,971.88 5,951,392.78 1,453,652.61 300.70 7,542.14 7,472.14 4.50 -87.53 7,052.18 5,951,441.86 1,453,581.71 295.53 7,592.12 7,522.12 4.50 -84.90 7,129.63 5,951,484.50 1,453,506.36 290.43 7,641.19 7,571.19 4.50 -82.32 7,203.74 5,951,520.44 1,453,427.03 285.41 7,689.05 7,619.05 4.50 -79.81 7,274.06 5,951,549.45 1,453,344.19 283.83 7,703.94 7,633.94 4.50 -77.41 7,295.52 5,951,557.19 1,453,317.25 1232018 10:30.35AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #8_GMTt-C2 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MD Reference: WELL @ 70.00usft (Original Well Elev) Well: Plan: Well #8_GMT1-C2 North Reference: True Wellbore: Wellbore #8_P81 Survey Calculation Method: Minimum Curvature Design: MT6-08PB1-wp04 Database: EDT Alaska Prod Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easgng (usft) (I (°) (usft) (usft) (°/100usft) (°) (usft) (usft) (usft) 11,400.00 62.19 283.83 7.735.79 7,665.79 0.00 0.00 7,341.20 5,951,573.04 1,453,259.00 11,500.00 62.19 283.83 7,782.45 7,712.45 0.00 0.00 7,408.11 5,951,596.27 1,453,173.67 11,600.00 62.19 283.83 7,829.11 7,759.11 0.00 0.00 7,475.03 5,951,619.50 1,453,088.33 11,700.00 62.19 283.83 7,875.76 7,805.76 0.00 0.00 7,541.95 5,951,642.73 1,453,002.99 11,758.14 62.19 283.83 7,902.89 7,832.89 0.00 0.00 7,580.85 5,951,656.24 1,452,953.38 Start 196.27 hold at 11758.14 MD 11,758.18 62.19 283.83 7,902.91 7,832.91 0.00 0.00 7,580.88 5,951,656.25 1,452,953.34 Alpine C 11,800.00 62.19 283.83 7,922.42 7,852.42 0.00 0.00 7,608.87 5,951,665.97 1,452,917.66 11,900.00 62.19 283.83 7,969.08 7,899.08 0.00 0.00 7,675.79 5,951,689.20 1,452,832.32 11,953.41 62.19 283.83 7,994.00 7,924.00 0.00 0.00 7,711.52 5,951,701.60 1,452,786.74 Start 111.69 hold at 11963.41 MD 11,959.73 62.19 283.63 7,996.95 7,926.95 0.00 0.00 7,715.76 5,951,703.07 1,452,781.35 uJu 12,000.00 62.19 283.83 8,015.74 7,945.74 0.00 0.00 7,742.70 5,951,712.43 1,452,746.98 12,065.00 62.19 283.83 8,046.07 7,976.07 0.00 0.00 7,786.20 5,951,727.52 1,452,691.52 TD at 12066.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 111) l"1 12,065.00 8,046.07 81/2" 8-1/2 8-1/2 1/23/2018 10:30:35AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #8 GMT1-C2 Project: Western North Slope TVD Reference: WELL Q 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MD Reference: WELL @ 70.00usft (Original Well Elev) Well: Plan: Well #8_GMT1-C2 North Reference: True Wellbore: Wellbore #8 P81 Survey Calculation Method: Minimum Curvature Design: MT6-08PB1-wp04 Database: EDT Alaska Prod Formations Vertical Local Coordinates Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology U) ( ) 10,235.31 7,130.05 HRZ Slump 7,812.75 5,733.37 Albion 94 8,760.78 6,279.94 Ablian 93 2,123.97 2,098.54 C-30 0.00 9,542.41 6,730.57 Top Fill 3,763.09 3,397.41 K-3 11,758.18 7,902.91 Alpine C 5,724.80 4,529.61 Albian 95 2,514.58 2,454.92 C-10 0.00 5,133.28 4,188.58 Albian 96 10,754.19 7,417.35 LCU 11,959.73 7,996.95 UJU 4,688.55 3,932.18 Albian 97 Plan Annotations Measured Vertical Local Coordinates Depth Depth -NIS +EAW (usft) (usft) (usft) (usft) Comment 10,400.00 7,225.00 5,726.62 -3,256.05 KOP 10,420.00 7,236.53 5,740.83 -3,264.12 Start DLS 4.50 TFO 286.00 10,720.00 7,399.97 5,940.18 -3,416.21 Start DLS 4.50 TFO -92.31 11,331.75 7,703.94 6,197.12 -3,873.01 Start 426.39 hold at 11331.75 MD 11,758.14 7,902.89 6,287.29 -4,239.20 Start 195.27 hold at 11758.14 MD 11,953.41 7,994.00 6,328.58 -4,406.91 Start 111.59 hold at 11953.41 MD 12,065.00 8,046.07 6,352.18 -4,502.74 TD at 12065.00 1123/2018 10:30.35AM Page 5 COMPASS 5000.14 Build 85 0 Project: Western North