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Home My WebLink About218-070DATA SUBMITTAL COMPLIANCE REPORT 1 1/2612 01 8 Permit to Drill 2180700 Well Name/No. KUPARUK RIV U WSAK 1H -108A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23608-01-00 MD 9245 TVD 3784 Completion Date 6/29/2018 Completion Status P&A Current Status P&A UIC No REQUIRED INFORMATION / Mud Log No V/ Samples No Directional Survey Yes ✓ DATA INFORMATION List of Logs Obtained: GR/ RES (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CN Received Comments ED C 29534 Digital Data 1783 9245 7/18/2018 Electronic Data Set, Filename: CPAI_1H- 108A_VISION_Resistivity_LW D003_RM_LAS.Ias ED C 29534 Digital Data 32 1840 7/18/2018 Electronic Data Set, Filename: CPAI_1H- 108_Scope_Gamma_Ray_LWD001_RM_LAS.Ias ED C 29534 Digital Data 1647 6526 7/18/2018 Electronic Data Set, Filename: CPAI 1H- 108_VISION_Service_LW D002_RM_LAS.las ED C 29534 Digital Data 32 9245 7/18/2018 Electronic Data Set, Filename: CPAI 11-1- 108A_V IS ION_Resistivity_RM_LAS.Ias ED C 29534 Digital Data 7/18/2018 Electronic File: CPAI_1H- 108_Scope_Gamma_Ray_RM_DLIS_LW D001.d1i S ED C 29534 Digital Data 7/18/2018 Electronic File: CPAI_1H- 108_Scope_Gamma_Ray_RM_DLIS_LW D001.ht ml ED C 29534 Digital Data 7/18/2018 Electronic File: CPAI_1H- 108_VISION_Service_RM_DLIS_LW D002.diis ED C 29534 Digital Data 7/18/2018 Electronic File: CPAI_1H- 108_VISION_Semice_RM_DLIS_LW 0002.html ED C 29534 Digital Data 7 /1 812 01 8 Electronic File: CPAI_1H- 108A_V ISION_Resistivity_RM_DLIS_LW D003.diI s ED C 29534 Digital Data 7/18/2018 Electronic File: CPAI_11-1- 108A_VISION_Resistivity_RM_DLIS_LW D003.ht ml ED C 29534 Digital Data 7/18/2018 Electronic File: CPAI 1H- 108A_VISION_Resistivity_DLIS.dlis AOGCC Page 1 of 4 Monday, November 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 11/2612018 Permit to Drill 2180700 Well Name/No. KUPARUK RIV U WSAK iH.108A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23608-01-00 MD 9245 TVD 3784 Completion Date 6/29/2018 Completion Status P&A Current Status P&A UIC No ED C 29534 Digital Data 7/18/2018 Electronic File: CPAI_11-1- 108A_V IS ION_Resistivity_DL IS. htm I ED C 29534 Digital Data 7/18/2018 Electronic File: CPAI_1H- 108A_VI S ION_Resistivity_2MD_RM. pdf ED C 29534 Digital Data 7/18/2018 Electronic File: CPAI_1H- 108A_V IS ION_Resistivity_2TVD_RM_above90_d egrees.pdf ED C 29534 Digital Data 7/18/2018 Electronic File: CPAI_11-1- 108A_V IS ION_Resistivity_2T V D_RM_below90_d egrees.pdf ED C 29534 Digital Data 7/18/2018 Electronic File: CPAI_1H- 108A_V I S ION_Resistivity_5MD_RM. pdf ED C 29534 Digital Data 7/18/2018 Electronic File: CPAI_1H- 108A_VI S ION_Resistivity_5T V D_RM_above90_d egrees.pdf ED C 29534 Digital Data 7/18/2018 Electronic File: CPAI_1H- 108A_V IS ION_Resistivity_5T V D_RM_below90_d egrees.pdf ED C 29534 Digital Data 7/18/2018 Electronic File: CPAI_1H- 108A_Pri ntSurveyList. csv ED C 29534 Digital Data 7/18/2018 Electronic File: Gyrodata Survey - 11-1-108A - Post SLB SAG.pdf ED C 29534 Digital Data 7/18/2018 Electronic File: Gyrodata Survey - 1 H-1 08A - Post SLB SAG.xlsx ED C 29534 Digital Data 7/18/2018 Electronic File: 1H -108A NAD27 EOW Compass Surveys [Canvas].txt ED C 29534 Digital Data 7/18/2018 Electronic File: 11-1-108A NAD27 EOW Compass I Surveys [Macro].txt ED C 29534 Digital Data 7/18/2018 Electronic File: 11-1-108A NAD27 EOW Compass Surveys [Petrel].txt ED C 29534 Digital Data 7/18/2018 Electronic File: 11-1-108A NAD27 EOW Compass Surveys [Surveys].txt ED C 29534 Digital Data 7/18/2018 Electronic File: 11-1-108A NA027 EOW Compass Surveys.pdf ED C 29534 Digital Data 7/18/2018 Electronic File: 1H -108A NAD83 EOW Compass Surveys [Canvas].txt AOGCC Page 2 of 4 Monday, November 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 11/26/2018 Permit to Drill 2180700 Well Name/No. KUPARUK RIV U WSAK 1H -108A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23608-01-00 MD 9245 TVD 3784 Completion Date 6/29/2018 ED C 29534 Digital Data ED C 29534 Digital Data ED C 29534 Digital Data ED C 29534 Digital Data Log C 29534 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report YD Production Test Information //®A Geologic Markers/Tops (!Y 1.1 COMPLIANCE HISTORY Electronic File: 1H -108A NAD83 EOW Compass Completion Date: 6/29/2018 Release Date: 7/2/2018 Description Surveys [Surveys].txt Comments: Interval Start Stop Completion Status P&A Current Status P&A UIC No 7/18/2018 Electronic File: 11-1-108A NAD83 EOW Compass Surveys [Macro].txt 7/18/2018 Electronic File: 1H -108A NAD83 EOW Compass Surveys [Petrel].txt 7/18/2018 Electronic File: 1H -108A NAD83 EOW Compass Surveys [Surveys].txt 7/18/2018 Electronic File: 1H -108A NA083 EOW Compass Surveys.pdf 0 0 2180700 KUPARUK RIV U WSAK 1H -108A LOG HEADERS Sample Set Sent Received Number Comments Directional / Inclination Data 0 Mechanical Integrity Test Information Y / NA Daily Operations Summary Date Comments Mud Logs, Image Files, Digital Data Y /® Core Chips Y / A Composite Logs, Image, Data FilesoY Core Photographs Y Cuttings Samples Y /FA Laboratory Analyses Y / NA AOGCC Page 3 of 4 Monday, November 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 11/26/2018 Permit to Drill 2180700 Well Name/No. KUPARUK RIV U WSAK 1H -108A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23608-01-00 MD 9245 TVD r37 C mpletion ate 6/29/2018 Completion Status P&A Current Status P&A UIC No Compliance Reviewed By: _ Date: AOGCC Page 4 of 4 Monday, November 26, 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 01 2098 Anr,r- r. WELL COMPLETION OR RECOMPLETION REPORT AM Mg- la.WellStatus: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑� Suspended ❑ 20AAC 25.105 20AAC 25.110 ElWINJ E]WAG[-❑ No. of Completions: 1b. Well Class: Developmen Exploratory E]GINJ Service M d(V Stratigraphic Test ❑ 2. Operator Name: ConocoPhillrps Alaska, Inc. 6. Date Comp., Susp., or Abend.: 6/29/2018 14. Permit to Drill Number / Sundry: 218-070 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 6/26/2018 15. API Number: 50-029-23608-01-00 4a. Location of Well (Governmental Section): Surface: 50' FSL, 770' FEL, Sec 28, T12N, R10E, UM Top of Productive Interval: 2417' FNL, 2355' FEL, Sec 34, T12N, R10E, UM Total Depth: 2428' FNL, 5083' FEL, Sec 35, T12N, R10E, UM 8. Date TD Reached: 6/27/2018 16. Well Name and Number: KRU 1H -108A 9. Ref Elevations: KB:92.99 GL:54 BF: 17. Field / Pool(s): Kuparuk River Field(West Salk Oil Pool 10. Plug Back Depth MDlrVD: 4311/2862 18. Property Designation: ADL 25639, ADL25638 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 549570.98 y- 5980762.52 Zone- 4 TPI: x- 553287 y- 5978311 Zone- 4 Total Depth: x- 555839 y- 5978319 Zone- 4 11. Total Depth MDTrVD: 9245/3784 19. DNR Approval Number: 80-261 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MDlrVD: 1685/1635 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 193911858 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 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 20 94 H-40 Surface 119 Surface 119 42 Existing, cement to surface 10.75 45.5 L-80 Surface 1834 Surface 1767 13.5 969 sx 11.0 Class G, 221sx 24. Open to production or injection? Yes ❑ No 0 If Yes, list each interval open (MD(f VD of Top and Bottom; Perforation Size and Number; Date Perfd): OTi�� % VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDIrVD) 3112 1834 N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes E]No E]O/ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): PLUGGED BACK Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24- our Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): V/L/l/a/l - r Form 10407 Revised 5/2017 RBDM� SEP 10 20�QNTINUED ON PAGE 2 Submit ORIGINIAL only- �'.A,$. tt�16'f� 28. CORE DATA Conventional Corals): Yes ❑ No ❑Q Sidewall Cores: Yes ❑ No D If Yes, list formations and intervals cored (MD/TVD, Fromlro), 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 I] If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1685 1635 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 6585 3716 information, including reports, per 20 AAC 25.071. Formation @ TPI -West Sak TD 9245 3784 Formation at total depth: West Sak 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 analysis, I 7. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L. Alvord Contact Name: Nick Lehman AAW -{or WL - Authorized Title: Alas Drillin Mans er Contact Email: nick. r.lehmana co .com Authorized _ 1 A Contact Phone: 263-4951 % Signature: ate: V 0 ` INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10104 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 1 a: 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 1b: 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: 50-029-20123-00A0). 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 �n I t w Wellhead /Tubing Hanger /'Free 13-3/8"x4-�h"HYD563, 5M 1H-1 OBA Injector Well Design Insulated Crossover below TH: 4-1/2"x3-1/2"Tubing Proposed Temporary Conductor: 20" Abandonment Casing I I I I 13-1h" HOLE & 10-3/4" 45.5#, L-80 HYD563 I\ r @ 1,834 ft MD 3-I/2", 9.3 #, 1-80, EUE 1,764'MD/1,705'TVD \ Top of Kickoff Plug @ \\ 1784'MD/ 1,723'TVD �\ \ Btm of Kickoff Plug @ \ \ 2284'MD/2,131'TVD \\ Top of Abandonment Plug #4 @ 431 1' MD / 2,862' TVD \t- Top of Ugnu C actual @ 5,065' MD / 3, l 13' TVD Ban of Abandonment Plug #4 @ 5,011' \ \ MD I3,093'TVD \ \ \ \ Top of Abandonment Plug #3 @ 5472' /► MD / 3.272' TVD t-- Top of N -Sand actual @ 6,093' MD / 3,513' TVD Btm of Abandonment Plug #3 @ 5,972' MD / 3,463' TVD 4-- Top of WestSak D -Sand actual @ 6,585' MD / 3,714' TVD Top of Abandonment Plug #2 @ 5.972' \\ {- Top of WestSak B -Sand actual @ 6,766 MD / 3,790' TVD MD / 3,463' TVD \\ \\ 4*. - Top of WestSak A4 -Sand actual @ 6,856' MD / 3,828' TVD Ban of Abandonment Plug #2 @ 6,585' \\ \\ t-- Top of WestSak A3 -Sand actual @ 6,958' MD / 3,872' TVD MD / 3,714' TVD Top of Abandonment Plug #1 @ 7,000' MD / 3.890' TVD Bum of Abandonment Plug #1 @ 7,500' MD / 4,049' TVD - Top of WestSak A2 -Sand actual @ 7,179' MD / 3,963' TVD 8-3/4" HOLE \t �- @ 9,245' MD / 3784' TVD Top of WestSak D -Sand actual @ 9,187' MD / 3,802' TVD R\ \ Top of WestSak B -Sand actual @ 8,990' MD / 3,866' TVD \Top of WestSak A4 -Sand actual @ 8,888' MD / 3,898' TVD Top of WestSak A3 -Sand actual @8,763' MD / 3,937' TVD Top of WestSak A2 -Sand actual 0 8,517' MD / 4,005' TVD J��',\ KUP PROD 1H -108A cwocaP fillips Well Attribut Max Angle TD 41 RJl.lJ�Al Y WEST 5002am60801 PRODasraw: 11,111, mD m,._. Oct80lnxRl Nagkry,hK WEST SAS 500292360801 PROD 9,2480 in -you. wYrzmea4e:4Y nrn last Tag V+Mslvlmiu! (.qpnnotatlon LAST TAG Ena Datr Ceym (MB)IaatMM BY jennalt Last Rev Reason Anno on E.O Deb IasIMM BY 14W3ER. azo _................................................................ ................... REV REASON jennalt __.......................................... xo Re9ure n�Wl:>&z C0NDXT0R,M0I%0 INTERMEDNTE: -lull SVRFPCE; 40.61.aa1.3� Summary (with Timelog Depths) 1H-108 lipoperations Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log D Start Depth Smd Time End Time Dur (M ase Ph Op code AcOvdy Code Tee hP-T-X O p ¢ration pt Ertl Depth (flKa) 6/4/2018 6/4/2018 0.75 MIRU MOVE MOB P Move rock washer & pipe shed. 0.0 0.0 00:00 00:45 SIMOPS install Amphion/NOVOS upgrade in drillers cab. 6/4/2018 6/4/2018 1.00 MIRU MOVE MOB. P Move power module. Install travel 0.0 0.0 00:45 01:45 tongue on sub. Finish unplugging interconnects f/ pits to sub. SIMOPS install Amphion/NOVOS upgrade in driller cab. 6/4/2018 6/4/2018 1.00 MIRU MOVE MOB P Skid dg floor & raise stompers. 0.0 0.0 01:45 02:45 6/4/2018 6/4/2018 0.50 MIRU MOVE MOB P Latch sub to truck & move off 1 H-110. 0.0 0.0 02:45 0315 6/4/2018 6/4/2018 2.25 MIRU MOVE MOB P Move sub towards 1H-108. Set dg 0.0 0.0 03:15 05:30 mats for 1H-108. Spot sub over well. Remove travel tongue & skid rig floor to drill position. 6/4/2018 6/4/2018 0.50 MIRU MOVE MOB P Spot pits complex to sub base. 0.0 0.0 05:30 06:00 6/4/2018 6/4/2018 2.00 MIRU MOVE MOB P Spot pumps, power, pipe shed, & rock 0.0 0.0 06:00 08:00 washer. SIMOPS install Amphion/NOVOS upgrade in drillers cab. 6/4/2018 6/4/2018 3.00 MIRU MOVE RURD P Spot cuttings tank, hook up all 0.0 0.0 08:00 11:00 interconnects, lower/secure skate rail & test skate. Complete rig acceptance checklist@ 11:00 hrs. 6/4/2018 6/412018 1.00 MIRU MOVE NUND P Torque diverter tee & annular flanges. 0.0 0.0 11:00 12:00 Attach diverter line extension. Swap to shore power at 12:00 hrs. 6/4/2018 6/4/2018 3.00 MIRU MOVE NUND P Obtain RKB's. Nipple up riser 0.0 0.0 12:00 15:00 extension, riser & mouse hole. Align & secure annular. Hook up kill, choke, & cement lines in interconnects. Secure all tools & housekeeping. As of 15:00 hrs decision was made to perform maintenance as bridge has washed out. Release from 1 H-108 and accept onto summer maintenance. 6/16/2018 6/16/2018 2.75 MIRU MOVE BOPE P Perform Diverter Test, Test witnessed 0.0 0.0 12:00 14:45 by AOGCC Rep Guy Cook. - Knife valve open in 7 sec; annular closed in 30 sec; initial system pressure 3050 psi; pressure after closure 1950 psi; 200 psi recharge time 6 sec; full recharge 45 sec; 6 nitrogen bottles avg pressure 2033 psi; test gas, flow, & pit level alarms.. 1 - FP change out knife valve hydraulic hoses for fire rated hydraulic hoses. 6/16/2018 6/16/2018 0.50 MIRU MOVE SFTY P Pre-spud meeting held with rig crew, 0.0 0.0 14:45 15:15 SLB directional, MI Rep, & CPAI Rep. 6/16/2018 6/1612018 2.25 MIRU MOVE BHAH P PJSM, pick up surface BHA 1 as per 0.0 91.0 15:15 17:30 SLB DD to 91' MD. 6/16/2018 6/16/2018 0.50 MIRU MOVE SEQP P Flood high pressure mud lines to top 91.0 91.0 17:30 18:00 drive. Test high pressure mud lines to 3500 psi, good test. 6/16/2018 6/16/2018 2.00 MIRU MOVE DRLG P Clean out conductor wl 13-1/2" 91.0 119.0 18:00 20:00 surface drilling assembly f/ 91'-119' MD, 119' ND, 450 gpm, 450 psi on, off 425 psi, FO 32%, 40 rpm, Tq 2K, off 1 K, WOB 2K, PU 64K, SO 70K, ROT 66K, MW 8.8ppg, Max Gas 0. Page 1136 Report Printed: 811012018 / Operations Summary (with Timelog Depths) 4 ' 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SW Depth slant Time End Time Our (hr) Phase Op Code Activity Code Time P -T -x Operation (M(B) End Depth (ftKB) 6/16/2018 6/17/2018 4.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface hole f/ 119.0 301.0 20:00 00:00 119'-301' MD, 301' TVD, 450 gpm, 550 psi on, 475 psi off, FO 38%, 50 rpm, Tq on 2K, off 1 K, WOB 9K, PU 64K, SO 70K, ROT 66K, MW 8.8 ppg, Max Gas 0, AST 0, ART 2.56, ADT 2.56, BIT 2.56, Jars 2.56. Total Footage 182' 6/17/2018 6/17/2018 6.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface hole f1 301.0 797.0 00:00 06:00 301'-797' MD, 796' TVD, 500 gpm, 1100 psi on, 950 psi off, FO 38%, 60 rpm, Tq on 4K, off 3K, WOB 29K, PU 78K, SO 82K, ROT 79K, MW 9.0 ppg, AST 1.53, ART 2.43, ADT 3.96, BIT 6.46, Jars 3.94. Total Footage 496' 6/17/2018 6/17/2018 6.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface hole it 797.0 1,367.0 06:00 12:00 797'-1367' MD, 1346' TVD, 550 gpm, 1400 psi on, 1150 psi off, FO 40%, 60 rpm, Tq on 5K, off 1 K, WOB 29K, PU 93K, SO 93K, ROT 92K, MW 9.4+ ppg, AST 2.35, ART 2.03, ADT 4.38, BIT 10.86, Jars 8.34. Total Footage 570'. 