Slope Site: Plan: GMT1 Lookout Pad Well: Plan: Well #8 GMT1-C2 Wellbore: Wellbore #8 PB1 Design: MT6-08PB1-wp04 Alpine C -4500 1000 13-3/8" x 16" V 6250 38 to 1250 -5000 -3750 -2500 -1250 West( -)/East(+) (2500 usft/in) �pp0 00 b0 00 y0 00 O� O Q 0 00 40 9-5/8" x 12-1/4" QZ e moo$ �ti W A Q� 1500 3000 4500 6000 7500 9000 Vertical Section at 324.67' (3000 usfUin) 13-3/8" x 16" ConocoPhillips(Alaska) Inc. -WNS Western North Slope Plan: GMT1 Lookout Pad Plan: MT6-08 MT6-08PB1 MT6-08PB1-wp04 ConocoPhillips Clearance Summary Anticollision Report 13 April, 2018 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Plan: GMT1 Lookout Pad - Plan: MT6-08 - MT6-08PB1 - MT6-081`131-vry04 Well Coordinates: 5,945,268.15 N, 1,457,038.09 E (70° 15' 21.50" N, 151° 28'55.82" W) Datum Height: WELL @ 70.00usft (Original Well Elev) Scan Range: 0.00 to 12,064.96 raft. Measured Depth. Scan Radius is 1,402.90 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85 Scan Type: GLOBAL FILTER APPLIED: All wellpalhs within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips ConocoPhillips Anticollision Report for Plan: MT6-08 - MT6-08PB1-wp04 ConocoPhillips(Alaska) Inc. -WNS Western North Slope Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Plan: GMTt Lookout Pad - Plan: MT6-08 - MT6-08PB1 - MT6-08PB1-wp04 Scan Range: 0.00 to 12,064.96 usft. Measured Depth. Scan Radius is 1,402.90 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 Plan: GMT1 Lookout Pad MT6-03 - MT6-03 - MT6-03 780.42 94.84 780.42 82.80 800.00 7.877 Centre Distance Pass - Major Risk MT6-03 - MT6-03 - MT6-03 1,030.33 95.75 1,030.33 80.02 1,050.00 6.087 Clearance Factor Pass - Major Risk MT6-03 - MT6-03 - MT6-03 wp05 1,031.30 100.00 1,031.30 73.26 1,050.00 3.740 Centre Distance Pass - Major Risk MT6-03 - MT6-03 - MT6-03 wp05 1,105.93 100.50 1,105.93 72.79 1,125.00 3.627 Clearance Factor Pass - Major Risk MT6-03 - MT6-03PB1 - MT6-03PB1 780.42 94.84 780.42 82.80 800.00 7.877 Centre Distance Pass - Major Risk MT6-03-MT6-03PB1-MT6-03PB1 1,030.33 95.75 1,030.33 80.02 1,050.00 6.087 Clearance Factor Pass - Major Risk MT6-03 - MT6-03PB1 - MT6-03PB1 wp05 1,031.30 100.00 1,031.30 73.26 1,050.00 3.740 Centre Distance Pass - Major Risk MTS-03-MT6-03PB1-MT6-03PB7 wp05 1,105.93 100.50 1,105.93 72.79 1,125.00 3.627 Clearance Factor Pass - Major Risk Plan: MT6-01-MT6-01-F-wp02 1,025.00 139.97 1,025.00 123.15 1,025.00 8.319 Centre Distance Pass - Major Risk Plan: MT6-01 - MT6-01 - F-wp02 1,074.72 140.22 1,074.72 122.74 1,075.00 8.023 Clearance Factor Pass - Major Risk Plan: MT6-02 - MT6-02 - E-wp02 1,025.00 120.05 1,025.00 103.23 1,025.00 7.135 Centre Distance Pass - Major Risk Plan: MT6-02-MT6-02-E-wp02 1,223.56 121.13 1,223.56 101.63 1,225.00 6.211 Clearance Factor Pass - Major Risk Plan: MT6-04-MT6-04-C1-wp02 1,370.65 72.36 1,370.65 51.01 1,375.00 3.389 Clearance Factor Pass - Major Risk Plan: MT6-05-MT6-05-MT6-05-wp04_Lower Let 1,918.68 20.17 1,918.68 14.84 1,925.00 3.780 Clearance Factor Pass - Minor 1/10 Plan: MT6-05-MT6-05_Upper Let - MT6-05-wp04 1,918.68 20.17 1,918.68 13.06 1,925.00 2.836 Clearance Factor Pass - Minor 1/10 Plan: MT6-06 - MT6-06 - B1-wp02_Drill South 774.93 39.72 774.93 26.92 775.00 3.105 Centre Distance Pass- Major Risk Plan: MT6-06 - MT6-06 - B7-wp02_Drill South 949.64 41.03 949.64 25.42 950.00 2.629 Clearance Factor Pass- Major Risk Plan: MT6-07-MT6-07-A7-wp02 1,224.26 17.84 1,224.26 13.38 1,225.00 4.000 Clearance Factor Pass - Minor l/10 Plan: MT6-08 - MT6-08 - MT6-08-wp04 Lower Let 10,719.36 36.02 10,719.36 26.41 10,725.00 3.746 Clearance Factor Pass- Major Risk Plan: MT6-08 - MT8-08_Upper Let- MT6-08-wp04 10,719.36 36.02 10,719.36 26.52 10,725.00 3.791 Clearance Factor Pass- Major Risk Plan: MT6-09 - MT6-09 - A2-wp02 1,025.00 19.95 1,025.00 15.67 1,025.00 4.664 Centre Distance Pass - Minor 1/10 Plan: MT6-09 - MT6-09 - A2-wp02 1,050.01 19.97 1,050.01 15.67 1,050.00 4.638 Clearance Factor Pass - Minor 1/10 13 April, 2018 - 14:50 Page 2 of 5 COMPASS ConocoPhillips Anticollision Report for Plan: MT6-08 - MT6-O8PB1-wpO4 Survey toot program From To (us@) (usn) 36.00 300.00 300.00 2,056.00 2,056.00 10,236.00 10,236.00 10,400.00 10,400.00 12,064.96 MT6-08PB1-wp04 10,400.00 12,064.96 MT6-08PB1-wp04 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. Survey/Plan Survey Tool BLIND MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC ConocoPhillips(Alaska) Inc. -WNS Western North Slope 13 April, 2018 - 14:50 Page 3 of 5 COMPASS ConocoPhillips Anticollision Report for Plan: MT6-08 - MT6-08PB1-wp04 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to WELL @ 70.00usfl (Original Well Elev). Northing and Easting are relative to Plan: MT&08. Coordinate System is US State Plane 1883, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergence at Surface is: -1.40 °. r. N 1200- N c N U 400- 0 w Ladder Plot ---- ---- I I ------ - I ---- --- I -- - - - - -- ------------------- I I I I I I I I ___ ` J__� _�}_I- II I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I i JI I I I I I I 1 I I 2500 5000 7500 10000 12500 Measured Depth (2500 usf /in) ConocoPhillips(Alaska) Inc. -WNS Western North Slope LEGEND -!- MT6-03, MT6-03, MT6-03VO $ MT8-03, MT6-03, MT6-03wpO5VO -� MT6-03, MTI6-03PB1, MT6-03PB1 VO $ Mi6-03,MT6-03PB1,Mr&-03PB1 wp05V0 $ Plan: M76-01,MT6-01,F-wp02VO -I- Plan: MT6-02, MT6-02,E-wp02V0 -E- Plan: MTT6-04, MT604, C1-vvp02VO $ Plan: MTS -05, MT6-05, MT6-05wp04_Lower LatVO -iE Plan:MT6-05, MT6-05_UpperLat, MT6-05-wp04VO -� Plan:MTT6-06, IMTS-06, B1-vvp02_1DnllSouth VO $ Plan: MTS -07, MT6-07,A1-wp02V0 $ Plan: MTS -08, MT6-08, MT6-08-wpO4 Laver LatVO $ Plan: MT6-08,MTS-OS_UpperLet MTf6-08AW04VO -8- Plan: MT"9, MTf6-09,A2-wp02 VO $ Mi6-08PBINpO4 13 April, 2018 - 14:50 Page 4 of 5 COMPASS ConocoPhillips Anticollision Report for Plan: MT6-08 - MT6-08PB1-wp04 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor 10, 8. 7 6 (% 3 2. m 0. ConocoPhillips(Alaska) Inc. -WNS Western North Slope LEGEND ♦- MT6-03, MT6-03, MT6-03 V0 $ MT6-03, MT6-03, MT&03 wp05V0 $ MT6-03, MT6.03P61, MT6-03PB1 V0 $ MTB -03, MT6-03PB1, MT6-03PB1 wp05V0 $ Plan: MT6-01, MM-01,F-wp02 V0 Plan: MT6-02, MT6-02,E-wp02 V0 -Q- Plan: MT6-04, MT6-04,C1-wp02 V0 $ Plan: MTS -05, MT6-05, MT6-05-wp04_1-ower LatVO PIan:MT6-05, MT6-05_UpperLat MT6-05-wp04 V0 -� PIan:MT6-06, MT6-06, B1-wp02_DnllSouth V0 $ Plan: MT6-07, MT6-07,A1-w4)02V0 $ Plan: MT6-08,MT6-08, MT6-08-wp04 LOV.er LatVO $ Plan: MT6-08,MT8-08_Upper Let, MT6-08-wp04VO -A- Plan: MT6-09, MT6-09,A2-wp02 V0 $ MT6-08PB1-wp04 13 Apn1, 2018 - 14:50 Page 5 of 5 COMPASS )o — i 5 '5— )0 )0- 50 50— )o )a 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 Measured Depth (ZOOD 1sRln) ConocoPhillips(Alaska) Inc. -WNS Western North Slope LEGEND ♦- MT6-03, MT6-03, MT6-03 V0 $ MT6-03, MT6-03, MT&03 wp05V0 $ MT6-03, MT6.03P61, MT6-03PB1 V0 $ MTB -03, MT6-03PB1, MT6-03PB1 wp05V0 $ Plan: MT6-01, MM-01,F-wp02 V0 Plan: MT6-02, MT6-02,E-wp02 V0 -Q- Plan: MT6-04, MT6-04,C1-wp02 V0 $ Plan: MTS -05, MT6-05, MT6-05-wp04_1-ower LatVO PIan:MT6-05, MT6-05_UpperLat MT6-05-wp04 V0 -� PIan:MT6-06, MT6-06, B1-wp02_DnllSouth V0 $ Plan: MT6-07, MT6-07,A1-w4)02V0 $ Plan: MT6-08,MT6-08, MT6-08-wp04 LOV.er LatVO $ Plan: MT6-08,MT8-08_Upper Let, MT6-08-wp04VO -A- Plan: MT6-09, MT6-09,A2-wp02 V0 $ MT6-08PB1-wp04 13 Apn1, 2018 - 14:50 Page 5 of 5 COMPASS Davies, Stephen F (DOA) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Wednesday, May 30, 2018 1:19 PM To: Davies, Stephen F (DOA) Subject: RE: [EXTERNAL]RE: Request for Waiver of Diverter Requirement on MT6-08 (PTD #218-048) H i Steve, You are correct, on MT6-03 we started with 9.5 ppg Mud and ended the surface section with 9.8 ppg mud. On MT6-05, we lowered the starting mud weight down to 9.3 ppg (9.3 ppg by design, on rig MW was closer to 9.4 when we started drilling) and ended the surface section with a 9.8+ mud weight. Our design for MT6 wells is to start with a MW of 9.0 ppg or slightly higher and let the mud weight drift up naturally as we drill ahead to a max of 10.0 ppg. MT6-03 and MT6-05 started with higher than designed mud weights as a precaution for possible shallow water flow as was seen on CDS. The shallow water flow on CDS was anomalous and we did not expect to see it at MT6, but to be conservative we started with higher mud weights and are bringing it down on a well by well basis. On MT6-03 we did see a slight increase in chlorides during a mud check. In order to rule out the possibility of shallow water flow, near TO we lowered the MW to 9.4 ppg and did not see an increase in chlorides, gas, or flow on connections. Due to no gas and no indication of shallow water flow, we will start MT6-08 with 9.0 ppg mud and will let it naturally drift up to —9.6 ppg by TD. We will be using gas monitoring equipment (Gas Watch III) and performing flow checks on connections while drilling MT6-08 Surface Section. Thank You Steve and let me know if you have any other questions, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.pola ek@conocophillips.com From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Wednesday, May 30, 2018 12:22 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: RE: [EXTERNAL]RE: Request for Waiver of Diverter Requirement on MT6-08 (PTD #218-048) Tom, Thank you for the additional information. I appreciate your help. One last question: the nearby Lookout 1, Lookout 2, MT6-03PH1 and MT6-05 wells all began drilling surface hole with mud weights ranging from 9.4 to 10.0 ppg. I notice that the Drilling Fluid Program for the MT6-08 surface hole interva specifies mud ranging from 9.0 to 10.0 ppg. Is 9.0 ppg sufficient? Thank you, Steve Davies Davies, Stephen F (DOA) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Tuesday, May 29, 2018 1:21 PM To: Davies, Stephen F (DOA) Subject: RE: [EXTERNAL]RE: Request for Waiver of Diverter Requirement on MT6-08 (PTD #218-048) Steve, Below is the data you have requested. As you know we didn't have a mud log on MT6-05. I took screen shots of our drilling data recorder and our Gas Watch III system. Highest reading during the Surface Section was 5 Units, which is around we the machine defaults to with no gas show. There is a screenshot at a very zoomed in scale of 0 to 100 units. Last screen shot shows the beginning of intermediate 1 section down to 3000' MD. MT6-05 Surface MD MW 0 9.4 980 9.8 1265 9.85 1342 9.8 1446 9.75 1662 9.8 1772 9.85 2024 9.85 Int 1 MD MW 2025 9.4 2159 9.4 2468 9.45 2773 9.55 3031 9.6 1 11226 .11 1 , 04 PITS removed pits'from the active system 08.00 I PITS adtled pits to the actio I -system I1 Rig Flo Ir set Bit PI sition fro I 115 ft l0 83 ft 0 12.OD ig Floor set Bit Position from 86 ft to 87 ft - :Ri to Ir set Bit Position fro I 179 ft to 179 16-00 �. 