6/17/2018 6/17/2018 5.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface hole f/ 1,367.0 1,840.0 12:00 17:00 1367'-1840' MD, 1772' TVD, 550 gpm, 1424 psi on, 1360 psi off, FO 37%, 60 rpm, Tq on SK, off 1K, WOB 29K, PU 97K, SO 100K, ROT 96K, MW 9.5 ppg, AST 1.58, ART 1.52, ADT 3. 10, BIT 13.96, Jars 11.44. Total Footage 473'. 6/17/2018 6/17/2018 0.75 SURFAC CASING BKRM P BROOH f/ 1840'-1703' MD, 552 gpm, 1,840.0 1,703.0 17:00 17:45 1205 psi, FO 36%, 60 rpm, Tq 2K, PU 97, SO 100, ROT 96K. Shoot final survey on bottom. BROOH w/ 1 BU during 1 stand on drill pipe. 6/17/2018 6/17/2018 0.50 SURFAC CASING OWFF P Monitor well, static. 1,703.0 1,703.0 17:45 18:15 6/17/2018 6/17/2018 2.75 SURFAC CASING BKRM P BROOH f/ 1703'-850' MD, 554 gpm, 1,703.0 850.0 18:15 21:00 1090 psi, FO 37%, 60 rpm, Tq 2K. 6/17/2016 6118/2018 3.00 SURFAC CASING BHAH P Rack back 2 stands of HWDP, lay 850.0 32.0 21:00 00:00 down remaining HWDP & BHA 1 f/ 850'-32' MD, as per SLB DD. 6118/2018 6/18/2018 0.50 SURFAC CASING BHAH P Continue laying down BHA 1. Pull mud 32.0 0.0 00:00 00:30 motor, flush & break off bit (3,2,WT,A,E,1,NO,TD). Clean & clear dg floor. 6/18/2018 6/18/2018 1.50 SURFAC CASING RURD P Rig up casing handling equipment for 0.0 0.0 00:30 02:00 - 10-3/4" surface casing. PJSM for all personnel involved in running casing. 6/18/2018 6/18/2018 0.75 SURFAC CASING PUTS P Make up 10-3/4", 45.5#, L-80, Hydril 0.0 125.0 02:00 02:45 563, dopeless shoe track to 125' MD. First 2 joints centralized with 2 bowspdng centralizers at 10' from top & bottom. Centralizer installed on each collar after. Connections Bakerl-ok'd & torque to 19,400 fVlbs. Check floats, good. 6/18/2018 6/1812018 4.25 SURFAC CASING PUTB P Continue to run 10-3/4", 45.5#, L-80, 125.0 1,790.0 02:45 07:00 Hydril 563, dopeless casing f/ 125'- 1790' MD, PU 117K, SO 102K, connections torque to 19.4K, centralized on each collar, total centralizers ran 44 & 4 slop rings. Page 2135 Report Printed: 8110/2018 Operations Summary (with Timelog Depths) 1H-108 .t> Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tare End Time our (hr) Phase Op code Activity Code Time P -T -X Operation IRKS) End Depth (fit®) 6/18/2018 6/18/2018 0.50 SURFAC CASING PUTS P Make up Vetco fluted casing hanger & 1,790.0 1,834.0 07:00 07:30 landing joint. Wash down at 3 bpm, 145 psi, FO 16%, PU 117K, SO 112K, land hanger w/ shoe depth at 1834' MD, 1776'TVD. 6/18/2018 6/18/2018 0.75 SURFAC CEMENT CIRC P Circulate & condition mud for 1,834.0 1,834.0 07:30 08:15 cementing, stage up pump to 8 bmp, ICP 145 psi, FCP 130 psi, FO 22%, PU 117K, SO 112K, reciprocate pipe 20'. 6/18/2018 6/18/2018 0.25 SURFAC CEMENT RURD P Rig up cement manifold & cement line 1,834.0 1,834.0 08:15 08:30 to Violent CRT. Blow down the top drive. 6/18/2018 6/18/2018 2.75 SURFAC CEMENT CIRC P Circulate & condition mud for 1,834.0 1,834.0 08:30 11:15 cementing, stage up pump to 8 bmp, ICP 309 psi, FCP 270 psi, FO 22%, _ PU 117K, SO 112K, reciprocate pipe 20'. 6/18/2018 6/18/2018 3.25 SURFAC CEMENT HOSO P PJSM w/ all involved parties for 1,834.0 0.0 11:15 14:30 cementing. Pump 5 bbls of H2O to flood lines. Test cement lines to 3500 psi, good. Pump 40 bbls of CW -100, 5 bpm, 120 psi, FO 13%. Pump 76 bbls of 10.5 ppg Mud Push II w/ red dye, 5 bpm, ICP 152 psi, FCP 130 psi, FO 16%. Drop bottom plug. Pump 328 bbls of 11 ppg Lead Cement, 6 bpm, 171 psi, FO 15%. Pump 65 bbis of 12 ppg Tail Cement, 5-6 bpm, ICP 220 psi, FCP 274 psi, FO 15%, PU 117K, SO 97K. Drop top plug. Kick out plug w/ 10 bbls of H2O. Swap to rig & pump treated 9.6 ppg mud, 7 bpm, ICP 250 psi, FCP 391 psi, FO 17%. Reciprocate casing w/20 strokes throughout job & land casing on hanger w/ 1000 strokes pumped by rig pump. Slow pump rale to 3 bpm at 1300 strokes, 250 psi, FO 11%. Bump the plug with 1569 strokes, pressuring up to 750 psi. Hold pressure for 5 minutes, bleed off, & floats holding. CIP @ 14:13 hrs. Total of 84 bbls of cement back to surface. 6/18/2018 6/18/2018 0.75 SURFAC CEMENT PRTS P Pressure test 10-3/4" surface casing 0.0 0.0 14:30 15:15 to 3000 psi for 30 minutes, charted. Pressure up w/ 9.6 ppg mud at 7 spm to 3340 psi in 32 strokes. Shut in & observe pressure for 30 minutes. ISICP 3280 psi, FSICP 3280 PSI, bled back 3 bbls. 6/18/2018 6/18/2018 1.25 SURFAC CEMENT RURD P Rig down / blow down testing & 0.0 0.0 15:15 16:30 cementing equipment. RD cement lines & manifold. Lay down Volant CRT. Pull landing joint. Clear rig floor of casing & cementing equipment. 6/18/2018 6/18/2018 0.50 SURFAC CEMENT WWWH P Make up stack washing tool &flush 0.0 0.0 16:30 17:00 surface stack w/ black H2O pill at 866 gpm, 115 psi, FO 35%, 30 rpm, Tq 1 K, Blown down top drive & lay down stack washing tool. 6/18/2018 6/18/2018 3.00 SURFAC CEMENT NUND P Drain stack, remove 4" conductor 0.0 0.0 17:00 20:00 valves, riser, annular, diverter tee & starting head. Rig down diverter line. Page 3/35 Report Printed: 8/10120181 Operations Summary (with Timelog Depths) . 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Sten Tena End Tme Dur(hr) Phase Op Code Activity Code Tme P -T -X Operation (nKB) End Depth (W) 6/18/2018 6/18/2018 3.75 SURFAC WHDBOP NUND P Prep casing hanger & install thread 0.0 0.0 20:00 23:45 ring. Set wellhead per GE Rep. Orientation verified by CPAI Rep & pad Operator. Install flanges on well head valves. Install sweeping 90's. Top of cement measured T below hanger flutes. 6/18/2018 6/19/2018 0.25 SURFAC WHDBOP NUND P Test seal between casing hanger& 0.0 0.0 23:45 00:00 wellhead to 2000 psi for 10 minutes, witnessed by CPAI Rep. 6/19/2018 6/19/2018 3.00 SURFAC WHDBOP NUND P Set spacer spool and stack / TQ all 0.0 0.0 00:00 03:00 flanges. set riser and install choke / Kill lines, 6/19/2018 6/19/2018 0.50 SURFAC WHDBOP RURD P Rig up to test BOPE 0.0 0.0 03:00 03:30 6/19/2018 6/19/2018 4.50 SURFAC WHDBOP BOPE P Test BOPE equipment. BOPE test 0.0 0.0 03:3.0 08:00 waived witness by AOGCC Matt - Herrera. Test performed at 50 psi low / 3,500 PSI high with 3 1/2" & 7" test joint. choke valves 1-14, Upper and lower IBOP valves. Kill valves on floor, Mez, HCR kill, Man kill, XT 43 TIW and dart. Man /Hyd choke test to 2,500 PSI. w3 1/2" and 4 1/2" test jt with lower VISITS. HCR, and man choke. Koomey drawn down test - ISP = 2,900 PSI, after closure 1,950 PSI. 200 PSI in 12 sec. Full pressure in 42 Sec. 6 bill average of 1,975 PSI. Test pit level alarms & FO system. H2S / combustible gas alarms. H2S tested audible and light. Passed. 6/19/2018 6/19/2018 1.00 SURFAC WHDBOP RURD P Pull test plug and install 12 1/4" wear 0.0 0.0 08:00 09:00 bushing. RILDS X2. RD testing equip an BD same. 6/19/2018 6/19/2018 2.00 SURFAC CEMENT SLPC P Slip & Cut 73' of 1.375" DL. Calibrate 0.0 0.0 09:00 11:00 Amphion system. 6/19/2018 6/19/2018 2.00 SURFAC CEMENT SHAH P PU/MU drilling BHA#2 to 99' MD. 0.0 388.0 11:00 13:00 Pre job safety meet. Monitor disp via pit 1. 6/19/2018 6/19/2018 0.75 SURFAC CEMENT TRIP P RIH with drilling BHA#2 on 4 1/2" DP 388.0 1,443.0 13:00 13:45 from 388' MD - 1,443' MD. Monitor disp via Pit 1. Up WT = 84K. OWN WT = 82K. 6/19/2018 6/19/2018 0.25 SURFAC CEMENT DHEQ P Shallow hole test MWD, @ 1,443' MD. 1,443.0 1,443.0 13:45 14:00 with 500 GPM @ 855 PSI DPP. 30% F/O. (PASSED). BD TD. 6/19/2018 6/19/2018 5.50 SURFAC CEMENT OTHR P Comission New NOVIS system. Work 1,443.0 1,443.0 14:00 19:30 7" casing in pipe shed / house keeping. 6/19/2018 6/19/2018 0.75 SURFAC CEMENT TRIP P RIH with Drilling BHA#2 from 1,443' 1,443.0 1,730.0 19:30 20:15 MD - 1,730' MO monitoring disp via Pit #1. Up WT=86K DWN WT=83K. Conduct 5 min test on OA valve to 3,000 PSI. (PASSED) 6/19/2018 6/19/2018 2.25 SURFAC CEMENT DDRL P Drill out shoe tract system and 20' new 1,730.0 1,860.0 20:15 22:30 hole. 60 RPM 4K TQ, 550 GPM @ 1,040 PSI DPP. C/O to 1,860'. UP W T= 86K, OWN WT = 84K. 6/19/2018 6/19/2018 1.00 SURFAC CEMENT CIRC P Circulate BU X2 for mud conditioning. 1,860.0 1,860.0 22:30 23:30 580 GPM @ 1,100 PSI DPP. recip pipe above shoe while rotating 60 RPM. 9.5+ in 9.5+ out. 6/19/2018 6/20/2018 0.50 SURFAC CEMENT FIT P Perform FIT to 220 PSI - 12 PPG 1,860.0 1,860.0 23:30 00:00 1 1 1 1 EMW. (PASSED) Page 4/35 ReportPrinted: 8110/2018 operations Summary (with Timelog Depths) IH -108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sad oepm Start TNie EM Toe Our ft) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth(xKB) 6/20/2018 6/20/2018 6.00 PROD1 DRILL DDRL P DDRL from 1,860'MD - 2,692'MD 1,860.0 2,692.0 00:00 06:00 2,372' TVD. 650 GPM @ 981 PSI DPP. 29% F/O 140 RPM @ 31K TQ. 2 -61K WOB with ECD's 10.24 PPG. Off bottom - 950 PSI, UP WT = 96K, OWN WT = 90K. ROT - 92K. 2K TQ, Max gas = 404 units. ADT - 4, Bit Hrs - 4, Jar hrs. - 48.52 SPRs @ 2,120' MD 2,004' TVD MW = 9.1 Time 0300 hrs MP 1) 30 SPM - 90 PSI 40 SPM - 120 PSI MP 2) 30 SPM - 90 PSI 40 SPM - 120 PSI 6/20/2018 6/20/2018 6.00 PRODt DRILL DDRL P DDRL from 2,692' MD 2,372' TVD - 2,692.0 3,738.0 06:00 12:00 3,738' MD 2,956' TVD. 650 GPM @ . - 1,257 PSI DPP. 30% F/O 140 RPM @ 5K TQ. 14K WOB with ECD's 10.86 PPG. Off bottom - 1,277 PSI, UP WT =111 K, DWN WT=92K. ROT -99K. 3K TO, Max gas = 51 units. ADT - 4.21, Bit Hrs - 8.21, Jar hrs. - 52.73 SPRs @ 2,782' MD 2,427' TVD MW = 9.0 Time 0630 hrs MP 1) 30 SPM - 120 PSI 40 SPM - 160 PSI MP 2) 30 SPM - 120 PSI 40 SPM - 150 PSI 6/20/2018 6/20/2018 6.00 PRODt DRILL DDRL P DDRL from 3,738' MD 2,956' TVD - 3,738.0 4,403.0 1200 18:00 4,403' MD 3,216' TVD. 650 GPM @ 1,408 PSI DPP. 30% F/O 140 RPM @ 5K TO. 14K WOB with ECD's 10.51 PPG. Off bottom - 1,390 PSI, UP WT =110K,DWNWT=90K. ROT -99K. 3K TO, Max gas = 105 units. ADT - 3.22, Bit Hrs - 11.43, Jar hrs. - 55.95 6/20/2018 6/21/2018 6.00 PROD1 DRILL DDRL P DDRL from 4,403' MD 3,216' TVD - 4,403.0 5,332.0 18:00 00:00 5,332' MD 3,575' TVD. 650 GPM @ 1,492 PSI DPP. 30% F/O 140 RPM @ 6K TQ. 14K WOB with ECD's 10.83 PPG. Off bottom - 1,450 PSI, UP WT =117K, DWN WT=93K. ROT - 105K. 5K TQ, Max gas = 43 units. ADT - 3.49, Bit Hrs - 14.92, Jar hrs. - 59.44 SPRs @ 4,591' MD 3,291' TVD MW = 9.1 Time 1900 hrs MP 1) 30 SPM - 200 PSI 40 SPM - 240 PSI MP 2) 30 SPM - 200 PSI 40 SPM - 240 PSI Page 5135 ReportPrinted: 811012015 operations Summary (with Timelog Depths) IH -108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log San Depth Stan Time End Time Dur (W) Phase Op Code Activity Code Time P -T -X Operation (RKS) End Depth(KKB) 6/21/2018 6/21/2018 6.00 PROD1 DRILL DDRL P DDRL from 5,332' MD 3,575' TVD - 5,332.0 6,208.0 00:00 06:00 6,208' MD 3,916' TVD. 650 GPM @ 1,635 PSI DPP. 30% F/O 160 RPM @ - 8K TO. 10K WOB with ECD's 10.94 PPG. Off bottom - 1,620 PSI, UP WT =130K, OWN WT=96K. ROT - 108K. 5K TO, Max gas = 154 units. ADT - 3.55, Bit Hrs - 18.47, Jar hrs. - 62.99 6/21/2018 6/21/2018 1.50 PROD1 DRILL DDRL P DDRL from 6,208' MD 3,916' TVD - 6,208.0 6,527.0 06:00 07:30 6,527' MD 4,043' TVD. 650 GPM @ 1,820 PSI DPP. 30% F/O 160 RPM @ 8K TQ. 18K WOB with ECD's 11.04 PPG. Off bottom - 1,760 PSI, UP WT = 130K, DWN WT= 100K. ROT - 108K. 6K TO, Max gas = 144 units. ADT - 1, Bit Hrs - 19.47, Jar hrs. - 63.99 6121/2018 6/21/2018 0.75 PROD1 CASING CIRC P Final survey and SPR's, BROOH from 6,527.0 6,497.0 07:30 08:15 6,527' MD - 6,497' MD. at 650 GPM @ 1,760 PSI DPP. 30% F/O, 130 RPM, 6K TO. UP WT = 130K, DWN WT = 100K. ROT= 108K. Total strokes pumped = 3,875 6/21/2018 62112018 0.50 PROD1 CASING OWFF P OWFF (Static) 6,497.0 6,497.0 08:15 08:45 6/21/2018 6/21/2018 3.25 PROD1 CASING BKRM P BKRM OOH from 6,497' MD -5,245' 6,497.0 5,245.0 08:45 12:00 MD with 650 GPM @ 1,790 PSI DPP. with FCP 1,638 PSI DPP 30% F/O 11.08 ECD. 120 RPM 51K TO, UP WT = 95K. 6/21/2018 6/21/2018 6.00 PROD1 CASING BKRM P BKRM OOH from 5,245'MD - 3,170' 5,245.0 3,170.0 12:00 18:00 MD 650 GPM @ 1,374 PSI DPP, 30 % F/O, 120 RPM, 10.80 ECD, 4K TO, 88K UP WT while BKRM. 6/21/2018 6/21/2018 3.00 PROD1 CASING BKRM P BKRM OOH from 3,170' MD - 1,824' 3,170.0 1,824.0 18:00 21:00 MD. 650 GPM @ 1,374 PSI DPP. 30% F/O, 120 RPM With ECD 10.80 PPG. 4K TQ UP WT = 88k. 621/2018 6/21/2018 1.00 PROD1 CASING CIRC P Circulate while recip in shoe @ 700 1,824.0 1,824.0 21:00 22:00 GPM, 1,200 PSI DPP, 110 RPM with UP WT=82K. DWN WT=80K. pump 5,000 STKS. observe well 10 min (Static). 6121/2018 621/2018 1.00 PROD1 CASING TRIP P POOH from 1,824' MD - 388' MD 1,824.0 388.0 22:00 23:00 rackin gback 4.5" DP. Monitor well at HWDP 10 min. 6/2112018 6/22/2018 1.00 PROD1 CASING SHAH P Begin breaking down 8 3/4" BHA 388.0 226.0 23:00 00:00 6122/2018 6/22/2018 1.50 PRODi CASING BHAH P Continue to LD 8 3/4" drilling BHA. 226.0 0.0 00:00 01:30 clear and clean rig floor. 6/22/2018 6/22/2018 1.00 PROD1 PLUG RURD X RU 3 1/2" handling equipment for 3 0.0 0.0 01:30 02:30 1/2" EUE cement stinger asym. 6/22/2018 6/22/2018 4.75 PROD1 PLUG TRIP X MU and RIH with 1,193.92' of 3 1/2" 0.0 6,250.0 02:30 07:15 9.3# L-80 cement stinger asym for P&A program. PUsh in hoe with 4 1/2" DPto 6,250' MD in preparation for plug program. Page 6135 ReportPrinted: 811012018 Uperations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth De Stan Time End Tine Dur(hr) ( ) Phase OP Code Apivity Code Time P -T -X Operation (n EM Depth (N(B) 6/22/2018 6122/2018 2.25 PROD1 PLUG CIRC X Recip pipe from 6,250'MD - 6,155' 6,250.0 5,722.0 07:15 09:30 MD Circulating up to 650 GPM ICP - 193 PSI DPP. with FCP -1,058 PSI DPP. 32% F/O. Pumped 7800 STKS for initial. Spot 50 BBL of 12 PPG high vis pill @ 355 GPM 420 PSI @ 24% F/O. chase with 78 BBLs of LSND @ 355 GPM 542 PSI @ 23% F/O. PUH to 5,722' MD UP WT = 119K DWN WT= 88K. BD Top drive and RU cement manifold / hose. 6/22/2018 6/22/2018 1.50 PROD1 PLUG CIRC X Condition mud and circulate while 5,722.0 5,722.0 09:30 11:00 stage pumps up to 7 BPM ICP = 167 - FCP = 420 18% F/O. PJSM for cement program. 6/22/2018 6/22/2018 3.00 PROD1 PLUG CMNT X Begin 1st cement plug testing lines to 5,722.0 5,206.0 11:00 14:00 800 - 3000 PSI, Pump 26 BBLS 12.5 PPG mud push @ 3 BPM ICP = 150 PSI DPP, FCP = 50 PSI DPP. core bag and batch up cement. Open bag and pump 50 BBLS of 15.8 Class G cement @ 3.5 BPM ICP = 50 PSI DPP, FCP = 102 PSI DPP. Close bag and drop foam ball. / Open bag to pump 4 BBLS 12.5 PPG mud push, Swap to rig pumps and pump 58 BBLS LSND @ 7 BPM, ICP = 60 PSI DPP, FCP = 300 PSI DPP. catch up to vement after 400 stks away. reduce rate to 4 BPM 12% F/O. PUH on elevators at 1300 hm from 5,722' MD to 5,206' MD. UP WT = 111 K. Stage up pumps to 7 BPM With ICP 196 PSI DPP, FCP - 420 PSI DPP. 18% F/O. pump 3400 stks. 6/2212018 6/22/2018 2.25 PROD1 PLUG CMNT X Begin 2nd cement plug pumping 26 5,206.0 4,610.0 14:00 16:15 BBLs 12.5 PPG mud push II. @ 3 BPM with ICP 222 PSI DPP, FCP - 50 PSI DPP. 10% F/O. Close bag and batch up cement. Open bag pump 50 BBLS of 15.8 PPG Class G cement. with ICP 50 PSI DPP. FCP 120 PSI DPP. 14% F/O. Close bag drop foam ball, Open bag and pump 4 BBLS 12.5 PPG. Mud push ii Swap to rig pumps. pump 51 BBLS of LSND @ 7 BPM. ICP = 153 PSI. catch cement @ 260 stks. Reduce rate to 4 BPM FCP = 374 15% F/O. PUH on elevators from 5206'-4,610'MD. UPWT=104K. Circulate staging pumps up to 650 GPM @ ICP 1,230 PSI FCP - 600 PSI DPP. 31 % F/O, Reduce rate due to contaminated mud returning to surface at 350 GPM. 352 PSI DPP. 22% F/O, 3,575 STKS pumped. 6/22/2018 6/22/2018 2.25 PRODt PLUG CIRC X Spot 45 BBL 12 PPG hi vis pill at 350 4,610.0 4,132.0 16:15 18:30 GPM 382 PSI DPP. 22% F/O. Chase pill with 56.8 LSND mud at 350 GPM 380 PSI DPP 22% F/O. POUH on elevators from 4,610' MD - 4,132' MD. UP WT = 99K, DWN WT = 80K. Condition mud and circulate pumping 441 GPM 565 PSI DPP, 27% F/O, Reduce rate due to contaminated mud returns to 350 GPM 350 PSI DPP, 23% F/O. 5,580 STKS pumped. Page 7135 Report Printed: 8/1 012 01 8 . uperations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Thee Ertl Tore Dur (hr) Phase OpCone Activity Cade Time P -T -X Operahan Start Depth (WB) End Depth(fil®) 6/22/2018 6/22/2018 2.25 PRODt PLUG CMNT X Begin 3rd cement isolation plug pump 4,132.0 3,400.0 18:30 20:45 25 BBLS 12.5 PPG Mud push ii. 4 BPM @ 220 PSI, 12% F/0, close bag. Batch up cement. CEMENT WET 1852 HRS. Pump 70.3 BBLS 15.8 PPG class G cement at 4 BPM, 390 PSI DPP. Close bag drop foam ball, Open bag and pump 5 BBLS of 12.5 PPG Mud push II then swap to rig pumps pumping 33 BBLS of 9.3 PPG LSND @ 7 BPM, catch cement at 180 STKS ICP = 300 PSI DPP FCP = 750 PSI. PUH from 4,132' MD - 3,400' MD monitor disp via pit #5, UP WT = 85K. DWN WT=80K. Break over weight at 119K. 6/22/2018 6/22/2018 1.25 PROD? PLUG CIRC X Circulate @ 3,400' MD at 450 GPM 3,400.0 3,400.0 20:45 22:00 560 PSI 27% F/O. Total stks 6,600. UP WT=84K. DWN WT=79K. 6/22/2018 6/22/2018 0.25 PROD1 PLUG OWFF X BD top drive and OWFF. 3,400.0 3,400.0 22:00 22:15 6/22/2018 6/22/2018 1.25 PROW PLUG TRIP X POOH from 3,400'to 1,190' MD 1,190.0 1,190.0 22:15 23:30 standing back DP. Monitor disp via pit 5 6/22/2018 6/23/2018 0.50 PROD1 PLUG TRIP X Stand back 3 1/2" L-80 tubing from 1,190.0 722.0 23:30 00:00 1,190'MD-722'MD. Monitordisp viat Pit 5. 6/23/2018 6/23/2018 0.75 PROD? PLUG TRIP X Continue to POOH with 3.5" 9.3# L-80 722.0 0.0 00:00 00:45 cement string standing back in derrick from 722' MD - surface. 6/23/2018 6/23/2018 0.75 PROD1 PLUG W W WH X MU Army Wacker tool and wash 0.0 275.0 00:45 01:30 BOP's. 21 BPM then RIH three stands. 6/23/2016 6/23/2018 17.50 PROD1 PLUG WOC X Wait on cement to cure. SIMOPs 275.0 0.0 01:30 19:00 NOVO's troubleshooting / training. 6/23/2018 6/23/2018 2.50 PROD1 PLUG TRIP X MU 3/5" cement muleshoe and RIH 0.0 3,282.0 19:00 21:30 with 3 1/2" 9.3# L-80 cement string. Monitor displacement via pit #1. 6/23/2016 6/23/2018 0.50 PROD1 PLUG CIRC X Circulate bottoms up stage pumps to 3,282.0 3,282.0 21:30 22:00 450 GPM @ 480 PSI DPP. 27% F/0, UP WT = 83K, DWN WT 77K, MW in - 9.1 MW Out =9.3 VERY CLOBBERISH! 6/23/2018 6/23/2018 0.75 PRODi PLUG WASH X Wash down from 3,282' MD at 2 BPM 3,282.0 3,402.0 22:00 22:45 110 PSI DPP. 7% F/0, tag TOC at 3,402' MD. rotate string 180 Deg and confirm tag at 3,402' MD with 7-81K dwn wt. 6/23/2018 6/23/2018 0.25 PROD1 PLUG TRIP X POOH from 3,402' MD - 2,806' MD UP 3,402.0 2,806.0 22:45 23:00 WT=75K. DWN WT=73K. 6/23/2018 6/23/2018 0.50 PRODi PLUG CIRC X Spot 50 BBLS hi vis 13.5 PPG pill and 2,806.0 2,806.0 23:00 23:30 chase with 315 silks LSND. 6/23/2018 6/24/2018 0.50 PROD1 PLUG TRIP X POOH from 2,806 MD - 2,334' MD UP 2,806.0 2,334.0 23:30 00:00 WT=68K. DWN WT=67K. 6/24/2018 6/24/2018 0.25 PR0D1 PLUG TRIP X Continue to PUH to 2,267' MD. 2,334.0 2,267.0 00:00 00:15 6/24/2018 6/24/2018 1.00 PROD1 PLUG RURD X Blow down top drive and rig up 2,267.0 2,267.0 00:15 01:15 cement equipment. Blow down cement line and hold PJSM for cement program. Page 8135 Report Printed: 8110/2018 Operations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log 518f(Tme End Time our (hr) Phase Op Cotle AmuHy Cotle Time P -T -X Operation SIaft Depth (RKB) End Depth(ftKB) 6/24/2018 6/24/2018 1.25 PROD1 PLUG CMNT X Pump kick off plug. Pressure lest all 2,267.0 2,267.0 01:15 02:30 lines to 3,500 PSI. Pump 25 BBLs of 12.5# at 3.3 BPM 90 PSI DPP, close bag and batch up cement. pump 50 BBLS of 17# class G cement @ 3.3 BPM 70 PSI, Close bag and drop foam wiper ball. Open bag and pump 4 BBLS 12.5# Mud push Il, chase with 1 BBL sfresh water to clear surface lines. Swap to dg pumps and displace with 13 BBLs @ 4 BPM 215 PSI. Catch cement at 8 BBLS into displacement. Cement wet at 0138 hrs. Cement in plae 0228 hrs. 6/24/2018 6/24/2018 0.75 PROD1 PLUG TRIP X POOH from 2,267' MD to 1,661' MD 2,267.0 1,661.0 02:30 03:15 Monitor displacement via Pit 1 UP WT = 58K, DWN WT= 60K. 6/24/2018 6/24/2018 0.75 PROD1 PLUG CIRC X Circulate three bottoms up while recip 1,661.0 1,661.0 03:15 04:00 from 1,661' MD- 1,600' MD. Monitor returns via pit #1. UP WT = 58K, DWN WT = 60K. 450 GPM @ 210 PSI DPP, 26% F/O, total slks pumped = 3100. MW in = 9.1+ MW out = 9.2 PPG. 6/24/2018 6/24/2018 3.50 PROD1 PLUG PULD X BD top drive monitor well (static) and 1,661.0 0.0 04:00 07:30 POOH from 1,661' MD to surface. Monitor disp via Pit #1. LD all 3.5" L- 80 tubing down sideways from 1,193' MD to surface and kick out. 6/24/2018 6/24/2018 1.50 PROD? PLUG RURD X Rig down GBR and release. clean dg 0.0 0.0 07:30 09:00 1 floor. 6/2412018 6125/2018 15.00 PROD1 PLUG WOC X Wait on cement to cure. Crews 0.0 0.0 09:00 00:00 performing maintenance / cleaning / paint / training. 6/25/2018 6/25/2018 7.00 PROD1 PLUG WOC X Continue to WOC. Sim ops rig 0.0 0.0 00:00 07:00 1 maintenance. 6/25/2018 6/25/2018 0.25 PROD1 PLUG SFTY X PJSM 0.0 0.0 07:00 07:15 6/25/2018 6/25/2018 1.25 PROD1 PLUG BHAH X MU Drilling BHA#3 as per SLB rep. to 0.0 379.0 07:15 08:30 379' MD. Monitor disp via pit#1. 6/25/2018 6/25/2018 1.00 PRODi PLUG TRIP X Continue to RIH from 379' MD to 379.0 1,625.0 08:30 09:30 1,625' MD running 4 1/2" DP out of derrick. UP WT=81 K. DWN WT= 84K. Monitor disp via pit #1. 6/25/2018 6/25/2018 0.25 PROD1 PLUG DHEQ X Shallow hole test @ 525 GPM, 785 1,625.0 1,625.0 09:30 09:45 1 PSI SPP. 29% F/O test good. 6/25/2018 6/25/2018 1.25 PROW PLUG CIRC X Condition mud and circulate @ 650 1,625.0 1,625.0 09:45 11:00 GPM, 1,025 PSI DPP @ 30% NO, Total stks 10,075. 6/25/2018 6/25/2018 0.50 PROD1 PLUG WASH X Wash down from 1,625' MD to 1,772' 1,625.0 1,772.0 11:00 11:30 MD TOC. Set 5K DWN. UP WT = 81 K, DWN WT=84K, ROT -81 K. 6/25/2018 6/25/2018 0.50 PROD1 PLUG DRLG X Drill cement from 1,772' MD -1,817' 1,772.0 1,817.0 11:30 12:00 MD with 520 GPM @ 750 PSI DPP. 31% F/O, 60 RPM, 2-41K TQ, 4K WOB. Off BTM Press 743 PSI, ECD 10. 18, UP WT=81 K, DWN WT= 84K, rotation WT = 84K. 6/25/2018 6/25/2018 2.00 PRODt PLUG DRLG X Drill cement form 1,817 MD - 1,900' 1,817.0 1,900.0 12:00 14:00 MD W 520 GPM @ 750 PSI DPP. 31% F/0, 60 RPM, 2-4K TQ, 4K WOB. Off BTM = 743, ECD = 10, 18, UP WT = 81 K, DWN WT = 84K, ROT WT = 84K Page 9/35 Report Printed: 8110/2018 operations Summary (with Timelog Depths) IH -108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(hr) (n) Phew O Cotle p Activi Cotle tY Time P -T- X Operztlon Start Depth (N(B) End Depth (#KB) 6/25/2018 6/25/2018 4.00 PROD2 DRILL DDRL X DDRL from 1,900'MD-2,181'MD 1,900.0 2,181.0 14:00 18:00 2,060 TVD, 550 GPM @ 38% F/O, 100 RPM 3K TO, 4K WOB, ECD = 10.07 Off Btm = 670 PSI, UP WT = 90K, DWN WT= 84K, ROT -87K, Max Gas = 5 units, ADT - 1.98, Bit Hrs - 1.98, Jar hrs - 65.99 SPR's @ 2,000' MD 1,911' TVD MW = 9. PPG Time 1545 hr MPI) 30 SPM 80 PSI 40 SPM 110 PSI MP2) 30 SPM 80 PSI 40 SPM 110 PSI 6/25/2018 6/26/2018 6.00 PROD2 DRILL DDRL X DDRL from 2,181'MD 2,060 TVD- 2,181.0 3,159.0 18:00 00:00 3,159' MD 2,586' TVD, 650 GPM @ 29% F/O, 140 RPM 41K TO, 5K WOB, ECD = 10.25 Off Btm = 1,020 PSI, UP WT=99K, DWN WT= 85K, ROT - 89K, Max Gas = 170 units, ADT - 3.37, Bit Hrs - 5.35, Jar hrs - 69.36 SPR's @ 2,298' MD 2,148' TVD MW = 9.2 PPG Time 1835 hr MPI) 30 SPM 80 PSI 40 SPM 120 PSI MP2) 30 SPM 80 PSI 40 SPM 120 PSI 6/26/2018 6/26/2018 6.00 PROD2 DRILL DDRL X DDRL from 3,159'MD 2,586'TVD- 3,159.0 4,153.0 00:00 06:00 4,153' MD 2,821' TVD, 650 GPM @ 1,180 PSI DPP 29% F/0, 140 RPM 6K TO, 13K WOB, ECD = 10.61 Off Btm = 1,170 PSI, UP WT= 108K, DWN WT = 78K, ROT- 89K, 4K TO Max Gas = 20 units, ADT - 3.26, Bit Hrs - 8.61, Jar hrs - 72.62 6/26/2018 6/26/2018 6.00 PROD2 DRILL DDRL X DDRL from 4,153' MD 2,821' TVD - 4,153.0 5,022.0 06:00 12:00 5,022' MD 3,099' TVD, 650 GPM @ 1,180 PSI DPP 29% F/0, 140 RPM 6K TO, 8K WOB, ECD = 10.61 Off Btm = 1,170 PSI, UP WT = 108K, DWN WT= 78K, ROT -89K, 4K TO Max Gas = 20 units, ADT - 3.48, Bit Hrs - 12.09, Jar hrs - 76.10 SPR's @ 4,198' MD 2,831' TVD MW = 9.2 PPG Time 0620 hr MPI) 30 SPM 160 PSI 40 SPM 200 PSI MP2) 30 SPM 160 PSI 40 SPM 190 PSI 6/26/2018 6/26/2018 6.00 PROD2 DRILL DDRL X DDRL from 5,022' MD 3,099' TVD 5,022.0 5,725.0 12:00 18:00 5,725' MD 3,362' TVD, 650 GPM @ 1,450 PSI DPP 29% NO, 140 RPM 7K TO, 10K WOB, ECD = 10.04 Off Btm = 1,400 PSI, UP WT = 122K, DWN WT= 83K, ROT -99K, 8K TO Max Gas = 112 units, ADT - 3.89, Bit Hrs - 15.98, Jar hrs - 79.99 Page 10135 Report Printed: 8/10/2018 Uperations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Tons Dw(hr) Phase DD Code Activity Code Time P -T -X Operation Start (nxI3a) End Depth 0) 6/26/2018 6/27/2018 6.00 PROD2 DRILL DDRL X DDRL from 5,725' MD 3,362' TVD - 5,725.0 6,550.0.0 18:00 0000 6,550' MD, 650 GPM @ 1,565 PSI DPP 27% F/O, 150 RPM 9K TO, 20K WOB, ECD = 10.69 Off Btm = 1,560 PSI, UP WT = 136K, DWN WT = 90K, ROT- 106K, 7K TO Max Gas = 70 units, ADT - 3.45, Bit Hrs - 19.43, Jar hrs - 83.44 SPR's @ 5,726' MD 3,362" TVD MW = 9.2 PPG Time 1800 hr MP1) 30 SPM 160 PSI 40 SPM 210 PSI MP2) 30 SPM 170 PSI 40 SPM 210 PSI 6/27/2018 6/27/2018 6.00 PROD2 DRILL DDRL X DDRL from 6,550' MD 3,701' TVD - 6,550.0 7,439.0 00:00 06:00 7,493 MD 4,033' TVD, 650 GPM @ 1,790 PSI DPP 29% F/O, 140 RPM 9.51K TO, 15K WOB, ECD = 10.92 Off Btm = 1,780 PSI, UP WT = 148K, DWN WT = 88K, ROT- 111 K, 7K TO Max Gas = 180 units, ADT - 3.69, Bit Hrs - 23.12, Jar his - 87.13 Drilled 350' w/NOVO's 6/27/2018 6/27/2018 6.00 PROD2 DRILL DDRL X DDRL from 7,493 MD 4,033' TVD - 7,439.0 8,076.0 06:00 12:00 6,076' MD 4,066' TVD, 650 GPM @ 1,678 PSI DPP 30% F/O, 100 - 150 RPM 9.5K TO, 12-16K WOB, ECD = 10.87 Off Btm = 1,649 PSI, UP WT = 143K, DWN WT = 79K, ROT- 105K, 9K TO Max Gas = 317 units, ADT - 4.15, Bit Hrs - 27.27, Jar hrs - 91.28 Drilled 350' w/NOVO's SPR's @ 7,435' MD 4,051 " TVD MW = 9.2+ PPG Time 0600 hr MP1) 30 SPM 240 PSI 40 SPM 280 PSI MP2) 30 SPM 240 PSI 40 SPM 280 PSI 6/27/2018 6/27/2018 6.00 PROD2 DRILL DDRL X DDRL from 8,076' MD 4,066' TVD - 6,076.0 8,741.0 12:00 18:00 8,741' MD 3,948' TVD, 650 GPM @ 2,000 PSI DPP 29% F/O, 150 RPM 11 K TO, 12K WOB, ECD = 10.81 Off Btm = 1,995 PSI, UP WT = 138K, DWN WT = 73K, ROT- 101 K, 8K TO Max Gas = 236 units, ADT - 3.96, Bit Hrs - 31.23, Jar hrs - 95.24 6/27/2018 6/27/2018 4.00 PROD2 DRILL DDRL X DDRLfrom 8,741' MD 3,948' TVD - 8,741.0 9,245.0 18:00 22:00 9,245' MD 3,787' TVD, 650 GPM @ 2,135 PSI DPP 28% F/O, 150 RPM 12K TO, 13K WOB, ECD = 11.12 Off Btm = 2,130 PSI, UP WT = 132K, DWN WT = 60K, ROT- 95K, 9K TO Max Gas = 220 units, ADT - 2.76, Bit Hrs - 33.99, Jar hrs - 98 Page 11/35 Report Printed: 8/10/2018 Operations Summary (with Timelog Depths) 11-1-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Stat Time End Tama Our (hr) Phase op co �ty cads Time P-T-X dperaum (ftKB) End Deptlr(ftKB) 6/27/2018 6/27/2018 1.00 PROD2 CASING CIRC X Cycle pipe from 9,146' MD to 9,245' 9,245.0 9,146.0 22:00 23:00 MD while circulating bottoms up @ 650 GPM, 28% F/0, 12 RPM, 81K TQ, 10.8 ECD. UP WT=127, DNW WT= 65K, ROT 96K. 6/27/2018 6/27/2018 0.50 PROD2 CASING OWFF X OWFF (Static) 9,146.0 9,146.0 23:00 23:30 6/27/2018 6/28/2018 0.50 PROD2 CASING BKRM X BKRM OOH from 9,146' MD - 9,016 9,146.0 9,016.0 23:30 00:00 UP WT = 90K, 645 GPM @ 2,053 PSI DPP, ECD - 10.79 gas 27 units. 6/2812018 6/28/2018 3.00 PROD2 CASING BKRM X Continue to BKRM OOH from 9,016' 9,016.0 7,822.0 00:00 03:00 MD - 7,822' MD. UP WT = 140K, OWN WT = 82K. 650 GPM @ 1,875 PSI DPP. 140 RPM with 8K TO. ECD = 10.64 6/28/2018 6/28/2018 1.50 PROD2 CASING CIRC X Circulate bottoms up with a high vis 7,822.0 7,628.0 03:00 04:30 sweep. 7,822'MD-7,628'MD. UP WT=143K, DWN WT=83K. pumped 11,500 STKS, with a MWI 9.2 MWO = 9.3 10.45 ECD, 650 GPM @ 28% F/0, 150 RPM with 8K TO, 6/28/2018 6/28/2018 0.50 PROD2 CASING TRIP X POOH on elevators from 7,628' MD - 7,628.0 7,477.0 04:30 05:00 7,477' MD. Swabbing and 25K overpull. go back to BKRM 6/28/2018 6/28/2018 7.00 PROD2 CASING BKRM X BKRM OOH from 7,477' MD - 4,777' 7,477.0 4,777.0 05:00 12:00 MD. 650 GPM @ 1,526 PSI DPP. 28% NO, 140 RPM, 5K TO, ECD = 10.62 UP WT = 91 K w/pump, DWN WT=81K. 6/28/2018 6/28/2018 8.75 PROD2 CASING BKRM X BKRM OOH from 4,777' MD - 1,736' 4,777.0 1,736.0 12:00 20:45 MD. Rate of BKRM = 750 FT/HR - 500 FT/HR. 650 GPM @ 1,525 - 1,030 PSI DPP. F/O 28%. 140-100 RPM. UP WT 83-88K, DWN WT= 84K. Slow down for coal areas 3,541' - 3,066'13,066 - 2400'. Recip pipe while pumping high vis sweep at shoe. 6/28/2018 6/28/2018 0.50 PROD2 CASING OWFF X OWFF (dropped 2"). Service TO situ 1,736.0 1,736.0 20:45 21:15 op. 6/28/2018 6/28/2018 0.50 PROD2 CASING CIRC X Pump slug to surface then BD lop 1,736.0 1,736.0 21:15 21:45 Drive. 6/28/2018 6/2812018 1.00 PROD2 CASING TRIP X POOH from 1,736' MD - 379' MD. 1,736.0 379.0 21:45 22:45 Monitor disp via TT. 6/28/2018 6/28/2018 0.25 PROD2 CASING OWFF X OWFF. Dropped V. 379.0 379.0 22:45 23:00 6/2812018 6/29/2018 1.00 PROD2 CASING BHAH X LD BHA frin 379'- 94' MD as per DD. 379.0 94.0 23:00 00:00 Monitor well via TT. 6/29/2018 6/29/2018 1.25 PROD1 CASING BHAH X Continue to lay down BHA from 94' As 94.0 0.0 00:00 01:15 per SLB. Monitor disp via TT. Clear and clean rig floor., 6129/2018 6/29/2018 0.75 PROD1 PLUG RURD X RU to run 3 112" cement string. Bring 0.0 0.0 01:15 02:00 GBR to rig floor. Spot equip. PJSM 6/29/2018 6/29/2018 2.00 PROD2 PLUG PULD X MU 3 1/2" Cement string BHA of 3 0.0 1,225.0 02:00 04:00 1/2" 9.3# EUE from surface to 1,225' MD 6/29/2018 6/29/2018 3.25 PROD2 PLUG TRIP X RIH with 4 1/2" OP from 1,225' MD - 1,225.0 8,000.0 04:00 07:15 8,000' MD. Monitor disp via TT. UP WT = 129K, DWN WT = 83K. 6/29/2018 1.50 PROD2 PLUG CIRC X Cir bottoms up while recip from 7,925' 8,000.0 8,000.0 07:15 08:45 MD - 8,000' MD. 308 GPM @ 430 16/29/2018 PSI DPP. 20% F/0, Pump 5,427 STKS. Page 12136 Report Printed: 811012018 Operations Summary (with Timelog Depths) IH -108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Star) Depth Start Time I EM Tme Du(hr) Phase OD Code Aodvlty Code Time P -T -X Operetlon (flKB) End Depth(ftKB) 6/29/2018 6129/2018 0.50 PROD2 PLUG CIRC X Spot 48 BBL pill of 12# Hi vs spacer 8,000.0 8,000.0 08:45 09:15 and chase with 102.5 BELS 6/29/2018 6/29/2018 0.50 PROD2 PLUG TRIP X PUH from 8,000' MD - 7,497' MD. 8,000.0 7,497.0 09:15 09:45 Monitor disp via pit #1. 