1 - --- -Rig se Lag was auto -configured -II 405 Auto roved -TVD at MD -296- .26 as receivedjby AUJ,O� Auto. roved T.VD.at MD.ft.was received lby.AUTOt-- 650 20 Auto oved TdD at MD.577.56.ft was receiveti'by AUTO Auto a oved-TVD at MD -766,06 ft was; re�jftr-7 by AUTO_ -MW-9 I 90UT-H2O@40BPH l04� �'� Rig FI sit Hole Depth from 12D5 IN 9.8 LUT-9:9+ 1315 IN.9.8� T -,8+— ---- 1415 = 1560 04.OU Rig Flog 24roed•Diff•Press @-1492-ft= 1670 IN 6.-7 UT- 9.9 1775 Rig Fl set Diff_Press to 0 psi @ 1697 MOV UD. -_ 1890 - 08=0D - r- - -- - 1995 IN' -,OUT9 9 ---- ---- 1940 _ D r MOVING MUD 1735 ® P added pits to the active System I� 9 IN/OUT H2O @ 20 May -13-2018 ° X10'E-228 ° ° 4 54 is00 -228 0 --- 100000 0 16.37 11226 11114 68:o(� 1 llo 110 120( 175 270 ?f:^ 90 15 Villi May -13-2018 0.43 'ruDa�e tura 1 11 lethe (GVO 1 1 Gori:, 1 I 735 735 875 1015 1140 00 0I 1290 1395 1510 04:0+ 1630 1745 1870 08.Oc, . 1965 1965 — 1805 E 1340 90 15 Villi May -13-2018 0.43 'ruDa�e tura 1 11 lethe (GVO 1 1 Gori:, 1 I 11226 14 a1 15.00 I IG GO 17.00 —� 17-2018 11114 0.01 0.03 2180, 09002220 2245 j 2315 10:W �. 2355 , 2470 t 11:01 2470 2505 2570 1200 2600 2670 2700 0 2770 13.01 14 a1 15.00 I IG GO 17.00 —� 17-2018 11114 0.01 0.03 Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.¢. polasek@conocoph illips.com From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Thursday, May 24, 2018 2:07 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: RE: [EXTERNAL]RE: Request for Waiver of Diverter Requirement on MT6-08 (PTD 11218-048) Tom, Since there is no mud log recorded in MT6-05, could you please provide a list of the mud weights used to drill the well from surface to 3000' MD? (I need MD and mud weight in ppg.) Are there any recorded gas measurement data from surface to 3000' MD? If so, could you please provide those data? Thank you, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.eov. From: Polasek, Tom G [mailto:Tom.G.Polasek@conocophillips.coml Sent: Tuesday, May 22, 2018 3:22 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]RE: Request for Waiver of Diverter Requirement on MT6-08 Steve, Attached is the requested MT6-05 Data. Let me know if you need anything else or in a different format. I acknowledge this information does not supplant reporting requirements of 20 AAC 25.070 or 20 AAC 25.071 for wells MT6-03 and MT6-05. Thank You, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.aov) Sent: Monday, May 21, 2018 2:55 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Cc: Schwartz, Guy L (DOA) <xuy.schwartz@alaska.gov> Subject: [EXTERNAL]RE: Request for Waiver of Diverter Requirement on MT6-08 Tom, I checked and, to date, the AOGCC has only received a single, Memory Cement Evaluation Log for MT6-03. We have not yet received recorded directional survey data, surface casing, geologic marker, mud log, or well -log information for wells MT6-03 and MT6-05. To support CPAI's Request for Waiver of Diverter Requirement for MT6-08, please provide the following information: 1. For MT6-03 and MT6-05, provide the recorded directional survey data in electronic form as Excel or ASCII -table files; 2. For MT6-03 and MT6-05, provide surface casing setting depth and geologic marker information as measured depths and true vertical depths; 3. For MT6-03, provide a field or final copy of the recorded mud log information as an electronic PDF -format image file and an electronic LAS -format data file; and 4. For MT6-03 and MT6-05, provide recorded field -copy LWD or open -hole well logging information for the surface and intermediate hole intervals