6/29/2018 6/29/2018 0.75 PROD2 PLUG CIRC X RU cement manifold and circ 284 7,497.0 7,497.0 09:45 10:30 GPm @ 450 PSI DPP. 18% F/O, PJSM for cement job with SLB/MI/DDI. 6/29/2018 6/29/2018 1.50 PROD2 PLUG CMNT X Pump 1st stage of cement plug 7,497.0 7,497.0 10:30 12:00 program @ 7,497' MD. Flood all lines and PT to 3,500 PSI. Close bag and lake all returns thin choke. Pump 27 BBLS 12.5# MP2 @ 4.2 BPM 100 PSI. Batch and pump 48.3 BBLS 15.8# cement at 4.5 BPM, 100 PSI. drop wiper ball and pump 3 BBLS of MP2. Swap to rig for displacement with 82.7 BBLS LSND. Pump 4 BPM @ 220 PSI, @ 772 stirs reduce rate to 2 BPM, 197 PSI. Cement wet at 1112 HRS> 6/29/2018 6/29/2018 0.75 PROD2 PLUG TRIP X PUH from 7,497' MD - 7,000' MD. 7,497.0 7,000.0 12:00 12:45 1,506 FPH pulling speed. Monitor disp via Pit #1. UP WT = 129K, DWN WT = 79K. 6/29/2018 6/29/2018 1.00 PROD2 PLUG CIRC X Circulate bottoms up while recip from 7,000.0 7,000.0 12:45 13:45 6,930' MD - 7,000' MD. Stage up pumps to 650 GPM @ 1,380 PSI. 29% F/O. 6/29/2018 6/29/2018 0.50 PROD2 PLUG CIRC X Spot 40 BBL pill of 12# Hi Ys spacer 7,000.0 7,000.0 13:45 14:15 and chase with 89.8 BBLS 1 -SND. 892 STKS @ 239 GPM 300 PSI, 13% F/O. 6/29/2018 6/29/2018 0.75 PROD2 PLUG TRIP X PUH from 7,000' MD to 6,580' MD. 7,000.0 6,580.0 14:15 15:00 MU 10' PUP jt. UP WT= 129K, DWN W T= 81 K. Monitor disp via Pit #1. 6/29/2018 6/29/2018 0.50 PROD2 PLUG CIRC X From 6,585' circulate bottoms up at 6,580.0 6,580.0 15:00 15:30 630 GPM. 1,290 PSI at 32% F/O. total stks 4,071. 6/29/2018 6/29/2018 1.25 PROD2 PLUG CMNT X PJSM . RU cement hose and 6,580.0 6,580.0 15:30 16:45 manifold, Close arm, open choke and pump cement plug #2. 27 BBPS 12.5# MPII @ 4.2 BPM 50-156 PSI DPP. Close choke and batch up cement. With super choke 1/2 open pump 59.5 BBLS of 15.8# class G cement. 4.7 - 4.2 BPM @ 84-111 PSI DPP. Close super choke to drop wiper ball. Pump 3 BBLS MPII spacer and 1 BBL waterswap to dg pumps and displace at 5 BPM, 220-250 PSI DPP. 4 BPM at 642 stks.340 PSI DPP. 2 BPM from 691 STKS at 232 FCP. 6/29/2018 6/29/2018 0.75 PROD2 PLUG TRIP X PUH to 5,972' MD UP WT = 118K. 6,580.0 5,972.0 16:45 17:30 DWN WT = 83K. Monitor disp via Pit #1. 6/29/2018 6/29/2018 1.25 PROD2 PLUG CIRC X Circulate bottoms up while recip from 5,972.0 5,972.0 17:30 18:45 5,942' MD - 5,972' MD. at 626 GPM 1,400 PSI DPP. 32% F/0. Reduce rate at 2,700 stks due to interface overflowing drag chain system. Increase rate to 633 GPM at 5,400 stks 1,380 PSI. 32% F/O. 7,379 total stks pumped. Page 13135 Report Printed: 8/10/2018 Operations Summary (with Timelog Depths) 1H-108 • Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth start Time EM Tme our (hr) Phase OP Code AXb ty Code Tere P -T -X Operation (IIKB) End Depth(BKB) 6/29/2018 6/29/2018 1.50 PROD2 PLUG CMNT X Pump cement plug —#3 at 5,972' MD. 5,972.0 5,972.0 18:45 20:15 MU cement hose assym and close ann taking returns through super choke and closing chokes with pumps off. Pump 27 BBLS 12.5# MPIL at 4 BPM 850 ICP, 340 FCP, Mix and pump 48.3 BBLS of 15.8#. cmt at 4 BPM. 78 -230 PSI. Stop wiper ball at 160 stks. 4 BPM from 420 stks 500 PSI. reduce to 3 BPM 518 PSI FCP. 617 total stks pumped. 6/29/2018 6/29/2018 0.75 PROD2 PLUG TRIP X PUH from 5,972' MD to 5,470' MD. 5,972.0 5,470.0 20:15 21:00 UP WT=114K, OWN WT=78K. j Swabbing occuring so slow down to 15 FPM. 6/29/2018 6/29/2018 2.75 PROD2 PLUG CIRC X Circulate while recip from 5,440' MD - 5,470.0 5,470.0 21:00 23:45 5,470' MD. stage pumps to 630 GPM @ 1,320 PSI DPP. 34% F/O, total stks pumped 16,690. UP WT = 107. OWN WT= 76K. 6/29/2018 6/30/2018 0.25 PROD2 PLUG CIRC X 5,3467' MD spotting 45 BBLS spacer 5,470.0 5,470.0 23:45 00:00 pill and chase with 682 STKS at 5 BPM 328 PSI DPP. 15% F/O. 6/30/2018 6/30/2018 0.75 PROD1 PLUG TRIP X PUH and space out with 15' PUP to 5,470.0 5,007.0 00:00 00:45 gel on depth at 5,007' MD. UP WT = 107K Monitor disp via pit #1. 6/30/2018 6/30/2018 0.50 PROD1 PLUG RURD X Flush choke manifold from previous 5,007.0 5,007.0 00:45 01:15 cement plugs. Rig up cement manifold to DP. 6/30/2018 6/30/2018 1.00 PROD2 PLUG CMNT X Pump Cement plug #4 ofAS1. Pump 5,007.0 5,007.0 01:15 02:15 27 BBLS of 12.7 PPG mud pushll @ 3.7 BPM 170 PSI DPP. Close bag, batch up cement system. Open Annular and pump 67.7 BBLS of 15.7# ASI cement at 4.3 BPM 90 PSI DPP. Close bag and drop wiper ball. Pump 3 BBLS Mud pushll and one barrel fresh water. Displace cement with rig pumps of LSND at 4 BPM with last 5 BBLS being pumped at 2 BPM. 470 PSI DPP. Was able to catch cement 21 BBLS into displacement. Cement wet at 0213 hrs. 6/30/2018 6/30/2018 1.00 PROD2 PLUG TRIP X PUH from 5,007' MD - 3,980' MD. 5,007.0 3,980.0 02:15 03:15 starting at 15 FPM then changed to 30 FPM. Monitor disp via Pit#1. UP WT = 94K, DW N WT = 74K.. 28K OP to move pipe. 6/30/2018 6/30/2018 5.75 PROD2 PLUG WOC X 630 GPM @ ICP of 1,120 PSI DPP 3,980.0 3,980.0 03:15 09:00 FCP 965 PSI DPP. 34% F/0. 6/30/2018 6/30/2018 1.00 PROD2 PLUG WASH X Wash down from 3,980' MD - 4,298' 3,980.0 4,280.0 09:00 10:00 MD @ 2 BPM 145 PSI DPP. 7% F/0, UP WT=94K, OWN WT=78K. Wash thru set down at 4,272' MD - 4,280' MD. 6/30/2018 6/30/2018 1.75 PR0D2 PLUG WASH X Wash down and circulate with 4,280.0 4,513.0 10:00 11:45 reciprocations from 4,280' MD - 4,513' MD @ 2 BPM with ICP of 145 PSI, FCP of 210 PSI. 9% F/O, UP WT = 96K, DWN WT=78K. 6/30/2018 6/30/2018 2.00 PROD2 PLUG CIRC X CBU while recip from 4,513' 4,456' 4,513.0 4,513.0 11:45 13:45 MD treating fluids due to clobbering. Stage up to 660 GPM 1,285 PSI, 33% F/0, 8,830 STKS @ full rate. Page 14/35 ReportPrinted: 8110/2018 uperations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Tare Dur(hn Phese Op Code Actielty Cade Time P-T-X Operation (ftKB) End Depth(ftKB) 6/30/2018 6/30/2018 0.75 PROD2 PLUG WASH X Continue to wash down to tag depth of 4,513.0 4,714.0 13:45 14:30 4,714' MD. Tagged three times and witnessed by Jeff Jones with AOGCC. UP WT = 96K, DWN WT= 78K. Tagged with 2 BPM and 1 OK DWN WT. 6/3012018 6/30/2018 1.25 PROD2 PLUG CIRC X CBU while recip from 4,714' MD - 4,714.0 4,714.0 14:30 15:45 4,641' MD Staging pumps up to 630 GPM @ ICP 1,380 PSI DPP, FCP = 1,080 PSI. 5,964STKS. 6/30/2018 6/30/2018 1.50 PROD2 PLUG TRIP X POOH from 4,714' MD - 2,784' MD. 4,714.0 2,784.0 15:45 1715 Monitor disp via Pit#1. UP WT = 100K, DWN WT=80K. 6/30/2018 6/30/2018 0.25 PROD2 PLUG CIRC X Pump 48.35 BBL spacer pill Hi-Vis 2,784.0 2,784.0 17:15 17:30 monitoring disp via Pit 1. chase with 218 stks. 6/3012018 6/30/2018 0.50 PROD2 PLUG TRIP X PUH from 2,784' MD - 2,282' MD 2,784.0 2,282.0 17:30 18:00 monitoring disp via Pit 1, UP WT = 72K, DWN WT = 71 K, 6/30/2018 6/30/2018 0.75 PROD2 PLUG CIRC X Circulate while recip from 2,282' MD - 2,282.0 2,282.0 18:00 18:45 2,189' MD, 630 GPM @ 820 PSI DPP. 32% F/O. UP WT = 69K. DWN WT = 71K. Total strokes pump= 3,900. 6/30/2018 6/3012018 1.25 PROD2 PLUG CMNT X RU cement head and pump KO plug. 2,282.0 2,282.0 18:45 20:00 PUmp 27 BBLS of 12.5# MP @ 4.8 BPM54 PSI DPP> close bag and batch cement. Open bag and pup 51 BBLS of ASI 15.7# cement at 4.6 BPM 100-421 PSI DPP. close bag and drop ball. Pump 3 BBLS Mud Push II and 1 BBLS fresh water behind ball then wrap to dg pumps for displacement of 11.47 BBLS LSND at 4 BPM, 35 PSI with last 5 BBLS at 2 BPM 42 PSI. Cement wet at 1920 hrs. CIP @ 1946 hrs. 6/30/2018 6/30/2018 1.00 PROD2 PLUG TRIP X PUH from 2,282' MD - 1,684' MD. 15 2,282.0 1,684.0 20:00 21:00 FPM@ 62K UP WT, 59K DWN WT. Monitor disp via TT. 6/30/2018 6/30/2018 0.50 PROD2 PLUG CIRC X Circulate while recip form 1,684' MD- 1,684.0 1,684.0 21:00 21:30 1,602'MD. UPWT=62K DNWWT= 59K. 630 GPM @ 760 PSI DPP FCP = 681 PSI DPP. 6/30/2018 6/30/2018 0.25 PROD2 PLUG OWFF X OWFF BD TD. 1,684.0 1,684.0 21:30 21:45 6/30/2018 6/30/2018 0.75 PROD2 PLUG PULD X POOH laying down 4 1/2" DP from 1,684.0 1,225.0 21:45 2230 1,634' MD -1,225' MD. Monitor disp via pit #1. 6/30/2018 6/30/2018 0.50 PROD2 PLUG RURD X RU GBR handling equipment for 3 1,225.0 1,225.0 22:30 23:00 1/2" 9.3# tubing. 6/30/2018 7/1/2018 1.00 PROD2 PLUG TRIP X POOH with 31/2" L-80 tubing 1,225.0 540.0 23:00 00:00 standing back in derrick. C/O seal rings on the fly. Monitor disp via Pit #1. 7/112018 7/1/2018 1.50 PROD2 PLUG TRIP X Continue to stand back in derrick 3 540.0 0.0 00:00 01:30 1/2" L-80 - 8 rnd EUE tubing while replacing seal rings. Monitor disp via Pit 1. Clear and clean rig floor. 7/1/2018 7/1/2018 0.75 PROD2 PLUG X MU Johnny wacker and wash 930 0.0 0.0 01:30 0215 GPM @ 160 PSI. wellhead/BOP'S jWWWH from post cement programs. Pull Wer busing and service. Page 15135 Report Printed: 8/1012018 Operations Summary (with Timelog Depths) IH -108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth staM1rme End rma Dar (hr) Phase Op code Acbvity Cale Time P -T -X operation (flke) End Depen (ftKa) 7/112018 7/1/2018 0.50 PROD2 PLUG BOPE X Install test plug / flood stack with fresh 0.0 0.0 02:15 02:45 water and test blind rams to 2501 3500 PSI. 5/5 charted (Passed) UII test plug / install wear bushing. 711/2018 7/1/2018 1.25 PROD2 PLUG SHAH X M/U BHA for cleanout using 9 7/8" 0.0 285.0 02:45 04:00 Generic rock bit. Monitor disp via Pit .1 7/1/2018 7/1/2018 0.75 PROD2 PLUG TRIP X TIH from 285' MD - 1,616' MD. 285.0 1,616.0 04:00 04:45 1 Monitor disp via Pit 1. 7/1/2018 7/1/2018 0.25 PROD2 PLUG CIRC X Circulate bottoms up at 630 GPM , 1,616.0 1,661.0 04:45 05:00 650 PSI DPP. 60 RPM with 2K TO. Recip pipe. 7/1/2018 7/1/2018 0.75 PROD2 PLUG WASH X Wash down from 1,661' MD to 1,661.0 1,750.9 05:00 05:45 1,750.89' MD at 2 BPM 105 PSI DPP, 7% F/0, tag cement at 1,750.89' MD. with 15K OWN WT. UP WT= 77K, DWN = 80K. 711/2018 7/112018 0.25 PROD2 PLUG DRLG X Drill cement from 1,750.89'MD- 1,750.9 1,765.0 05:45 06:00 1,765 MD. 800 GPM @ 875 PSI DPP. 34% F/0, 60 RPM with 21K TO. 1 K SOB. , 7/1/2018 711/2018 0.75 PROD2 PLUG CIRC X Circulate BU while rotating and recip 1,765.0 1,765.0 06:00 06:45 from 1,765' MD - 1,705' MD. 807 GPM @ 880 PSI DPP. 34% F/O, 60 RPM 1.51K TQ. 6,500 STKS pumped. UP WT=80K. DWN WT= -80K. 7/1/2018 7/112018 1.75 PROD2 PLUG PRTS X RU and perform a casing pressure 1,765.0 1,765.0 06:45 08:30 test against TOC. 1,500 PSI = 300 PSI bleed off over charted 30 min test. Bleed off and dg dwn test equip. 7/1/2018 7/1/2018 0.25 PROD2 PLUG DRLG XT Drill cement from 1,765' MD - 1,784' 1,765.0 1,784.0 08:30 08:45 MD at 802 GPM 850 PSI. 34% F/O, 60 RPM, 2K TO, 5K WOB. 7/1/2018 7/1/2018 0.75 PROD2 PLUG CIRC XT Circulate bottoms up while recip from 1,784.0 1,799.0 08:45 09:30 1,784' MD -1,799' MD. @ 802 GPM, 805 PSI DPP. 34% F/O, 60 RPM 1.51K TQ. 3535 total stks pumped. UP WT = 82K, DWN WT= 80K. Tag cement with 11K DWN WT. 7/1/2018 7/1/2018 2.50 PROD2 PLUG PRTS XT MU test equip and test / chart cmt plug 1,799.0 1,799.0 09:30 12:00 to 1,500 PSI. Pressure dropped on initial test from 1,500 PSI - 570 PSI. PUmped 1.8 BBLS to obtain 1500 PSI. Check all surface equip and - repeat test X 3 with pressure leveling off at 850 PSI, then droppping to 500 PSI after isolating casing. RD test equip B/D same. test witnessed by Jeff Jones with AOGCC. 7/1/2018 7/1/2018 4.25 PROD2 PLUG PULD X LJD std @16 from string in hole to 1,799.0 1,708.0 12:00 16:15 1,708' MD. Cont to LD stds from derrick via mousehole. LD total of 47 stds. Off bottom UP WT= 80K. DWN WT = 80K. 7/1/2018 7/1/2018 0.75 PROD2 PLUG TRIP XT POOH racking back DP in derrick. 1,708.0 285.0 16:15 17:00 Monitor disp via Pit 1. 7/1/2018 7/1/2018 0.25 PROD2 PLUG OWFF X OWFF/pre job LD BHA 285.0 285.0 17:00 17:15 7/1/2018 7/1/2018 2.25 PROD2 PLUG SHAH X LO BHA monitor disp via Pit 1. Clean 285.0 0.0 17:15 19:30 rig floor /jet flow line and clean floor pan. 7/1/2018 7/1/2018 0.50 PROD2 PLUG SVRG X Service top drive / Blocks / crown. 0.0 0.0 1930 20:00 Page 16135 Report Printed: 8/1012018 Uperations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start DepM Stan Time End Time Dur(hr) Phase op coda Activity Cafe Time P -T -X Operation (RKB) End Depth inks) 7/1/2018 7/1/2018 1.25 PROD2 PLUG TRIP X Make up Baker 10 314" N-1 cement 0.0 1,726.0 20:00 21:15 retainer and RIH to 1,726' MD. Monitor disp via Pit 1. UP WT = 73K. OWN WT=70K. 7/1/2018 7/1/2018 1.00 PROD2 PLUG CIRC X Fill pipe and RIG to tag TOC. Tag at 1,726.0 1,786.0 21:15 22:15 1,786' MD. Pick up V and circ 1.5 SIS # 6 BPM. 285 PSI 16% F/O, total stks pumped 2,350. UP WT=73K. OWN WT=71K. 7/1/2ol8 7/1/2018 1.00 PROD2 PLUG MPSP X Set cement retainer as per BOT REP. 1,786.0 1,782.0 22:15 23:15 Top of retainer at 1,782' MD. PU and RU to test retainer to 1,500 PSI for 30 MIN (PASSED). 7/1/2018 7/2/2018 0.75 PROD2 PLUG DISP X Displace well over to sea water at 10 1,782.0 1,782.0 23:15 00:00 BPM 240 PSI DPP 20% F/O, UP WT = 73K, OWN WT = 72K. 7/2/2018 7/212018 1.75 PROD2 PLUG PRTS X RU and test cement retainer with sea 1,782.0 1,782.0 00:00 01:45 water to 1,500 PSI charted 30 min. (PASSED) 7/2/2018 7/212018 0.50 PROD2 PLUG OWFF X OWFF and monitor same. BD top 1,782.0 1,782.0 01:45 02:15 drive / equip 7/2/2018 7/2/2018 1.50 PROD2 PLUG PULD X POOH laying down singles from 1,782' 1,782.0 0.0 02:15 03:45 MD Monitor disp via TT. 712/2018 7/2/2018 0.50 PROD2 PLUG W W WH X Make up Johnny Wacker and wash 0.0 0.0 03:45 04:15 WH / pull wear bushing. 7/2/2018 7/2/2018 0.75 PROD2 PLUG RURD X RU to RIH with 3 1/2" 8rnd EUE 9.3#. 0.0 0.0 04:15 05:00 for a kill string. 7/2/2018 7/2/2018 5.50 PROD2 PLUG PUTB X RIH with 9.3# L-80 8rnd EUE kill 0.0 1,783.9 05:00 10:30 string. from surface to tag of cement retainer at 1,783.9' MD. DOWN WT = 58.5K UP WT = 54K. Space out and pick up hanger. Damaged hanger when picking up. Replace with new from warehouse. 7/2/2018 7/2/2018 1.00 PROD2 PLUG THGR X Make up new hanger and landing jt. 1,783.9 1,781.9 10:30 11:30 Orient hanger profile and land. Top of retainer at 1,783.9' MD. Bottom of kill string at 1,781.89' with space out. Verify alignment via tubing port and RILDS. 7/2/2018 7/2/2018 0.50 PROD2 PLUG THGR X PT hanger seals to 5,000 PSI 1,781.9 1,781.9 11:30 12:00 witnessed,. LD landing joint and pu dry rod., 7/212018 7/2/2018 1.00 PROD2 WHDBOP MPSP X Install BPV and lest from beloow with 1,781.9 0.0 12:00 13:00 sea water to 1,500 PSI. charted for 10 min (PASSED). BD / RD. 7/2/2018 7/2/2018 3.00 PROD2 WHDBOP NUND X Pull riser and mousehole. ND ROPE 0.0 0.0 13:00 16:00 Secure same. 7/2/2018 7/212018 1.25 PROD2 WHDBOP NUND X Clean well head pick and set tree. NU 0.0 0.0 16:00 17:15 istall test dart. 7/2/2018 7/2/2018 1.25 PROD2 WHDBOP PRTS X TEst Bonnet seals to 5,000 PSI 0.0 0.0 17:15 18:30 witnessed. Fill tree with diesel with 5 gal buckets and test to 250 / 5000 PSI (Charted). PASSED 7/2/2018 7/2/2018 0.50 PROD2 WHDBOP MPSP X Drain tree and pull test dart ?BPV. 0.0 0.0 18:30 19:00 7/2/2018 7/2/2018 2.25 PROD2 WHDBOP FRZP X RU LRS and tiger tank lest return line 0.0 0.0 19:00 21:15 then pump lines. Freeze protect IA TBG with 180 BBLS deisel at 4 BPM, ICP 350 PSI, FCP 350 PSI. Diesel returns to surface @ 165 BBLS away. . BD RD. Page 17136 Report Printed: 811012018 Operations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sear) Depth Star) Time EM rime Our (hr) Phase Op Cade Activity Code Time P -T -X Operabon (BKB) End Depth (RKB) 7/2/2018 7/2/2018 1.25 PROD2 WHDBOP MPSP X RU lubricator and set BPV / test to 0.0 0.0 21:15 22:30 1,500 PSI, Good. LD lubricator via Beaver slide. 7/2/2018 7/3/2018 1.50 DEMOB MOVE RURD X Install flanges and jewlery on tree. 0.0 0.0 22:30 00:00 Clean and secure wellhead . Install well sign. TBG / IA 0/0 press. Swap to generator power, disconnecting electrical interconnect. Rig release to move to 1 H-115 @ 2359 hrs 7/2/2018. 7/19/2018 7/19/2018 8.00 MIRU MOVE MOB X Released rig F/1H-115 at 10:00 1,834.0 1,834.0 10:00 18:00 Moved rig over 1 H-1 08B, Rigged up and completed rig acceptance check list. Rig accepted at 18:00 hrs. 7/19/2018 7119/2018 1.50 MIRU MOVE RURD X Rig up to circulate out diesel to tiger 0.0 0.0 18:00 19:30 tank 7/19/2018 7/19/2018 3.00 MIRU WHDBOP MPSP X Monitor well pull BPV. Reinstall BPV. 0.0 0.0 19:30 22:30 ( Rig waiting on vis. Brine decision made to reinstall BPV) test BPV 250 low- 2,500 psi high. (Charted) N/D tree, Install blanking plug, Set install plate on top of hanger and torque. 7/19/2018 7/20/2018 1.50 MIRU WHDBOP NUND X Set spacer spools, Set BOP stack, 0.0 0.0 22:30 00:00 Install choke and kill lines. Install flow riser. 7/20/2018 7/20/2018 1.50 MIRU WHDBOP NUND X Complete torquing all flanges on 0.0 0.0 00:00 01:30 BOPE. Install mouse hole 7/20/2018 7/20/2018 2.50 MIRU WHDBOP CIRC X Pull blanking plug & BPV, Install 0.0 0.0 01:30 04:00 landing joint. Rig up to reverse circulate out diesel freeze protect to tiger tank. Pump 6 bpm, 600 psi. 1,800 strokes until brine visable at tiger tank. 7/20/2018 7/20/2018 7.00 MIRU WHDBOP BOPE X Install BPV & blanking plug. Witness 0.0 0.0 04:00 11:00 of test waived by AOGCC Insp Adam Earl. Test w/ 3.5", 4.5" and 7" test jts. Test 250 psi low and 3500 psi high, 5 min each.lnstall BPV & blanking plug. Test Super & manual choke T/2,500 psi. Test all other 250-3,500 psi. Test choke valves 1-14. Test mud manifold, Mezzanine, HCR & manual kill valves. Manual & HCR choke, Annular W/7"- 3 -112' test jts. 4 1/2" XT43 and 4" XT39 TIW & dart Valves, Test Upper & lower top drive IBOP's. Lower VERS. W/3- 1/2" & 4-1/2" test jts. Upper rams W/7" test jt. Perform koomey draw down test- Initial system psi 3,000, After closure 1,750 psi, 200 psi attained 7 sec. Full psi- 48 sec. 6 nitrogen bottles average psi 1,975. Test pit levels, flow out alarm, H2S & Combustable gas audible & light alrams. 7/20/2018 7/20/2018 1.00 MIRU WHDBOP RURD X Rig down testing equipment, Blow 0.0 0.0 11:00 12:00 down all lines. 7/20/2018 7/20/2018 1.00 PROD2 PLUG PULL X PJSM/ F/ Laying down 3-1/2" EUE 9.3 1,781.0 1,750.0 12:00 13:00 ppf. tubing and hanger. Pick up landing joint make upto hanger, Make up cement hose T/ Circulate, Pull hanger W/62k up. Pull hanger to floor. 7/20/2018 7/20/2018 0.50 PROD2 PLUG CIRC X Circulate @ 523 gpm, 12 bom, 327 1,750.0 1,750.0 13:00 13:30 psi, 27% flow out. Total strokes pumped - 3,030. Sim -Ops R/U GBR Page 18135 ReportPrinted: 811012018 Operations Summary (with Timelog Depths) IH -108 ' Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stall Time End Tie Dur(hr) Phase Op Code Activity Code Tim P -T -X Operation (ftKB) End DepN(MB) 7/20/2018 7120/2018 3.25 PROD2 PLUG PULL X UD hanger & Landing Joint. Lay down 1,750.0 0.0 13:30 16:45 55 joints & 2, pups of 3-1/2 EUE 9.3 ppf tubing. Up wt. 60k Dn wt. 59k. Monitor via trip tank. 7/20/2018 7/20/2018 1.00 PROD2 PLUG RURD X Rig Down GBR. Clear and clean rig 0.0 0.0 16:45 1745 floor. 7/20/2018 7/20/2018 0.50 PROD2 PLUG RURD X Mobilze saver sub & BHA to rig floor 0.0 0.0 17:45 18:15 7/20/2018 7/20/2018 1.25 PROD2 PLUG SVRG X Change out XT -43 saver sub in top 0.0 0.0 18:15 19:30 drive. 7/20/2018 7/20/2018 1.25 PROD2 PLUG SLPC X Slip & Cut 63' of Drill line, Calibrate 0.0 0.0 1930 2045 block height - 7/20/2018 7/20/2018 0.50 PROD2 PLUG SVRG X Service Top Drive, Blocks & Crown 0.0 0.0 20:45 21:15 7/20/2018 7/20/2018 0.50 PROD2 PLUG RURD X set 12-3/8" ID- Wear ring. Obtain RKB 0.0 0.0 21:15 21:45 measurements 7/20/2018 7/20/2018 2.00 PROD2 PLUG BHAH X P/U CIBP & Cement drill out BHA- 0.0 482.0 21:45 23:45 T/482' MD. Monitor displacement via pit # 1 7/20/2018 7/21/2018 0.25 PROD2 PLUG TRIP X Trip in picking up 4-112" XT -43 482.0 703.0 23:45 00:00 drillpipe. F/482'MD - T/ 703'MD. Monitor displacement via pit # 1 7/21/2018 7/21/2018 1.25 PROD2 PLUG TRIP X Continue RIH P/U 4-1/2"X743 703.0 1,777.0 00:00 01:15 Drillpipe F/703' MD -T/1,777' MD. Monitor displacement via pit # 1. Up wt. 92k, Dn wt, 87k, Rot wt. 90k 7/21/2018 7/21/2018 0.50 PROD2 PLUG CIRC X Fill Pipe, Obtain Slow Pump Rates 1,777.0 1,782.0 01:15 01:45 Wash down and tag at 1,782' MD 7/2112018 7/21/2018 4.25 PROD2 PLUG COCF X Drill CIBP & Cement F/1,782' MD - 1,782.0 1,809.0 01:45 06:00 T/1.809' MD. 800 gpm,415 psi, 29% flow out, 70 rpm, 1-1 OK torque. 20-40k bit wt. up wt. 98k. Dn wt. 87K. Rot wt. 90K. 7/21/2018 7/21/2018 3.00 PROD2 PLUG COCF X Drill] CIBP & Cement F/1,809' MD - 1,809.0 1,836.0 06:00 09:00 T/1.836' MD. 567 gpm,400 psi, 29% flow out, 70 rpm, 1-1 OK torque. 20-40k bit wt. up wt. 98k. Dn wt. 87K- Rat M. 90K. 7/21/2018 7/21/2018 0.50 PROD2 PLUG CIRC X Wash & Ream F/1,830' MD -T/1,800' 1,836.0 1,830.0 09:00 09:30 MD. 700 gpm, 423 psi, 34% flow out 70 rpm, 3K. Torque, Up wt. 98K. Dn Wt. 87K. Rot. Wt. 90K. Total strokes pumped - 3,330 7/21/2018 7/21/2018 0.50 PROD2 PLUG DISP X Displace well Fl viscosified brine - T/ 1,830.0 1,830.0 09:30 10:00 9.0 ppg. LSND. Pump 30 bbl. spacer followed by 9.0 ppg LNSD. Rotate & Reciprocate F/ 1,830' MD - T/1,800' MD. 700 gpm, 423 psi, 34% flow out, 31K torque. Up wt. 98k Dn wt. 87k. Rot wt. 90k. Total strokes pumped - 5,358 7/21/2018 7/21/2018 0.50 PROD2 PLUG CIRC X Obtain slow pump rates 1,830.0 1,810.0 10:00 10:30 MP#1) 30 spm -60 psi 40 spm - 70 -psi MP#2) 30 spm -60 psi 40 spm - 70 -psi Rack back stand # 15, OWFF- static 7/21/2018 7/21/2018 1.50 PROD2 PLUG TRIP X Pump dryjob, TOOH - F/1,810'MD - 1,810.0 300.0 10:30 12:00 T/300' MD. Pulling on elevators. Monitor via trip tank. 7/21/2018 7/21/2018 1.00 PROD2 PLUG BHAH X UD Cleanout BHA F/300' MD 300.0 0.0 12:00 13:00 Monitor via trip tank Page 19135 Report Printed: 8110/2018 Gperations Summary (with Timelog Depths) 1 H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start lime End Time our (hr) Phase Op Code Acdvity Cade Time P -T -X Operelbn Start Depth (MB) End Depth (Wll) 7121/2018 7/21/2018 0.50 PROD2 PLUG BHAH X Clear and Clean rig floor 0.0 0.0 13:00 13:30 7/21/2018 7/21/2018 0.75 PROD2 PLUG BHAH X Pick up Drilling assembly with 0.0 368.0 13:30 14:15 Milltooth bit T/386' MD. Ran in with BHA F/ Derrick F/ 86' MD - T/368' MD. Drill collars, HWDP & Jars Up wt. 59k. Dn wt. 64k. Monitor displacement via trip tank. 7/21/2018 7/21/2018 1.50 PROD2 PLUG TRIP X TIH, F/36& MD -T/1,794' MD. Picking 368.0 1,794.0 14:15 15:45 up 4-1/2" XT -43 ddllpipe F/Pipeshed. Shallow pulse test downhole tools W1550 gpm, 776 psi. 37% Flow out at 1,794' MD. 7/21/2018 7/21/2018 0.75 PROD2 PLUG REAM X Wash & Ream down F/1,794' MD - 1,794.0 1,836.0 15:45 16:30 T/1,836' MD. W/587 gpm, 816 psi. 30% flow out. 60 rpm. 3k. torque Up wt. 85k. Dn wt. 82k. Rot wt. 82k. 7/21/2018 7/21/2018 1.50 INTRMI DRILL DDRL X Dril 8-3/4" hole F/1,836' MD -T/1,884' 1,836.0 1,884.0 16:30 18:00 MD. 1,813' TVD. 560 gpm,770 psi,28% Flow out,60 rpm,2K torque, 5k. WOB, Up wt. 85k. Dn wt. 82k. Rot wt. 82k. Ik. Torque off bottom, Off bottom psi -764. Max gas units 17 ADT -96 Bit Hrs..96, Jar hrs. = 59.4 Sidetrack not confirmed at this depth. Indications good. 7/21/2018 7/21/2018 4.50 INTRMI DRILL DDRL X Drill 8-3/4" hole F/1,884'MD-T/2,264' 1,684.0 2,264.0 18:00 22:30 MD, 2,119' TVD. 550 gpm,830 psi. 30% flow out, 60 rpm, 3k. torque 20k. Bit wt. ECD's 9.8. Off bottom psi = 820. Up -89k. Down -861k. Rot -87k. 1.5k. torque off, Max gas 40 units. ADT- 3.61 Bit hrs. 4.57. Jar hrs. 63.01 7/21/2018 7/21/2018 0.50 INTRM1 DRILL CIRC X Circulate 2 times bottoms up Rot & 2,264.0 2,170.0 22:30 23:00 recip F/2,264' MD -T/2,170' MD. 600 gpm, 930 psi.29%flow out, 60 rpm, 1.5k. torque off. Total strokes 3,300. MW in 9.0 MW out 9.1. Up 88k. Down 87k. Rot 87k. 7/21/2018 7/21/2018 0.25 INTRMI DRILL OWFF X Monitor well for 10 minutes fluid level 2,170.0 2,170.0 23:00 23:15 dropped 3" 7/21/2018 7/22/2018 0.75 INTRMI DRILL TRIP X POOH on elevators, F/2,170' MD- 2,170.0 1,604.0 23:15 00:00 T/1,980' MD. Swabbing- Kelly up & pump out at 5 bpm, 220 psi. 13% flaw out. F/1,980' MD -T/ 1,790' MD. Pulling sipped 40 fpm. POOH on elevators F/1,980' MD - T/1,604' MD. Up - 80k. Down 78k. SPR's @ 2,264' MD - 2,119' TVD MW - 9.0 ppg. Time 23:00 Pump #1= 30 spm 90 psi, 40 spm 120 psi. Pump #2= 30 spm 90 psi, 40 spm 120 psi. 7/22/2018 7/22/2018 0.50 INTRMI DRILL TRIP X TOOH F/1,604'MD - T/ 367'MD. 1,604.0 367.0 00:00 00:30 Monitor via trip tank, Up 63k. Down 66k. 7/22/2018 7/22/2018 1.00 INTRMI DRILL BHAH X Rack back HWDDP, Jars, Drill collars, 367.0 0.0 00:30 01:30 Lay down BHA components. Down 62k. Hole fill monitored via trip tank. 7/22/2018 7/22/2018 1.25 INTRMI DRILL BHAH X Make up BHA# 7. Per directional 0.0 381.0 01:30 02:45 driller T/381' MD. Displacement monitored via trip tank. Up 87k. Down 83k. Page 20136 ReportPrinted: 811012018 Operations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Tene our (hr) Phase Op Cade Aetivity Code Time P -T -X Operalbn (flkB) End Depth (IIkB) 7/22/2018 7/22/2018 0.75 INTRMI DRILL TRIP X Run in hole with drilipipe from Derrick 381.0 1,813.0 02:45 03:30 T/1,813' MD. Displacement monitored via trip. Up 87k. Dwon 83k. 7/22/2018 7122/2018 2.50 INTRMI DRILL DHEQ X Shallow pulse test tools, (Good test) 1,813.0 2,264.0 03:30 06:00 MADD pass F/1,813' MD - T/2,264' MD. 600 gpm, 800 psi, 30% flow out. MADD pass at 350 fph. 7/22/2018 7/22/2018 6.00 INTRM1 DRILL DDRL X Drill 8-3/4" Intermediate section F/ 2,264.0 2,820.0 06:00 12:00 2,264' MD - T/2,820' MD, 2,418' TVD. 605 gpm,864 psi,30 % Flow out Off bottom psi = 560. ECD's - 9.72 ppg. Max gas 89 units. Up 98k. Down 82k. Rot 87k. 3k. Torque. ADT -3.35, Bit hrs. 3.35, Jar hrs. 66.36 SPR's @ 2,286' MD, 2,131' TVD, MW 9.2 ppg MP#1) 30 SPM- 90 psi. 40 SPM- 120 psi. MP#2) 30 SPM- 90 psi. 40 SPM- 120 psi. 7/22/2018 7/22/2018 1.50 INTRMI DRILL DDRL X Drill 8-3/4" Intermediate section F/ 2,820.0 2,983.0 12:00 13:30 2,820' MD - T/2,983' MD. 605 gpm, 846 psi. 30% flow out.max gas 53 units. off bottom psi = 850. ECD's 9.72 ppg. Rot 120 rpm, 3.5k. Torque, 2k. bit wt. Up 98k. Dwon 82k. Rot 87k. Observed 200 psi packoff. 7/22/2018 7/22/2018 4.00 INTRMI DRILL DDRL X Drill coal section F/2,983' MD. - T/ 2,983.0 3,030.0 13:30 17:30 3,030' MD. 2,505' TVD. 420-481 gpm, psi 460- 517. Flow out 29% 80 rpm, 3.5k. Torque 1-3 bit wt. 7/22/2018 7/22/2018 0.50 INTRMI DRILL DDRL X Drill 8-314" Intermediate section, 3,030.0 3,050.0 17:30 18:00 FI3,030' MD. - T/3,050' MD. 2,505' - TVD. 605 gpm,870 psi, 30%, Flow out. ECD's 9.7 ppg. Off bottom psi- 863. Gas 57 units. 3.5k. torque Bit wt4k. max gas 57 units. 140 rpm. 3k. torque, off bottom. Up 98k. Down 82k. Rot 87k. ADT- 2.46 hrs. Bit hrs. 5.81 Jar hrs - 68.82. 7/22/2018 7/23/2018 6.00 INTRMI DRILL DDRL X Drill 8-3/4" Intermediate section, 3,050.0 4,100.0 18:00 00:00 F/3,050' MD. -T/4,100' MD. 2,875' TVD. 700 gpm,1320 psi, 33%, Flow out. ECD's 10.33 ppg. Off bottom psi - 1,315. Gas 95 units. 6k. torque Bit wt 14k. max gas 95 units. 140 rpm. 3.5k. torque, off bottom. Up 109k. Down 83k. Rot 94k. ADT- 4.2 hrs. Bit hrs. 10.01 Jar hrs - 73.02. Pump Hi -Vis weighted sweeps every 500' MP#1) 30 SPM- 100 psi. 40 SPM- 140 psi. MP#2) 30 SPM- 10 psi. 40 SPM- 140 psi Page 21135 Report Printed: 8110/2018 p Gperations Summary (with Timelog Depths) 11-1-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase op Co Acllvtty Code Time P -T -X Operation Start Depth (itKB) EM DepN (BKB) 7/2312018 7/23/2018 6.00 INTRMI DRILL DDRL X Drill 8-3/4" Intermediate hole, F/4,100' 4,100.0 5,180.0 00:00 06:00 MD-T/5,180'MD,3,228'TVD.700 gpm, 1,530 psi, 33% flow out, 140 rpm, 6k torque, bit wt. 7k. ECD's 10.57, Off bottom -1,540 psi,Up 116k, Down 851k, Rot 99k, 5k torque off, Max gas 60 units. ADT - 4.1, Bit hrs: 14.11, Jar hrs. - 77.12 7/23/2018 7/23/2018 6.00 INTRMI DRILL DDRL X Drill 8-3/4" Intermediate hole, F/5,180' 5,180.0 5,845.0 06:00 12:00 MD - T/ 5,845' MD, 3,409' TVD. 748 gpm, 1,406 psi, 32% flow out, 130 rpm, 6.51k torque, bit wt. -2k. ECD's 10.13, Off bottom -1,407 psi,Up 1191k, Down 87k, Rot 100k, 5k torque off, Max gas 201 units. ADT -4.03, Bit hrs.- 18.14, Jar hrs. - 81.15 SPR's- 5,237' MD, TVD - 3,247' MW - 9.0 ppg MP # 1) 30 SPM - 240 psi. 40 SPM - 280 psi. MP # 2) 30 SPM - 240 psi. 40 SPM - 290 psi. No losses 7/23/2018 7/23/2018 3.50 INTRMI DRILL DDRL X Drill 8-3/4" Intermediate hole, F/5,845' 5,845.0 6,191.0 12:00 15:30 MD - T/ 6,191' MD, 3,463' ND. 720 gpm, 1,745 psi, 32% flow out, 140 rpm, 7 k torque, bit wt. -12 k. ECD's 10.35, Off bottom -1,740 psi,Up 120 k, Down 85 k, Rot 100 k, 5k torque off, Max gas 90 units. ADT - 2.57, Bit hrs.- 20.71, Jar hrs. - 79.69. Xceed tool problem, Discontinue drilling. 7/23/2018 7123/2018 2.25 INTRMI DRILL CIRC XT Rot & Reciprocate pipe 6,189' MD - 6,191.0 6,191.0 15:30 17:45 6,099' MD. 771 gpm, 1,848 psi, Flow out 34%, 100 rpm, 6 k torque. Up 120 k. Down 85 k. Rot 100 k. Total strokes pumped 9,050 SPR's-6,186'MD, TVD -3,463' MW - 9.1+ ppg MP # 1) 30 SPM - 160 psi. 40 SPM - 210 psi. MP # 2) 30 SPM - 170 psi. 40 SPM - 210 psi. 7/23/2018 7/23/2018 0.50 INTRMI DRILL OWFF XT Observe well for flow, Fluid level 6,191.0 6,191.0 17:45 18:15 dropped 6" Sim -Ops- Service wash pipe, Blow down topddve 7/23/2018 7/23/2018 0.75 INTRMI DRILL TRIP XT Pull out of hole F/6,189' MD - T/ 5,816' 6,191.0 5,816.0 18:15 19:00 MD. Up 129k. down 77k. 20-30k Overpull, well swabbing. 7/23/2018 7/24/2018 5.00 INTRM1 DRILL BKRM XT Back Ream Out of Hole, F/5,816' MD- 5,816.0 3,531.0 19:00 00:00 T/3,531' MD. 700 gpm, 1,420 psi, 33% Flow out, 140 rpm, 51k. Torque, ECD's 10.54 ppg. Up. 103k. Down 83k. 7/24/2018 7/24/2018 4.25 INTRMI DRILL BKRM XT Back Ream Out of Hole, F/3,531' MD - 3,531.0 1,809.0 00:00 04:15 T/1,809' MD. 600 gpm, 925 psi, 32% Flow out, 140 rpm, 3k. Torque, ECD's 10.03 ppg. Up. 86k. Down 84k. Page 22136 Report Printed: 811012018 Operations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op CcOe Activity Code Time P -T -X Operation Stan Depth d1KB) End Depth (ftKB) 7/24/2018 7/24/2018 0.25 INTRMI DRILL CIRC XT Circulate bottoms up Rotating and 1,809.0 1,809.0 04:15 04:30 reciprocating drillstring. F/ 1,809' MD - T/ 1,728' MD. 700 gpm, 1,100 psi, 33% flow out. 100 rpm, 1.8k Torque. 9.69 ECD's. Total strokes pumped = 1,700 7/24/2018 7/24/2018 0.25 INTRMI DRILL OWFF XT Monitor well (Static) Pump 15 bbl. dry 1,809.0 1,809.0 04:30 04:45 job 10.3 ppg. 7/24/2018 7/24/2018 0.75 INTRMI DRILL TRIP XT POOH F/1,809' MD - T/ 381' MD. (At 1,809.0 381.0 04:45 05:30 BHA) Monitor hole fill via trip tank 7/24/2018 7/24/2018 1.50 INTRM1 DRILL BHAH XT Rack back HWDP, Jars, Stand DC's. 381.0 0.0 05:30 07:00 1 Lay down Xceed tool and bit. (Per D.D.) 7/24/2018 7/24/2018 0.50 INTRMI DRILL CLEN XT Clear and Clean Rig Floor. - Sim Ops, 0.0 0.0 07:00 07:30 PM Service on drawworks. 7/24/2018 7/24/2018 1.00 INTRM1 DRILL BHAH XT Make up BHA# 8, Run NM Drill collar, 0.0 383.0 07:30 08:30 HWDP & Jars F/Derrick. F/ 95'MD. - T/383' MD. Up 61 k. Down 67k. Monitor displacement via trip tank. 7/24/2018 7/24/2018 3.25 INTRMI DRILL TRIP XT Continue to RIH with BHA #8 with 4.5" 383.0 6,102.0 08:30 11:45 DP from derrick. 