as electronic LAS -format data files. Please note that providing the above preliminary information does not supplant any of the reporting requirements of 20 AAC 25.070 or 20 AAC 25.071 regarding MT6-03 or MT6-O5. Thank you, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 CONFIDENTIAUTY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.eov. From: Polasek, Tom G [mailto:Tom.G.Polasek@conocophillips.com] Sent: Monday, May 21, 2018 1:08 PM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.eov> Subject: Request for Waiver of Diverter Requirement on MT6-08 Guy, It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h) (2) is granted for well MT6-08. At Greater Moose's Tooth Pad MT6, two penetrations have been completed and there has not been a significant indication of shallow gas or gas hydrates above the C30 where casing will be set. MT6-08 is within 500 feet of both penetrations. MT6-08 planned surface casing shoe is 250.3 feet from well MT6-03 surface casing shoe and MT6-08 surface casing shoe is 59.5 from well MT6-05 surface casing shoe. Please see attached plot. Please advise if a request for waiver needs to be submitted through other form of communication. Thank You, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com Remark: AOGCC Coordinate Conversion Check 23 May 2018 INPUT Geographic, NAD83 OUTPUT State Plane, NAD27 5004 -Alaska 4, U.S. Feet Accuracies of conversions from NAD 83 to NAD 27 are typically 12 to 18 cm. GMTU MTG-08 ill Latitude: 70 15 21.503 Northingfr. 5945523.180 Longitude: 151 28 55.825 EastinglX: 317003.514 Convergence: -1 23 31.67200 Scale Factor: 0.999938042 Datum Shift (m.): Delta Lat. = 38.574, Delta Lon = -118.045 Corpscon v6.0.1, U.S. Army Corps of Engineers 12:131,"21,2018 MT6-08 wp06 500 ft Surface Casing View e poo �poy M�0 0 Mj0p3 600 400 c to 7 13.318" x 16" 0 200 �t -�` 1P.__13.318"x16" J. , r-. o + ti� 13-318" x 16" O Z r 0 U) -200 -400 -400 -200 0 200 400 600 800 1000 1200 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, May 10, 2018 1:59 PM To: 'Polasek, Tom G' Cc: Davies, Stephen F (DOA) (steve.davies@alaska.gov) Subject: RE: MT6-08 Changes, Conoco Alaska, Tom Polasek (PTD 218-048) Tom, Regarding the changes to the PTD application as proposed below: 1) It looks like steps 22-29 would be omitted if Pilot hole is not drilled. ( note in step No. 17 4.5" x 7" VBR would be installed). The change in the BHA logging tools is also appropriate as indicated below. 2) You are correct that AOGCC will require a CBL in the 7" liner. The 9 5/8" CBL is optional. So summarize.. the AOGCC will not require a formal sundry application to make the suggested changes below. We will modify the PTD for the well to reflect the changes and file this email in our system. Please also note that in step 47 the new window will require an FIT. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwortz@alasko.aov). From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Thursday, May 10, 2018 9:59 AM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: MT6-08 Changes, Conoco Alaska, Tom Polasek Hi Guy, I just left you a message on your phone regarding same topic, There are some changes to MT6-08 and I wanted to talk to you before submitting Sundry's. 1. We are dropping the Pilot Hole on MT6-08 and committing to drilling upper and lower laterals. Step 22.a in the procedure mentions Pilot hole data will be a trigger for drilling upper lateral or not. This changes the formation logging program. We now plan to run Gamm Ray and Resistivity in Surface, Intermediate 1, Intermediate 2 (SDL 7" Drill in Liner), and for both upper and lower laterals will run Gamm Ray, Resistivity and Neutron/Density. In Step 27 of procedure it mentions we will log the TOC in the 9-5/8" Intermediate 1 Section and there is no mention of logging TOC in the 7" SDL Section. This well is an injector and my understanding is AOGCC wants to see the Top Of Cement log for the 7" Liner. With further discussion with you, we will plan to log the TOC for the 7" Liner and not log TOC on the 9-5/8" Intermediate 1 Casing. After we discuss these topics, by phone or email, I will submit the necessary sundry's, if need be. Thanks Guy, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tomg.polasek@conocophillips.com TRANSMITTAL LETTER CHECKLIST WELL NAME: GNB 1 AL lYl (o - Oy� PTD: at g __Gql� Development Service —Exploratory _ Stratigraphic Test —Non -Conventional FIELD: (� ('tr,kr USES T�A POOL: �u" / C); / 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 V(& acquired for the pilot hole must be clearly differentiated in both well Pilot oly MO O, name (�-/1LI 1�. /1' M – 0$ 41 PH) and API number (50- /03 - `�-'0-�� for from records, data and logs acquired well µ )b_ name on permit). 5. 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 5/2013 WELL PERMIT CHECKLIST Field & Pool GRTR MOOSES TOOTH, ALPINE UN O - 28210 Engineering Well Name: GMTV MT6-08 Program SER Well bore seg ❑ PTD#:2180480 Company CONOCOPHILLIPS ALASKA, INC. Initial Class/Type SER / PEND GeoArea 890 Unit 10750 On/Off Shore On Annular Disposal ❑�/ Administration 17 Nonconven. gas conforms to AS31.05.0300.1.A),(j.2.A-D) _ _ _ _ _ . NA ..... . .... . . . . . _ 1 Permit fee attached _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .... NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 Lease number appropriate ......... . . .......... . . ........... . ..... No _ .. - _ Partially: AA.092345 closed in 2010. AA 081798 contains surface location; portion of well passes _ 3 Unique well name and number _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ .... through AA 081818; top prod interval and TO in AA 081819, SFD 4 Well located in. a. defined pool. _ _ _ _ _ _ _ . . . . . . ..... . . . Yes ...... Conservation Order No. 747, issued Mary 29. 2018, governs. Lookout Oil Pool. 5 Well located proper distance from drilling unit boundary. _ _ ............. No. _ No restrictions as to well spacing except that no pay shall be opened to a. well within 500 feet of an _ 6 Well located proper distance from other wells. ......... . ....... . . . . . . . No _ _ _ external property line where the owners and landowners are not the same on. both sides of the line, 7 Sufficient acreage available in. drilling unit. _ _ _ _ _ _ _ _ _ _ _ No _ As planned, this well conforms with statewide spacing requirements, _ 8 If deviated, is wellbore plat. included _ _ _ _ _ _ _ _ . . . . . ..... . . . . Yes 9 Operator only affected party...... _ _ ..... Yes 10 Operator has appropriate bond in force .. _ _ _ _ _ Yes Appr Date 11 Permit can be issued without conservation order _ _ _ _ _ _ _ _ _ _ Yes Conservation Order No. 747, issued. May 29, 2018,. governs_ Lookout Oil Pool__ 12 Permit can be issued without administrative approval _ _ Yes SFD 5/30/2018 13 Can permit be approved before 15 -day wait .. ..... _ Yes 14 Well located within area and strata authorized by Injection Order # (put. IO# in comments). (For. Yes _ _ _ _ Area Injection Order No. 40, issued May 29, 2018, governs Lookout Oil Pool....... 15 All wells within 114 mite area of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ .... Norte, . 