383' MD - 6,102' MD. UP WT=120K. DWN WT=78K. Monitor disp via TT. Shallow hole pulse test at 1,810' MD (GOOD). 569 GPM @ 888 PSI DPP. 31 % F/O. Taking 15K DWN WT @ 2,374' MD. and 5,850' DM. 7/24/2018 7/24/2018 0.75 INTRMI DRILL WASH XT Wash down from 6,102' MD to 6,187' 6,102.0 6,187.0 11:45 12:30 MD while staging up pumps to 550 GPM ICP 160 PSI DPP FCP' 1,225 . PSI DPP. 31% F/O. 70 RPM with 6K TQ. UP WT=120 K. DWN WT= 78K. ROT WT - 97K. take SPR's. SPR's 6,188' MD 3,463' TVD MW = 9.2 PPG hrs 12:30 SPM 1) 30 SPM - 180 PSI 40 SPM - 220 PSI SPM 2) 30 SPM - 180 PSI 40 SPM - 220 PSI 7/24/2018 7/24/2018 5.50 INTRMI DRILL DDRL X DDRL 8 3/4" hole from 6187' MD to 6,187.0 6,880.0 12:30 18:00 6,880' MD 3,510' TVD. at 646 GPM 1,694 PSI DPP. 30% F/O, 140 RPM 8K TQ, with 15K WOB. ECD - 10.38, Off bottom 1,658 PSI. UP WT = 132K, DWN WT=78K. ROT -102K. Max gas = 122 units, ADT - 3.57 Bit hrs 3.57, Jar hrs 83.26 7/24/2018 7/25/2018 6.00 INTRMI DRILL DDRL X DDRL 8 3/4" hole from 6,880' MD 6,880.0 7,620.0 18:00 00:00 3,510' TVD - 7,620' MD 3,697' TVD. at 646 GPM 1,950 PSI DPP. 32% F/O, 140 RPM 8K TQ, with 19K WOB. ECD - 10.72, Off bottom 1,940 PSI. UP WT = 136K, DWN WT = 78K. ROT - 102K. 8K TQ Max gas = 30 units, ADT - 3.93 Bit hrs 7.5, Jar hrs 87.19 SPR's 7,140' MD 3,612" TVD MW = 9.0+ PPG hrs 1920 SPM 1) 30 SPM - 180 PSI 40 SPM - 240 PSI SPM 2) 30 SPM - 180 PSI 40 SPM - 230 PSI Page 23/35 Report Printed: 8/10/2018 Summary (with Timelog Depths) 1H-108 lipOperations Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Tune End Tme Dwthr) PhM Dip COW Activity Code Time P-T-XOperetlon Stan Depth (HKS) End Depth (ftKB) 7/25/2018 7/25/2018 6.00 INTRMI DRILL DDRL X DDRL 8 314" hole from 7,620' MD 7,620.0 8,296.0 00:00 06:00 3,697' TVD - 8,286' MD 3,791' TVD. at 646 GPM 1,745 PSI DPP. 31% F/0, 140 RPM 9K TQ, with 4K WOB. ECD - 10.62, Off bottom 1,735 PSI. UP WT =136K, DWN WT=77K. ROT- 106K. 91K TQ Max gas = 50 units, ADT - 4.08 Bit his 11.58, Jar his 91.27 7/25/2018 7/2512018 3.00 INTRMI DRILL DDRL X DDRL 8 3/4" hole from 8,286' MD 8,296.0 8,517.0 06:00 09:00 3,791' TVD - 8,517' MD 3,809' TVD. at 525 GPM 1,333 PSI DPP. 27% F/O, 80 RPM 10K TQ, with 5K WOB. ECD - 10.28, Off bottom 1,909 PSI. UP WT =142K DWN WT=77K. ROT- 107K. 9K TO Max gas = 137 units, ADT - 2.3 Bit hrs 13.88, Jar hrs 93.57 SPR's 8,451' MD 3,804" TVD MW = 9.2+ PPG his 1000 SPM 1) 30 SPM - 190 PSI 40 SPM - 240 PSI SPM 2) 30 SPM - 200 PSI 40 SPM - 250 PSI 7/25/2018 7/25/2018 1.00 INTRMI CASING CIRC X Rotate and recip from 8,517' MD- 8,517.0 8,517.0 09:00 10:00 8,450' MD circulating at 650 GPM, 1,887 PSI DPP. 30% F/O. 140 RPM, 12K TQ. 7/25/2018 7/25/2018 0.50 INTRMI CASING OWFF X OWFF. (static). 8,517.0 8,517.0 10:00 10:30 7/25/2018 7/26/2018 13.50 INTRMI CASING BKRM X BKRM OOH from 8,517' MD - 3,517' 8,517.0 3,517.0 10:30 00:00 MD. UP WT = 102K W/pump 140K WO. 7/26/2018 7/26/2018 5.00 INTRMI CASING BKRM X Continue to BKRM OOH from 3,517' 3,517.0 1,811.0 00:00 05:00 MD- 1,811' MD at 650 GPM 1,110 PSI DPP. 32% F/O with 140 RPM @ 3K TQ. 9.39 ECD. UP WT = 87K. DWN WT = 86K. 7/26/2018 7/26/2018 0.75 INTRMI CASING CIRC X Circulate high vis sweep while recip 1,811.0 1,811.0 05:00 05:45 from 1,811' -1,716' MD. 750 GPM @ 1,350 PSI, 33% F/O with 100 RPM 2K TQ. 9.42 ECD. MWI 9.0 MWO 9.0... 4,745 STKS pumped. UP WT = 86K DWN WT= 85K. 7/26/2018 7/26/2018 0.25 INTRMI CASING OWFF X OWFF dropped - 3". Pump DJ. 1,811.0 1,811.0 05:45 06:00 7/26/2018 7/2612018 1.50 INTRM1 CASING TRIP X Continue to POOH from 1,811' MD - 1,811.0 363.0 06:00 07:30 383'MD. UP WT=85K.. DWN WT= 85K. Monitor disp via TT. 7/26/2018 7/26/2018 2.50 INTRMI CASING BHAH X LD HWDP jars and BHA#8. Clean dg 383.0 0.0 07:30 10:00 floor while monitor disp via TT. 7/26/2018 7/26/2018 2.00 INTRMI CASING KURD X MU 4 1/2" DP cross over and stack 0.0 0.0 10:00 12:00 flushing tool. flush stack at 900 GPM / simiops bringing GBR tools to rig floor and setting up. Clean rig floor. Pull wear bushing and prep to RIH with 7" casing. 18 7/26/2018 0.25 INTRMI CASING SFTY X PJSM for running casing with GBR 0.0 0.0 12:15 and dg crew. 18 tOO 7/26/2018 0.50 INTRMI CASING PUTB X MU / Baker Lock Shoe track assym. 0.0 1200 12:45 TQ TXP connections to 17,700 FT/LB. HYD 563 TQ - 9,400 FT / LB. Monitor disp via TT. Page 24/35 ReportPrinted: 811012018 Uperations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time Entl Tme Dur (h) Phase Op Code Activiry Code Time P -T -X Operadon Start Depth (ftKB) End Depth(ItKa) 7/26/2018 7/26/2018 0.25 INTRMI CASING CIRC X Check floats (Good). staged up 120.0 199.0 12:45 13:00 pumps to 8 BPM @ 350 GPM, 85 PSI casing pressure, 26% F/O. 330 silks. 7/26/2018 7/26/2018 1.75 INTRMI CASING PUTB X Continue to RIH with 26# L-80 TXP 7" 199.0 940.0 13:00 14:45 casing from 199' MD TO TXP to 17,700 FT/LB. Monitor tlisp via Pit 5- 712612018 7/26/2018 1.50 INTRM1 CASING EQRP XT GBR hose failure. Shut down for hose 940.0 940.0 14:45 16:15 replacement and troubleshoot. clean up hyd fluid. Spill -1 gal of had fluid to pad. 7/26/2018 7/27/2018 7.75 INTRM1 CASING PUTB X Continue to RIH with 7" 26# TXP L-80 940.0 4,245.0 16:15 00:00 casing from 940' MD - 4,245' MD filling every 10. Losses minimal and acceptable. Monitor tlisp via pit #5. 7/27/2018 7/27/2018 6.00 INTRMI CASING PUTB X Continue to RIH with 7" 26# L-80 TXP 4,245.0 6,672.6- 00:00 06:00 casing from 4,245' MD - 6,672' MD. Fill on the fly and top off every ten joints. Monitor disp via pit #5. UP WT =167K. DWN WT=86K. 7/27/2018 7/27/2018 0.75 INTRMI CASING CIRC X Circulate bottoms up while recip from 6,672.0 6,672.0 06:00 06:45 6,672' MD - 6,632' MD. Stage pumps up to 7 BPM @ 305 PSI. 22% F/O. 2,300 STKS pumped MWI = 9.2# MWO = 9.2#. 7/27/2018 7/27/2018 4.00 INTRMI CASING PUTB X Continue to RIH with 7" 26# L-80 TXP 6,672.0 8,466.0 06:45 10:45 casing from 6,672' MD - 8,466' MD. Fill on the fly and top off every 10 jts. Monitor tlisp via Pit #5. UP WT = 204K. DWN WT=94K. 7/27/2018 7/27/2018 0.75 INTRMI CASING HOSO X Make up HNGR assym and wash 8,466.0 8,508.0 10:45 11:30 down to land on depth at 4 BPM 350 PSI with 14% F/O. 7/27/2018 7/27/2018 4.00 INTRMI CEMENT CIRC X RU cement hose and circulate while 8,508.0 8,488.0 11:30 15:30 recip from 8,504' MD - 8,488' MD. Stage up to 7 BPM @ 500 PSI, 23% F/O with UP WT = 173K (While pumping), DWN WT= 84K. Raise rate to 8 BPM and pump a total of 15,120 stks. 7/27/2018 7/27/2018 0.50 INTRMI CEMENT PRTS X RU Schlumberger pump and pump 5 8,488.0 8,488.0 15:30 16:00 BBL of fresh water to PT Replace 1502 gsket and retest to 4,000 PSI. Page 25135 Report Printed: 8116-120-18 Operations Summary (with Timelog Depths) 11-1-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slav Time E d-hm Dur (hr) Phase Op COP Advity Cotl Time PJA Opeatlon Star) Dep" (We) End Depth (fiKB) 7/27/2018 7/27/2018 2.75 INTRMI CEMENT CMNT X Drop bottom plug number 1 and pump 8,488.0 8,508.0 16:00 18:45 40.1 BBLS of 12.5# mud push. pumping at 4.1 BPM with 80-177 PSI casing pump pressure. 10-14%F/0, Launch 2nd bottom plug and pump 173.1 BBLS of 15.8PPG class G cement at 3.7 - 5.2 BPM at 50-140 PSI pump pressure. 11-21%F/0. UP WT = 230K. OWN WT = 54K. Launch Top plug and push with 10 BBLS Fresh water prior to switching to dg pumps. On dg pump and displace with 9.2# LSND @ 8 BPM at 2,089 STKS. ICP = 200 PSI, FCP = 737 PSI. 23% F/O, UP WT = 250K, OWN WT = 52K. Lower rate to 5 BPM pump 2,730 STKS with ICP 575 PSI 17% F/0, FCP = 863 PSI, UP WT = 250 K OWN WT= 40K. Land on hanger at 2,230 STKS due to lack of down wt. Reduce rate to 3 BPM with a FCP of 900 PSI 8% F/O. Bump plug at 3,074 STKS. raise pressure to 1,400 PSI and hold for 5 min. Cement in place at 1830 hrs. Bleed off. 7/27/2018 7/27/2018 1.00 INTRMI WHDBOP PRTS X RU and pressure test casing to 3,600 8,508.0 8,508.0 18:45 19:45 PSI for 30 charted min. (PASSED) Pumped 6 BBLS and bled back same. Floats holding (PASSED) 7/27/2018 7/27/2018 0.50 INTRMI CEMENT RURD X BD lines and pull landing joint / lay 8,508.0 0.0 19:45 20:15 down same. 7/27/2018 7/27/2018 0.75 INTRMI WHDBOP WWSP X Drain stack and set pack off. RILDS 0.0 0.0 20:15 21:00 and test to 5,000 PSI witnessed by Rock. LDtestjoint. 7/27/2018 7/27/2018 2.00 INTRMI CEMENT CIRC X C/0 saver sub to XT -39 and run 0.0 0.0 21:00 23:00 injection line to OA. Inject 13 BBLS into 10 3/4" X 7" annulus to ensure injectivity at 1 BPM 450 PSI. 7/27/2018 7/27/2018 0.50 INTRMI CEMENT RURD X Test 4" dart valve to 250/3,500 PSI for 0.0 0.0 23:00 23:30 5 min ea. Tested 4" XT39 FOSV to 250 psi / 3500 psi 5 min ea. All tests charted. Set 9" wear bushing. 7/27/2016 7/28/2018 0.50 INTRMI CEMENT SHAH X Bring BHA and handling tools to rig 0.0 22.0 23:30 00:00 floor. Hold PJSM for making up PD to bit. 7/28/2018 7/28/2018 2.25 INTRMI CEMENT BHAH X Continue to MU BHA#9 from 22'- 22.0 395.0 00:00 02:15 395' MD. 7/28/2018 7/28/2016 2.00 INTRMI CEMENT TRIP X RIH from 395' MD to 1,900' MD. 395.0 1,900.0 02:15 04:15 Monitor disp via pit#1. UP WT=80K. OWN WT= 76K. Fill every ten. 7/28/2018 7/28/2018 0.25 INTRMI CEMENT DHEQ X Shallow hole test MWD at 250 GPM 1,900.0 1,900.0 04:15 04:30 1,330 PSI DPP. 18% F/0. 7/28/2018 7/28/2018 1.50 INTRMI CEMENT QEVL X Continue to RIH logging free pipe from 1,900.0 2,862.0 04:30 06:00 1,900' MD to 2,100' MD' MD at 800 FPM. Making up stands in mouse hole. Monitor disp via pal. UP WT = 90K. OWN WT=78K. Page 26135 Report Printed: 8/1 012 01 8 Uperations Summary (with Timelog Depths) 11-1-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartT, End Tana our (hr) Phase Op Code Activity Code Time P -T -X Operation Stan Depth (BKB) EM Depth IflKB) 7/28/2018 7/28/2018 10.26 INTRM1 CEMENT QEVL X Continue to RIH with BHA#9 from 2,862.0 8,338.0 06:00 16:15 2,862' MD - cement tag at 8,338' MD. Filling pipe every ten and monitoring disp via Pit #I. Log cement quality form 6,001' MD - 6,338' MD at 800 FPH. Simops to flush and freeze protect OA with 89 BBLS of FW and 97 BBLS diesel. SIP after water flush = 460 PSI. After diesel = 600 PSI. Max pressure while injecting 635 PSI. 7/28/2018 7/28/2018 1.75 INTRMI CEMENT DRLG X Drill cement from 8,338' MD - 8,382.8 8,338.0 8,385.0 16:15 18:00 MD. at 240 GPM, 1,810 PSI DPP. 21% F/O, 50 RPM with 1 OK TO. Tag plugs at 8,382' MD. Drill plugs from 8,383' MD - 8,385' MD. @ 150 -200 GPM, 1,100 PSI DPP. 15%F/O 7K WOB. 10K TQ. 7/28/2018 7/28/2018 2.75 INTRMI CEMENT DRLG X Continue to drill shoe track from 8,385' 8,385.0 8,517.0 18:00 20:45 MD - 8,517' MD. at 230 GPM 80 RPM, 9.5K TQ, 15K WOB, 11.5 ECD, Tag top of shoe at 8,506' MD. Drill out with 6-10K WOB. 7/28/2018 7/28/2018 0.25 INTRMI CEMENT DRLG X Drill 6 1/8" hole form 8,517' MD - 8,517.0 8,537.0 20:45 21:00 8,537' MD 3,812' ND. at 240 GPM 1,900 PSI 17% F/0, 80 RPM 9.5K TO. 12K WOB, ECD's = 11.38, ADT .16. Bit HRS =.16, Jar ms =.16. 7/28/2018 7/28/2018 1.00 INTRMI CEMENT CIRC X Circulate bottoms up while recip and 8,537.0 8,537.0 21:00 22:00 rotating from 8,537' MD - 8,503' MD. 240 GPM @ 1,850 PSI. 18% F/O, 80 RPM wiht 9K TO. UP WT = 175K. DWN WT=56K. ROT =104K. 9.1 PPG MWI/MWO. 2,230 STKS pumped. 7/28/2018 7/28/2018 0.75 INTRMI CEMENT FIT X RU and perform an FIT to 13 PPG 8,537.0 8,537.0 22:00 22:45 EMW. 9 stks, to pressure up. .6 BBLS bled back. BD/RD. (PASSED) 7/28/2018 7/29/2018 1.25 PROD3 DRILL DDRL X DDRL 6 1/8" hole form 8,537 MD - 8,537.0 8,597.0 22:45 00:00 8,597' MD 3,815' TVD. 250 GPM 1,815 pSl DPP. 17% F/O, 100 RPM, 9.4K TQ with 4K WOB. ECD'c = 11.06, Off bottom 1,810 PSI, UP WT = 137K, DWN WT=75K. ROT =98K. 9K TO. ADT .68, Bit hrs .84, Jar hrs .84 7/29/2018 7/29/2018 6.00 PROD3 DRILL DDRL X DDRL 6 1/8" hole form 8,597' MD 8,597.0 9,323.0 00:00 06:00 3,815' TVD - 9,323' MD 3,830' TVD. 250 GPM 1,950 PSI DPP. 19% F/O, 150 RPM, 6.5K TQ with 3K WOB. ECD'c = 11.5, Off bottom 1,940 PSI, UP WT = 125K, OWN WT = 76K. ROT = 94K. 5K TQ. ADT .3.86, Bit hrs 4.7, Jar his 4.7 MAx gas = 1,030 units SPR's @ 8,657' MD 3,818' TVD MW = 9.2 PPG hrs 0100 1) 20 SPM 530 PSI 30 SPM - 730 PSI 2) 20 SPM 520 PSI 39 SPM - 720 PSI Page 27135 ReportPrinted: 8/10/2018 uperations Summary (with Timelog Depths) IH -108 li p Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartTime End Time Our (hr) Phase Op Code Activit' Code Time P -T -X Operation Start Depth (fIXa) End Depth (ftKB) 7/29/2018 7/2912018 6.00 PRODS DRILL DDRL X DDRL 6 1/8" hole form 9,323' MD 9,323.0 9,798.0 06:00 12:00 3,830' TVD - 9,798' MD 3,840' TVD. 258 GPM 2,105 PSI DPP. 20% F/O, 150 RPM, 8.4K TQ with 10K WOB. ECD'c = 11.3, Off bottom 2,100 PSI, UP WT= 125K, OWN WT= 71 K. ROT = 96K. 5.5K TQ. ADT .4.47 Bit hrs 9.17, Jar hrs 9.17 Max gas = 109 units Troubleshooting MWD system while drilling SPR's @ 9,323' MD 3,830' TVD MW = 9.1+ PPG hrs 0600 1) 20 SPM 540 PSI 30 SPM - 750 PSI 2) 20 SPM 530 PSI 30 SPM - 740 PSI 7/29/2018 729/2018 2.00 PRODS DRILL DDRL X DDRL 6 1/8" hole form 9,798' MD 9,798.0 9,876.0 12:00 14:00 3,840' TVD - 9,876' MD 3,842' TVD. 258 GPM 2,100 PSI DPP. 20% F/0, 150 RPM, 8.4K TQ with 6K WOB. ECD'c = 11.3, Off bottom 2,100 PSI, UP WT= 125K, DWN WT= 71 K. ROT= 96K. 5.5K TO. ADT 1.0 Bit hrs 10. 17, Jar hrs 10.17 Max gas = 109 units 7/29/2018 7/29/2018 1.50 PROD3 DRILL OTHR XT Troubleshoot MWD. Sporadic 9,876.0 9,876.0 14:00 15:30 communication. 7/29/2018 729/2018 1.50 PROD3 DRILL BKRM XT BROOH from 9,876' MD - 9,514' MD 9,876.0 9,514.0 15:30 17:00 @ 240 GPM 1,860 PSI DPP. F/O = 20%, 100 RPM with 5K TQ. UP WT = UP WT= 124K, DWN WT= 97K. 7/29/2018 7/29/2018 1.00 PROD3 DRILL CIRC XT Pump 60 BBL High Vis pill while 9,514.0 9,800.0 17:00 18:00 rotating from 9,514' Md - to 9,800' MD. UP WT=120K, DWN WT=74K. Monitor disp via Pits 1-5. 7/29/2018 7/292018 0.50 PRODS DRILL SVRG X Troubleshoot drawworks shut down. 9,800.0 9,800.0 18:00 18:30 7/292018 7/30/2018 5.50 PRODS DRILL DDRL X Ream to bottom and DDRL from 9,800.0 10,465.0 18:30 00:00 9,876' MD 3,842 TVD - 10,465' MD 3,885' TVD. @ 250 GPM 2,160 PSI DPP. 18% F/O, 150 RPM 8K TO 4.5K WOB. ECD's = 11.78 PPG. Off BTM = 2,150 PSI. UP WT = 130K, DWN WT = 68K, ROT = 95K. 7K TO. Max gas = 67 units, ADT = 3.37, Bit hrs = 13.54, Jar = 13.54. SPR's @ 9,895' MD 3,843' TVD MW = 9.1 PPG, hrs = 1915 1) 20 SPM = 550 PSI 30 SPM = 760 PSI 2) 20 SPM = 550 PSI 30 SPM = 780 PSI Page 28135 Report Printed: 8/10/2018 Gperations Summary (with Timelog Depths) IH -108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siert Tim End Time Dur (hr) Phase Op Code Activit' Tim me P -T -X Operation Start Depth (KKa) EM Depth(Ih(a) 7/30/2016 7/30/2018 4.50 PROD3 DRILL DDRL DDRL from 10,465' MD 3,885' TVD - 10,465.0 10,725.0 0000 04:30 10,725' MD 3,895' TVD. @ 250 GPM 2,270 PSI DPP. 19% F/O, 150 RPM 7.81K TO, 3K WOB. ECD's = 11.82 PPG. OR BTM =2,260 PSI. UP WT= 132K, OWN WT = 65K, ROT = 1 OOK. 71K TQ. Max gas 60 units, ADT= 1.97, Bit hrs = 15.51, Jar= 15.51. SPR's @ 10,725' MD 3,895' TVD MW = 9.0 PPG, him = 0509 1) 20 SPM = 640 PSI 30 SPM = 840 PSI 2) 20 SPM = 620 PSI 30 SPM = 840 PSI 7/30/2018 7/30/2018 0.50 PROD3 DRILL CIRC XT Circulate bottoms up while 10,725.0 10,725.0 04:30 05:00 reciprocating from 10,724' MD - 10,656' MD. 250 GPM @ 2,270 PSI DPP. 19% F/O, 140 RPM, 71K TQ, pumped 2,300 STKs total. POOH to change out smart tools! 