16 Pre -produced injector: duration of pre production less than 3 months (For service well only) No _ ...... Operator; MT6-08 will only be flowed back enough to clean up. It will not be pre -produced...... 18 Conductor string. provided .... . . ............................. Yes .... _ 20 inch conductor set at115' .cemented Engineering 19 Surface casing protects all. known USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ____ _ _____ NA _ _ No aquifers .. Permafrost area 20 C.MT vol adequate.to circulate on.conductor & surf.csg ........................ Yes 21 CMT vol adequate to tie-in long string to surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No.. 95/6" int.1. casing will have 1000 ft of cement above shoe... 22 CMT will cover all known productive horizons. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes production. lateral will be. uncemented pert pups... _ _ _ _ _ _ ....... 23 Casing designs adequate for C,. T, B &. permafrost ..................... Yes BTC supplied in similar well on.pad.. 24 Adequatetankage or reserve pit . . . . . . . . . ........ . .... Yes _ _ _ Rig has steel pits.... All waste to approved disposal well. 25 If.a_re-drill, has a 10-403 for abandonment been approved . ..................... NA _ _ _ _ _ grassroots well.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .... 26 Adequate wellbore separation proposed- _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - Yes 27 If diverter required, does it meet regulations _ _ _ _ _ _ _ _ .......... Yes Diverter waived per 20 AAC 25,035 (h)(2) ....less than 200 R from other surface casing point Appr Date 28 Drilling fluid. program schematic.8, equip list adequate _ _ _ _ .. Yes _ max formation press= 3610.psi. (9.3 ppg ) will drill with 9.0 - 9.5 ppg using. MPD GLS 5/31/2018 29 BOPEs,do they meet regulation _ _ _ _ _ _ .. Yes.... _ _ on file. 30 BOPE.press rating appropriate; test to (put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ MASP= 3019 psi,., will test BOPE to 3500 psi (annular to 2500 psi)_ 31 Choke manifold complies w/API RP -53 (May 84). _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 32 Work will occur without operation shutdown _ _ _ _ _ _ _ _ _ _ _ .... - Yes .. .. 33 Is presence of H2S gas probable .................. . . . ........... . _ No... _ _ H2S not expected but rig has.sensors.and alarms... 34 Mecbanical.condition of wells within AOR verified (For. service well only) .............. Yes ..... _ _ 1/4 mile AOR completed .. No other.weils in area (besides planned lateral L1) 35 Permit can be issued w/o hydrogen. sulfide measures _ _ _ _ _ _ No _ _ _ H2S measures required. Expected reservoir pressure is 9.3 ppg EMW; well lot be. drilled using Geology 36 Data presented on potential overpressure zones _ _ _ _ _ _ _ _ _ Yes _ _ _ _ 9.0 to_ 110. ppg mud._ Production interval will be drilled with 8.8-9.5 ppg mud using. Managed Pressure Appr Date 37 Seismic analysis of shallow gas zones _ _ _ _ _ _ _ _ _ _ . NA _ .. Drilling Technique to. keep the well. balanced dynamically. Surface csg to be set above C-30 (Tuluvak SFD 5/30/2018 38 Seabed condition survey (if off -shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ ... sandstone). The 7"_csg shoe will. be set in the top of Alpine C reservoir. 39 Contact name/phone for weeklyprogressreports [exploratory only] . . . ... ........NA ....... Onshore injection well. _ ... Geologic Engineering Public Well will be considered for Annular disposal pending OA LOT results. GIs Commissioner: Date: Date DCommissioner: Com ioner Date 01