7/30/2018 7/30/2018 0.50 PRODS DRILL OWFF XT Observe well for flow(droped l"). 10,725.0 10,725.0 05:00 05:30 7/30/2018 7/30/2018 6.o0 PRODS DRILL BKRM XT BKRM OOH from 10,725'M D, to 10,725.0 8,468.0 05:30 11:30 8,468' MD @ 250 GPM, 2,067 PSI, 19% F/O. 150 RPM, 5.51K TO, 11.21 ECD. UPWT=110,DWNWT=65K. 7/30/2018 7/30/2018 1.50 PRODS DRILL CIRC XT Pump a high vis pill and circulate / 8,468.0 8,468.0 11:30 13:00 recip from 8,468' MD - 8,373' MD. @ 250 GPM, 2,260 PSI 19% F/0, ECD = 111.66, 120 RPM 5K TO. 7/30/2018 7/30/2018 4.00 PROD3 DRILL TRIP XT Monitor well for static(passed), POOH 8,468.0 395.0 13:00 17:00 on elevators to BHA after pumping dry job from 8,468' MD - 395' MD UP WT = 118K DWN WT= 79K. 7/30/2018 7/30/2018 1.50 PROD3 DRILL BHAH XT Monitor well and lay down BHA#9 as 395.0 0.0 17:00 18:30 per SLB rep. Standing back DC/JArs. Monitor disp via TT. Clean dg floor. 7/30/2018 7/30/2018 1.00 PRODS DRILL BHAH XT MU BHA# 10 as per SLB rep to 365' 0.0 365.0 18:30 19:30 MD. Monitor disp via TT. 7/30/2018 7/30/2018 0.75 PRODS DRILL TRIP XT Trip in hole from 365' MD - 2,255MD. 365.0 2,255.0 19:30 20:15 UP WT=80K. DWN WT=77K. Monitor disp via TT. 7/30/2018 7/30/2018 0.25 PRODS DRILL DHEQ XT Shallow hole lest MWD @ 240 GPM 2,255.0 2,255.0 20:15 20:30 1,430 PSI, 19% F/O, 40 RPM. (GOOD). 7/30/2018 7/31/2018 3.50 PROD3 DRILL TRIP XT Continue to trip in hole form 2,255' MD 2,255.0 8,913.0 20:30 00:00 - 8,913' MD 85K UP WT/42K DWN WT . Monitor disp via TT. fill pipe every 20 stands. 7/31/2018 7/31/2018 0.75 PRODS DRILL TRIP XT Continue tripping in hole F/ 8,916' MD 8,913.0 10,626.0 00:00 00:45 -T/ 10,626' MD. Monitor displacement via trip tank Up 138k. Down 74k. 7/31/2018 7/31/2018 0.75 PROD3 DRILL REAM XT Wash down F/ 10,626'MD 7T/ 10,725' 10,626.0 10,725.0 00:45 01:30 MD 250gpm,2,415 psi. 18% flow out, 100 rpm, 5.7k Torque. 11.6 ECD. SPR's at 10,711' MD 3,897' TVD MW 9.2 MPp1) 20 spm - 680 psi, 30 spm - 880 psi MP#2) 20 spm - 640 psi, 30 spm - 860 psi Page 29135 ReportPrinted: 811 012 01 8 . Operations Summary (with Timelog Depths) 11-1-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth StartTime End Time our(hr) PhaseOp Cotle ANvily Code Time P -T -X Operedon (fixe) End Depth (fiKB) 7/31/2018 7/31/2018 4.50 PRODS DRILL DDRL X Drill 6-1/8" Production hole section F/ 10,725.0 11,097.0 01:30 06:00 10,725' MD -T/11,097' MD, 3,896' TVD 250 gpm, 2,460 psi. 18% flow out. 150 rpm, 8.5k Torque, 7.5k bit wt. ECD's 11.88 ppg. off bottom psi=2,450. Up 130k, down 64k, rot 92k. 6k. Torque off bottom,Gas units = 0 ADT - 2.98, Bit hrs. 2.98, jar hrs. - 18.49 7131/2018 7/31/2018 6.00 PRODS DRILL DDRL X Drill 6-1/8" Production hole section F/ 11,097.0 11,490.0 06:00 12:00 11,097' MD - T/11,490' MD, 3,894' TVD 250 gpm, 2,400 psi. 19% flow out. 150 rpm, 7k Torque, 3k bit wt. ECD's 11.99 ppg. off bottom psi=2,400. Up123k,down721k, rot 94k.6kTorque off bottom,Gas units = 0 ADT - 4.2, Bit hrs. 7.18, jar hrs. - 22.69 SPR's at 11,283' MD 3,901' TVD MW 9.2+ MP#1) 20 spm - 740 psi, 30 spm - 960 psi MP#2) 20 spm - 700 psi, 30 spm - 930 psi 7/31/2018 7/31/2018 6.00 PRODS DRILL DDRL X Drill 6-1/8" Production hole section F/ 11,841.0 12,318.0 12:00 18:00 11,841' MD - T/12,318' MD, 3,925' TVD 250 gpm, 2,630 psi. 18% flow out. 150 rpm, 11k Torque,20k bit wt. ECD's 12.09 ppg. off bottom psi=2,580. Up141 k,down 65k, rot 100k.7.5 It, Torque off bottom,Gas units = 30 ADT - 4.36, Bit hrs. 16.33, jar hrs. - 31.84 12,068' MD drilled through fault stayed in zone, SPR's at 11,957' MD 3,917' TVD MW 9.1+ MP#1) 20 spm - 720 psi, 30 spm - 930 psi MP#2) 20 spm - 720 psi, 30 spm - 400 psi 7/31/2018 8/1/2018 6.00 PROD3 DRILL DDRL X Drill 6-1/8" Production hole section F/ 11,490.0 11,841.0 18:00 00:00 11,490' MD - T/11,841' MD, 3,914' TVD 250 gpm, 2,387 psi. 19% flow out. 150 rpm, 8k Torque, 3k bit wt. ECD's 11.82 ppg. off bottom psi=2,380. Up130k,down65k, rot 92k.6kTorque off bottom,Gas units = 0 ADT - 4.79, Bit hrs. 11.97, jar hrs. - 27.48 Page 30135 ReportPrinted: 131-1012018 Operations Summary (with Timelog Depths) 11-1-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time EM Time Our(hd Phase OP Code Ac ivity Cade Time P-T.X Operation Shan Depth (ftKB) End Depth (nKB) 8/1/2018 8/1/2018 6.00 PRODS DRILL DDRL X Drill 6-1/8" Production hole section F/ 12,318.0 12,452.0 00:00 06:00 12,318' MD - T/12,452' MD, 3,939' TVD 250 gpm, 2,585 psi. 18% flow out. 150 rpm, 8k Torque, 4k bit M. ECD's 12.19 ppg. off bottom psi=2,580. Up143 k,down73 k, rot 104 k.8.5 kTorque off bottom, Gas units = 60 ADT - 4.86, Bit hrs. 21.19, jar hrs. - 36.7 8/1/2018 8/1/2018 6.00 PRODS DRILL DDRL X Drill 6-1/8" Production hole section F/ 12,452.0 12,900.0 06:00 12:00 12,452' MD - T/12,900' MD, 4,128' TVD 250 gpm, 2,765 psi. 18% flow out. 150 rpm, 8 k Torque, 4k bit wt. ECD's 12.60 ppg. off bottom psi=2,755. Up152 k,down 83 k, rot 108 k.8 kTorque off bottom, Gas units = 238 ADT - 4.32, Bit hrs. 25.51, jar hrs. - 41.02 SPR's @ 12,489' MD 3,949' TVD MW - 9.2+ ppg MP # 1) 20 spm = 810 30 spm = 1,060 MP # 2) 20 spm = 800 30 spm = 1,020 16 bbl. loss this tour. 8/1/2018 8/1/2018 3.25 PRODS DRILL DDRL X Drill 6-1/8" Production hole section F/ 12,900.0 13,080.0 12:00 15:15 12,900' MD - T/13,080' MD, 4,233' TVD 250 gpm, 2,950 psi. 18% flow out. 150 rpm, 8k Torque, 10 k bit wt. ECD's 12.58 ppg. off bottom psi=2,930. Up164 k,down 89 k, rot 113 k.8 kTorque off bottom, Gas units = 175 ADT - 1.82, Bit hrs. 27.33, jar hrs. - 42.84 MP # 1) 20 spm = 880 30 spm = 1,160 MP # 2) 20 spm = 900 30 spm = 1,170 8/1/2018 8/1/2018 0.25 PRODS CASING CIRC X Obtain final survey, Take Slow pump 13,080.0 13,080.0 15:15 15:30 rates, Obtain torque and drag data. 8/1/2018 8/1/2018 1.00 PRODS CASING CIRC X Lay down single drillpipe not in string, 13,080.0 13,040.0 15:30 16:30 Circulate while rotating & reciprocating FI 13,080' MD - T/ 13,010' MD, 250 gpm, 2,780 psi, 18% flow out, ECD's = 12.39 ppg. 150 rpm, 7 k. torque, 3,144 total strokes pumped. Lay down 2 joints drillpipe not in string. 8/1/2018 8/1/2018 0.50 PRODS CASING UW -FF X Monitor well for flow (Static) 13,040.0 13,040.0 16:30 17:00 8/1/2018 8/112018 4.50 PRODS CASING BKRM X Backream out of hole racking back 13,040.0 11,570.0 17:00 21:30 HWDP and laying down drillpipe to pipeshed. F/13,040'MD - T/ 11,570 MD, 250 gpm,2,390 psi. 17% flow out, ECD's = 11.65 ppg, 150 rpm, 6.5 k torque, up 130 k, Down 70 k. Obtained surveys at pre -determined depths per SLB. Page 31135 Report Printed: 8/1012018 4- Operations Summary (with Timelog Depths) 11-1-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time 8/1/2018 End Time 8/2/2018 Dur(hr) 2.50 Phase PROD3 Op code Activity Code Time P-T-Xstart Operatpn Depth (flKe) End Depth flKS) 21:30 00:00 CASING BKRM X Continue backreaming out of hole 11,570.0 10,626.0 laying down drillpipe to pipeshed. F/ 11,570' MD - T/10,626' MD. 250 gpm, 2,330 psi. 18% flow out, ECD's = 11.62 ppg. 150 rpm, 6 k. Torque, Up 124 k. Down 75 k. SPR's @ 13,080.' MD 4,233' TVD MW -9.2+ ppg MP # 1) 20 spm = 880 30 spm = 1,160 MP # 2) 20 spm = 900 30 spm = 1,170 Mud losses this tour 7 bbls. 8/2/2018 00:00 8/2/2018 5.25 PROTCA BKRM X Back ream out of hole F/10,626' MD - 10,626.0 8,500.0 05:15 T/8,500' MD, 250 gpm,2,085 psi,18°k Flow out. 150 rpm,4.3 k, Torque. ECD's 11.16 ppg. Up 114 k. Down 89 k. 18 8/2/2018 1.25 PROCIRC X Circulate at shoe, Rotate & 8,500.0 8,490.0 05:15 05:15 06:30 Reciprocate F/8,490' MD -T/ 8,435' MD. 250 gpm, 2,085 psi. 17% flow out, 120 rpm, 4 k, Torque. ECD's 11.03 ppg. Up 113 k, Down 89 k. 8/2/2018 06:30 8/2/2018 0.25 PROD3 TASING CASINGOWFF X Lay down stand #86, Drop 2.0" rabbit 8,490.0 8,442.0 06:45 W/110' wire, Monitor well for 10 min. (Static) 8/2/2018 06:45 8/2/2018 1.00 PROD3 CASING TRIP X Pull out of hole on elevators F/8,442' 8,442.0 7,491.0 07:45 MD - T/7,49V MD. Laying down drillpipe to pipeshed. Monitor hole fill via trip tank, Calculated 5.5 bbls. Actual 5.3 bbls. up 113 k, down 87 k. 8/2/2018 07:45 8/2/2018 0.50 PROD3 CASING CIRC X Pump 20 bbl. dry job, Blow down 7,491.0 7,491.0 08:15 topdrive. 8/2/2018 8/2/2018 3.00 PRODS CASING TRIP X Pull out of hole on elevators, Lay 7,491.0 365.0 08:15 11:15 down drillpipe to pipeshed F/7,491' MD - T/ 7,206' MD. Continue tripping out of hole racking pipe in derrick F/7,206' MD - T/365' MD. Rabbit recovered at top of jars. Monitor hole fill via trip tank. 8/2/2018 11:15 8/2/2018 0.75 PROD3 CASING BHAH X Monitor well 10 min. (Static) Lay down 365.0 140.0 12:00 BHA F/ 365' MD - T/140' MD Monitor well via trip tank. 8/2/2018 8/2/2018 1.00 PRODS CASING BHAH X Lay down remainder of BHA, F/140' 140.0 0.0 12:00 13:00 MD. 8/2/2018 8/2/2018 0.50 COMPZN CASING SHAH X Clear and Clean floor, Drain BOP 0.0 0.0 13:00 13:30 Stack. 8/2/2018 8/2/2018 0.25 COMPZN CASING RURD X Pull wear -bushing. 0.0 0.0 13:30 13:45 8/2/2018 8/2/2018 1.00 COMPZN CASING W W WH X Makeup sub to wash BOP Stack to 4" 0.0 0.0 13:45 14:45 drillpipe, Flush stack at 825 gpm, Lay down wash sub, Blow down topddve, Drain stack. 18 18 0.75 COMPZN CASING RURD X Set test plug W/4-1/2" test joint. Rig up 0.0 0.0 14:45 14:a5 15:30 15:30 test equipment, Flush lines. Page 32135 Report Printed: 8/10/2018 Gperations Summary (with Timelog Depths) 1H-108ip Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan nme End Time Dw (hn Phase Op cede Activity Code Time P -T -X Operation Stan Depth (PKB) End Depth (aKB) 8/2/2018 8/2/2018 5.00 COMPZN WHDBOP BOPE X Test BOPE. Tested 250 psi low & 0.0 0.0 15:30 20:30 3,500 psi hiigh 5 min. per test all tests charted. Super and manual operated chokes tested to 2 k. Tested with 3-1/2" & 4-1/2" Test joints. Tested -Annular, lower pipe rams, Blind rams, Choke valves 1-14, HCR & Manual choke & kill, Mezzanine kill line valves, Upper & lower IBOP, 4" XT -39 Dart & TIW, Koomey drawdown initial accumulator pressure -2,900 psi. After function = 1,700 psi. 200 psi build 8 sec, Full system recovery 57 sec. 6 nitrogen bottle average 1,937 psi. Test PVT's & Methane, H2S alarms. Test witnessed by AOGCC rep Austin McLeod. Testing complete 20:30 8/3/2018. 8/2/2018 8/2/2018 0.25 COMPZN WHDBOP BOPS X Pull test plug, Set Wear ring (9" ID) 0.0 0.0 20:30 20:45 8/2/2018 8/2/2018 1.25 COMPZN CASING RURD X R/U to run 4-1/2" Lower completion 0.0 0.0 20:45 22:00 liner, Verify tally. 8/2/2018 8/3/2018 2.00 COMPZN CASING PUTS X Run in hole with 4-1/2"12.6 ppf L-80 0.0 1,182.0 22:00 00:00 IBT-M liner per detail T/1, 182' MD. Monitor displacement visa trip tank, Install 5.88 OD Hyd Centralizers per tally. Up 54 k. down 58 k. 8/3/2018 8/3/2018 4.25 COMPZN CASING PUTB X Continue running in hole with 4-1/2" 1,182.0 4,730.0 00:00 04:15 Lower compleflon per tally, F/1, 182'MD - T/4,730' MD. Install 97 hyd centalizers 5.88 OD, Up 81 k. down 71 k. Monitor displacement via trip tank. 8/3/2018 8/3/2018 1.25 COMPZN CASING OTHR X Make up seal bore assembly and 4,730.0 4,809.0 04:15 05:30 hanger per baker rep. to 4,809' MD Up 83k, down 73k. 8/3/2018 8/3/2018 0.50 COMPZN CASING CIRC X Pick up crossover and 1 stand 4" 4,809.0 4,809.0 05:30 06:00 drillpipe, Circulate to ensure flow path clear. 4 bpm. - 160 psi. 10% flow out. 8/3/2018 8/3/2018 0.75 COMPZN CASING RUNL X Run in hole with 4-1/2" Lower 4,809.0 5,854.0 06:00 06:45 completion liner on 4" drillpipe, F/4,904' MD - T/5,854' MD. Down 85k. Displacement monitored via trip tank. 813/2018 8/3/2018 0.50 COMPZN CASING SVRG X Service ST -100 Iron Roughneck. 5,854.0 5,854.0 06:45 07:15 8/3/2018 8/3/2018 1.25 COMPZN CASING RUNL X RIH with 4-1/2" Lower completion liner 5,854.0 7,175.0 07:15 08:30 on 4" drillpipe, F/5,854' MD - T/7,175' MD. Displacement monitored via trip tank. 8/3/2018 8/3/2018 0.25 COMPZN CASING CIRC X Fill pipe staging pumps up to 4 bpm. 7,175.0 7,175.0 08:30 08:45 364 psi, 12% flow out, up 103k, down —0 80k. 8/3/2018 8/3/2016 75 COMPZN CASING RUNL X RIH with 4-1/2" Lower completion liner 7,175.0 8,500.0 08:45 09:30 on 4" drillpipe, F/7,175' MD - T/8,500' MD. —0 Displacement monitored via trip tank. 8/312018 8/3/2018 50 COMPZN CASING CIRC X Circulate drillpipe volume staging 8,500.0 8,500.0 09:30 10:00 pump up to 4 bpm. 410 psi,12%flow out, 110k up, 79k down 8/3/2018 8/3/2018 2.00 COMPZN CASING RUNL X Run in open hole with 4-1/2" Lower 8,500.0 11,360.0 10:00 12:00 completion liner on 4" drillpipe, F/8,500' MD - T/11,360' MD. Displacement monitored via trip tank. 131k up 70k down. Page 33135 ReportPrinted: 8110120181 Operations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siert Time Ertl TimeDur(hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (rt KB) End Depth (WB) 8/3/2018 8/3/2018 2.25 COMPZN CASING RUNL X Run in open hole with 4-1/2" Lower 11,360.0 13,060.0 12:00 14:15 completion liner on 4" drillpipe, F/11,360' MD - T/13,082' MD. Space out liner hanger w/Shoe atl3,060' MD. 163k up 84k down. Displacement monitored via trip tank. 8/3/2018 8/3/2018 1.00 COMPZN CASING CIRC X Circulate 80 WIS.- drillpipe volume, 13,060.0 13,060.0 14:15 15:15 Stage up to 4 bpm. 789 psi,11 %flow Put, 819 total strokes. 8/3/2018 8/3/2018 1.25 COMPZN CASING HOSO X Drop 1.625" setting ball, pump down 13,060.0 13,060.0 15:15 16:30 @ 3 bpm. 610 psi. 12% flow out, reduce to 1 bpm, 390 psi, ball on seal 659 strokes, Set hanger per baker rep increasing pressure to 1,900 psi. Slack off attempt to set hanger twice,lncrease pressure to 2,135 psi. setting hanger with 48k down, increase pressure to 2,400 psi. for min. setting packer, increase pressure to 4,200 psi. releasing HRDE, bleed pressure, pick up 7' up wt. 123k. 4- 1/2" Lower completion slotted liner shoe set at 13,060.14' MD TOL at 8,264.72'. 7" shoe @ 8508.85', 244.13' lap. 8/3/2018 8/3/2018 0.75 COMPZN CASING PRTS X Perform packer test 3,400 psi- 30 min. 13,060.0 13,060.0 16:30 17:15 charted test. Pumped down IA With annular closed and drillpipe open. 8/3/2018 8/3/2018 1.75 COMPZN WELLPR DISP X Pick up additional 6'- pump 30 bbl. 13,060.0 8,239.0 17:15 19:00 spacer, Start displacement over to 9.2 ppg kill wt. brine, at 3 bpm. pump 102 bbl's. and pick up out of liner top to 8,239' MD. Increase pump rate to 12 bom. 3,200 psi. 3,900 total strokes pumped. 8/3/2018 8/3/2018 0.50 COMPZN WELLPR OWFF X Monitor well for flow (Static) 8,239.0 8,239.0 19:00 19:30 8/3/2018 8/3/2018 1.00 COMPZN WELLPR SLPC X Slip and cut 88' of drilling line. 8,239.0 8,239.0 19:30 20:30 8/3/2018 8/4/2018 3.50 COMPZN WELLPR TRIP X TOOH laying down 4" drillpipe to 8,239.0 4,409.0 20:30 00:00 pipeshed. F/ 8,239' MD - T/4,409' MD. 8/4/2018 8/4/2018 3.50 COMPZN WELLPR TRIP X TOOH Laying down 4" drillpipe F/ 4,409.0 0.0 00:00 03:30 4,490' MD to surface. 8/4/2018 8/4/2018 0.25 COMPZN WELLPR BHAH X Lay down baker liner running tool. 0.0 0.0 03:30 03:45 8/4/2018 8/4/2018 1.25 COMPZN WELLPR WWWH X Pull wear bushing, Clean BOP stack 0.0 0.0 03:45 05:00 with flushing tool. 8/4/2018 8/4/2018 1.50 COMPZN RPCOMP RURD X Rig up to run 3-1/2" Tubing upper 0.0 0.0 05:00 06:30 completion. Verify tubing tally & count. PJSM 8/4/2018 8/4/2018 5.50 COMPZN RPCOMP PUTB X Make up seal assembly, RIH with 3- 0.0 4,492.0 06:30 12:00 1/2" 9.3 ppf. L-80 Hyd 563 upper completion per detail to 4,492' MD. Connections torqued to 2,900 fUlbs. Disp monitored via trip tank Up 70 k. down 66 k. 8/4/2018 8/4/2018 5.00 COMPZN RPCOMP PUTB X RIH with 3-1/2" 9.3 ppf. L-80 Hyd 563 4,492.0 8,223.0 12:00 17:00 upper completion per detail F/4,492' MD -T/8,223' MD. Disp monitored via trip tank Up 84 k. down 61 it. 8/4/2018 8/4/2018 0.50 COMPZN RPCOMP PUTB X RIH with joints 259 through 262, Tag 8,223.0 8,326.0 17:00 17:30 no go at 8,326.51 MD. Lay down joint #262 Page 34/35 Report Printed: 8/10/2018 ■ operations Summary (with Timelog Dt+pths) IH -108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sled Time End Time our (m) phase Op Code Aemnly Code Time P -T -X Operation Stan Depth (M1KB) End Depth(%KB) 8/4/2018 8/4/2018 1.75 COMPZN RPCOMP CRIH X Make up crossover, Pick up to 8,270' 8,326.0 8,270.0 17:30 19:15 MD. Pump 161 bbl's. corrosion inhibited brine at 3 bpm, 190 psi. 7% flow out. Spot inhibited brine with 82 bbl's 9.2 ppg. brine. 8/4/2018 8/4/2018 1.25 COMPZN RPCOMP HOBO X Lay down 3 joints, (161-159) Pickup 8,270.0 8,324.0 19:15 20:30 space out pups. 3.8579.8479.85'- 1.33' crossover, Joint 4-1/2"Hyd 563 tubing 38.07' pup 3.05 & hanger, Make up to landing joint and land hanger at 8,324.37' MD. 86 k up 61 k down 2.25' off fully located. 8/4/2018 8/4/2018 1.25 COMPZN RPCOMP W WSP X Rig up and test hanger seals 5,000 psi 8,324.0 8,324.0 20:30 21:45 upper and lower tests. Test good. 8/4/2018 8/4/2018 1.25 COMPZN RPCOMP PRTS X Rig up and test IA and hanger. 1,500 8,324.0 8,324.0 21:45 23:00 psi F/10 min. 21 strokes. Pump up to 2,000 psi F/30 min 25 strokes, Pressure up to 2,787 psi to shear SOV, 32 strokes. 3 bbl's received on bleed back 8/4/2018 8/5/2018 1.00 COMPZN WHDBOP NUND X Remove flow riser, Choke and kill 8,324.0 0.0 23:00 00:00 hoses, Unbolt BOPE flanges. 8/5/2018 8/5/2018 1.00 COMPZN WHDBOP NUND X Set back BOP Stack, Remove Spacer 0.0 0.0 00:00 01:00 1 spools. 8/5/2018 8/5/2018 3.00 COMPZN WHDBOP NUND X Nipple up Tree, Install test dart, Test 0.0 -0.0 01:00 04:00 hanger void 5 k. 15 min. Test tree body 5 k. 15 min. (Charted) Remove test dart and BPV. 8/5/2018 8/5/2018 3.75 COMPZN WHDBOP FRZP 37— Rig up and pump 93 bbls. diesel 0.0 0.0 04:00 07:45 freeze protect. with Little Red Services. Pump down IA returns up tubing to open top tank holding back pressure with choke skid. Rate .8 bpm, 2,000 psi. Shut in tubing 220 psi. Blow down and rig down. OA= 140 psi. 8/52018 8/5/2018 1.25 DEMOB MOVE RURD X Secure tree and Cellar. OA= 140 psi, 0.0 0.0 07:45 09:00 I IA = 0.0 psi. TBG = 200 psi. Release Rig (off 09:00 Page 35135 Report Printed: 811012018 NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H -108A ConocoPhillips Definitive Survey Report 05 July, 2018 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. Yes n No 1 have checked to the best of my ability that the following data is correct: C Surface Coordinates (71 Declination & Convergence O GRS Survey Corrections [i OlgiullyvgnW by Viiwc. Dara Survey Tool Codes n-ScHumox Vincent Osa ra �Schumcerr,im, ger, ema=rosara;al, cm c_ -US SLB DIE : Date. 10180. loos. 183aL iy) Nick Lehman Digitally sig neb by Nick Lehman Client Representative: Date: 2018.07.f917:0527-oe on Date: ConocoPhillips Schlumberger Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 11-1-108 Project: Kuparuk River Unit TVD Reference: 1 H-108 actual @ 92.99usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-108 actual @ 92.99usft (Doyon 142) Well: 11-1-108 North Reference: True Wellbore: 1H -108A Survey Calculation Method: Minimum Curvature Design: 11-1-108A Database: OAKEDMP2 roject Kuparuk River Unit, North Slope Alaska, United States lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level ;so Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zona: Alaska Zone 04 Using geodetic scale factor well 1 H-108 Audit Notes: Well Position +NIS 0.00 usft Northing: 5,980,752.52 usft Latitude: 70° 21'29.515 1 ACTUAL +E/ -W 0.00 usft Easting: 549,570.98 usft Longitude: 149° 35'50.595 V 'osItion Uncertainty Direction 0.00 usft Wellhead Elevation: usft Ground Level: 54.00 usf Velltrore 11-1-108A 8egnetics Model Name Sample Date Declination Dip Angle FkrM Strength (') (1) W) BGGM2017 6/1/2018 17.08 80.93 57,468 Design 1H -108A Date Audit Notes: From To Map Version: 1.0 Phase: ACTUAL Tie On Depth: 1,847.94 Vertical Section: Depth From (TVD) -NIS +E/ -W Direction Gyrodata gyro single shots (usft) (usft) (usft) Cl MWD+IFR-AK-CAZSC 38.99 0.00 0.00 111.60 Survey Program Date From To Map Vertical MD (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 120.48 1,266.38 1H-108 Srvy 1 - SLB _GWD70 (1 H-108) GYD-GC-SS Gyrodata gyro single shots 6/16/2018 8:51: 1,361.99 1,750.031H-108 Srvy 2-SLB_MWD+GMAG(1 H- MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 6/16/2018 8:54:' 1,847.94 1,847.941H-108 Srvy 3- SLB _MWD+GMAG(1H- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/19/2018 8:55:' 1,939.54 2,039.471H -108A Srvy 1-MWD4nc-Only(1 H-108 MWD-INC_ONLY MWD-INC_ONLY_FILLER 6/25/2018 8:22:- 2,047.56 9,177.371H -108A Srvy 2-MWD+IFR-AK-CAZSC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/25/2018 8:27:' Survey 7/5/2018 9:08:20AM Page 2 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azl TVD TVDSS +NIS +FJ -W Northing Easting DLS Section (usft) (-) (-) (usft) (-It) (usft) (uslt) (to (to (-1100') (It) Survey Tool Name 38.99 0.00 000 3899 54.00 0.00 0.00 5,980,752.52 549,570.98 0.00 0.00 UNDEFINED 120.48 0.15 315.17 120.48 27.49 0.08 -0.08 5,980,752.60 549,570.90 0.18 -0.10 GYD-GCSS(1) 147.84 0.08 176.35 147.84 54.85 0.08 4).10 5,980,752.60 549,570.88 0.79 -0.12 GYD-GCSS(1) 239.63 0.20 174.22 239.63 146.64 -0.14 -0.08 5.9W,752.38 549,570.90 0.13 4).02 GYD-GC-SS(1) 336.20 0.12 174.23 336.20 243.21 -0.41 -0.05 5,980,752.11 549,570.93 0.08 0.10 GYD-GC-SS(1) 429.26 1.29 146.15 429.25 336.26 -1.38 0.54 5,980,751.15 549,571.53 1.27 1.01 GYD-GCSS(1) 519.62 1.88 132.82 519.58 426.59 5.23 2.20 5,980,749.31 549,573.20 0.77 3.23 GYDGCSS(1) 610.87 2.81 12522 610.75 517.76 -5.54 5.12 5,980,747.02 549,576.14 1.07 6.80 GYD-GC-6S(1) 700.99 4.86 123.76 700.66 607.67 5.93 10.10 5,980,743.65 649,581.14 2.28 12.68 GYD-GC-SS(1) 79146 7.14 120.25 790.65 697.66 -13.90 18.15 5,980,738.75 549,589.21 2.55 21.99 GYD-GC-SS(1) 7/5/2018 9:08:20AM Page 2 COMPASS 5000.14 Build 85 Schlumberger Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 1H-108 Project: Kuparuk River Unit TVD Reference: 1H-108 actual @ 92.99usfl (Doyon 142) Stte: Kuparuk 1 H Pad MD Reference: 1 H-108 actual @ 92.99usft (Doyon 142) Well: 1H-108 North Reference: True Wellbore: 1 H-1 08A Survey Calculation Method: Minimum Curvature Design: 1H -108A Database: OAKEDMP2 Survey 1,834.00 29.50 121.43 1,767.10 1,674.11 -201.99 308.89 5,980,552.60 549,881.17 Map Map NOT an Actual Survey Vertical MD Inc AZI TVD TVDSS +NIS +El -W Northing Easting DLS Section (USM P) P) (usR) (usft) (usN) (usft) (}t) tft) (°11001 (N) Survey Tool Name 886.41 10.45 122.90 884.45 791.46 -21.55 30.47 5,980,731.18 549,601.59 3.51 36.26 GYD-GCSS(1) 981.60 12.58 121.52 977.72 884.73 51.66 46.56 5,980,721.18 549,617.74 2.26 54.94 GYD-GC.SS 0) 1,077.17 14.17 121.38 1,070.70 977.71 43.19 65.42 5,980,709.77 549,636.68 1.66 76.72 GYD-GC-SS(1) 1,171.65 15.91 122.81 1,161.94 1,068.95 56.23 86.18 5,980,696.B7 549,657.52 1.88 100.83 OYD-GC-SS(1) 1,266.38 18.99 124.39 1,252.30 1,159.31 -71.97 109.82 5,980,681.28 549,681.26 3.29 128,60 GYD-GCSS(1) 1,361.99 21.79 123.25 1,341.91 1,248.92 -90.49 137.50 5,980,662.95 549,709.06 2.96 161.15 MWD+IFR-AK-CAZ-SC (2) 1,422.20 23.55 123.41 1,39746 1,304.47 -103.24 156.99 5,980,650.33 549,728.53 2.92 183.87 MWD+IFR-AK-CAZSC(2) 1,516.33 25.66 123.18 1483.04 1,390.05 -124.76 189.65 5,980,629.03 549,761.43 2.24 222.25 MWD+IFR-AK-CAZSC(2) 1,611.98 25.72 122.60 1,569.24 1,476.25 -147.27 224.46 5,98,606.75 549,796.39 0.27 262.91 MW0+IFR-AK-CAZ-SC (2) 1,707.27 26.11 123.45 1,654.94 1,561.95 -169.97 259.38 5,980,5134.29 549,831.45 0.57 303.73 MWD+IFR-AK-CAZ-SC (2) 175nM 7717 17375 1693.17 1.600.18 -180.57 275.33 5,98,573.79 549,847.48 2.3B 322.47 MWD+IFR-AK-CAZSC(2) 1,834.00 29.50 121.43 1,767.10 1,674.11 -201.99 308.89 5,980,552.60 549,881.17 3.12 361.56 NOT an Actual Survey 10 3W x 13 112" 413.32 MWD -INC ONLY(4) 2,039.47 33.81 128.13 1,943.24 1,850.25 -261.91 395.86 1,847.94 29.90 121.08 1,779.21 1,686.22 -205.57 314.60 5,980,549.05 549,887.10 3.12 368.36 MWD IFR-AK-CAZ SC 1,939.54 30.19 124.64 1,858.50 1,765.51 -230.45 353.30 5,980,524.43 549,925.77 1.97 413.32 MWD -INC ONLY(4) 2,039.47 33.81 128.13 1,943.24 1,850.25 -261.91 395.86 5,980,493.26 549,968.53 4.07 464.48 MWD -INC _ONLY W Side 2,047,56 33.95 128.39 1,949.96 1,856.97 -264.71 399.40 5,980,490.49 549,972.09 2.49 468.80 MWD+IFR-AK-CAZ-SC(5) track 2,142.9 38.68 130.49 2,026.11 1,933.12 500.30 442.58 5,980,455.18 550,015.50 5.17 522.05 MWD+IFR-AK-CAZSC(5) Pt 2,237.17 43.07 131.63 2,097.99 2,005.00 -341.18 489.47 5,980,414.62 550,062.65 4.68 580.69 MWD+IFR-AK-CAZSC(5) 2,332.49 45.77 133.31 2,166.06 2,073.07 586.24 538.66 5,980,369.89 550,112.13 3.09 643.01 MWD+IFR-AK-CAZ-SC(5) 2,428.06 49.15 134.12 2,230.67 2,137.68 43.90 589.54 5,980,321.57 55,163.32 3.59 708.22 MWD+IFR-AK-CAZSC(5) 2,523.51 52.64 134.30 2,290.86 2,197.87 486.54 642.62 5,980,270.29 550,216.74 3.66 776.59 MWD+IFR-AK-CAZSC(5) 2,618.92 55.46 134.39 2,346.87 2,253.88 540.53 697.85 5,980,216.68 550,272.32 2.96 847.81 MWD+IFR-AK-CAZ-SC(5) 2,712.87 58.18 134.64 2,398.28 2,305.29 595.65 753.91 5,980,161.93 550,328.74 2.90 920.23 MWD+IFR-AK-CAZSC(5) 2,807.95 61.56 133.58 2,446.00 2,353.01 552.87 812.95 5,980,105.11 550,388.16 3.68 99648 MWD+IFR-AK-CAZSC(5) 2,902.77 64.67 134.85 2,488.88 2,395.89 -711.85 873.55 5,98,046.54 550,449.14 3.49 1,074.24 MWD+IFR-AK-CAZ-SC(5) 2,997.71 68.39 135.78 2,526.68 2,433.69 -773.76 934.77 5,979,985.04 550,510.76 4.02 1,153.95 MWD+IFR-AK-GAZSC(5) 3,092.73 71.21 136.29 2,559.49 2,466.50 537.94 996.67 5,979,921.28 550,573.07 3.01 1,235.12 MWD+IFR-AK-CAZSC(5) 3,187.86 73.20 138.20 2,588.56 2,495.57 -904.45 1058.15 5,979,855.18 550,634.99 2.83 1,316.76 MWD+IFR-AK-CAZ-SC (5) 3,282.93 75.97 141.06 2,613.84 2,520.85 -974.27 1,117.49 5,979,785.76 550,694.78 4.11 1,397.64 MWD+IFR-AK-CAZSC(5) 3,378.11 75.85 141.77 2.637+01 2,544.02 -1,046.43 1,175.6 5,979,713.99 550,752.83 0.73 1,477.73 MWD+IFR-AK-CAZSC (5) 3,472.89 75.88 141.80 2,650.16 2,567.17 -1,118.64 1,231.92 5,979,642.16 550,810.15 0.04 1,557.18 MWD+IFR-AK-CAZ-SC(5) 3,568.18 75.94 140.49 2,683.35 2,590.36 -1,190.61 1,2B9.90 5,979,570.58 55,868.60 1.33 1,637.58 MWD+IFR-AK-CAZSC(5) 303.55 76.06 139.39 2,706.43 2,613.44 -1,261.44 1,349.45 5,979,500.16 550,928,62 1.13 1,719.02 MWD+IFR-AK-CAZ-SC(5) 3,758.79 75.99 139.22 2,729.43 2,636.44 -1,331.51 1,409.71 5,979,430,50 550,989.34 0.19 1,800.84 MWD+IFR-AK-CAZSC(5) 3,853.85 76.32 138.63 2,752.17 2,659.18 -1,401.09 1,470.36 5,979,361.33 551,050.44 0.70 1,882.84 MWD+IFR-AK-CAZ-SC (5) 3,948.74 75.88 137.92 2,774.97 2,681.98 -1,469.83 1,531.66 5,979,293.00 551,112.19 0.86 1,965.14 MWD+IFR-AK-CAZ-SC(5) 4,047.65 77.55 137.15 2,797.70 2,704.71 -1,540.84 1,596.65 5,979,222.43 551,177.64 1.85 2,051.71 MWD+IFR-AK-CAZ-SC(5) 4,138.48 76.36 134.63 2,816.20 2,725.21 -1.604.37 1,658.23 5,979,159.31 551,239.63 3.00 2,132.35 MWD+IFR-AK-CAZSC(5) 4,233.36 75.00 133.05 2,841.67 2,748.68 -1,668.05 1,724.53 5,979,096.OB 551,306.35 2.16 2,217,43 MWD+IFR-AKCAZSC(5) 4,328.88 73.23 130.70 2,867.82 2,774,83 -1,729.37 1,792.93 5,979,035.22 551,375.14 3.01 2,303.60 MWD+IFRAK-CAZSC(5) 7/52078 9:08:20AM Page 3 COMPASS 5000.14 Build 85 Company Project: Site: Well: Wellbore: Design: Survey NADConversion Kupamk River Unit Kuparuk 1H Pad 1H-108 1H -108A 1H -108A MD Inc (uaft) (°) 4,423.92 71.95 4,518.75 70.71 4,613.89 70.61 4,709.08 70.36 4,805.07 70.12 4,900.14 69.70 4,995.06 69.29 5,090.59 69.02 5,195.46 68.85 5,280.50 68.44 5,375.86 67.91 5,470.74 67.65 5,566.59 65.98 5,661.35 66.47 5,756.42 65.78 5,851.31 65.95 5,946.45 65.71 6,041.49 65.89 6,136.54 65.93 6,231.15 66.03 6,326.12 65.90 6,421.38 66.04 6,516.50 65.06 6,611.96 65.93 8706.71 64.93 6,801.91 64.74 6,897.52 64.35 6,993.17 64.37 7,088.65 66.19 7,183.55 6801 7,279.08 70.67 7,374.54 75.23 7,469.54 81.13 7,564.85 85.42 7,659.34 87.73 7,754.17 88.26 7,849.39 88.32 7,945.02 91.98 8,039.77 92.06 8,134.65 9340 7/5/2018 9:08'20AM Azi 127.57 126.63 125.% 124.81 122.51 120.28 118.51 116.18 116.21 115.37 114.67 112.98 112.23 108.98 107.03 104.86 100.62 95.73 95.52 95.73 99.93 94.20 92.40 92.01 91.91 91.43 91.52 89.37 88.55 86.54 88.27 88.91 91.48 92.03 91.58 91.22 88.44 89.67 88.38 89.97 Schlumberger Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1H-108 1 H-108 actual ® 92.99usft (Doyon 142) IH -108 actual Q 92.99usft (Doyon 142) True Minimum Curvature OAKEDMP2 Map Map Vertical TVD TVDSS +N/.S +E/ -W Northing Easgng OLS Section (usft) (usft) (usft) (usft) (ft) (ft) ("/100') (ft) Survey Tool Name 2,896.26 2,803.27 -1,786.61 1,863.25 5978,978.46 551,445.83 3.42 2,390.05 MWD+IFRAK-0AZ-SC(5) 2,926.62 2,833.63 -1,840.80 1,934.90 5,978,924.75 551,517.83 1.61 2,476.62 MWD+IFR-AK-CAZSC(5) 2,958.13 2,865.14 -1,893.94 2,007.26 5,978,872.09 551,590.53 0.67 2,563.45 MWD+IFRAK-CAZSC (5) 2,989.93 2,896.94 -1,945.89 2,080.40 5,978,820.63 551,664.01 1.17 2,650.58 MWD+IFRAK-CAZ-SC (5) 3,022.38 2,929.39 -1,995.96 2,155.59 5,978,771.06 551,739.52 2.27 2,738.92 MWD+IFR-AK-CAZSC(5) 3,055.04 2,962.05 -2,042.47 2,231.79 5,978,725.06 551,816.02 2.25 2,826.89 MWD+IFR-AKLAZSC(5) 3,088.29 2,995.30 -2,086.11 2,309.25 5,978,681.94 551,893.76 L80 2,914.97 MWD+IFRAK-CAZ-SC (5) 3,122.29 3,029.30 -2,127.11 2,388.54 5,978,641.47 551,973.31 2.30 3,003.79 MWD+IFRAK-CAZSC(5) 3,156.39 3,063.40 -2,166.19 2,467.98 5,978,602.92 552,053.00 0.18 3,092.04 MWD+IFR-AK-CAZSC(5) 3,191.00 3,098.01 -2,204.70 2,547.68 5,978,564.94 552,132.94 0.93 3,180.32 MWD+IFRAK-CAZSC (5) 3,226.45 3,133.46 -2,242.15 2,627.89 5,978,528.03 552,213.40 0.88 3,268.68 MWD+IFR-AK-CAZSC(5) 3,262.33 3,169.34 -2,277.62 2,708.24 5,978,493.09 552,293.97 1.67 3,356.45 MWD+IFRAK-CAZSC(5) 3,299.30 3,206.31 -2,311.62 2,789.88 5,978,459.64 562,375.82 1.00 3,444.87 MWD+IFR-AK-CAZSC(5) 3,336.75 3,243.76 -2,342.25 2,871.34 5,978,429.55 552,457.48 3.20 3,531.89 MWD+IFRAK-CAZSC(5) 3,375.23 3,282.24 -2,369.12 2,954.01 5,978,403.23 552,540.32 2.01 3,618.64 MWD+IFR-AK-CAZSC(5) 3,414.04 3,321.05 -2,392.91 3,037.27 5,978,379.99 552,623.72 2.09 3,704.81 MWD+IFRAK-CAZ-SC (5) 3453.01 3,360.02 -2,412.05 3,121.91 5,978,36142 .552,708.48 4.07 3,790.55 MWD+IFRAK-CAZSC(5) 3,491.98 3,398.99 -2,425.12 3,207.58 5,978,348.92 552,794.23 3.74 3,875.02 MWD+IFR-AK-CAZSC(5) 3,530.78 3,437.79 -2,434.38 3,293.85 5,978,340.23 552,880.55 1.16 3,958.64 MWD+IFR-AK-CAZ-SC(5) 3,559.29 3,476.30 -2,442.85 3,379.86 5,978,332.33 552,966.60 0.23 4,041.73 MWD+IFR-AK-CAZSC(5) 3,607.97 3,514.98 -2,450.90 3,466.22 5,978,324.85 553,053.00 0.78 4,124.99 MWD+IFR-AK-CAZSC(6) 3,646.76 3,553.77 -2,457.83 3,552.94 5,978,318.50 553,139.76 0.72 4,208.18 MWD+IFRAK-CA7-SC(5) 3,686.13 3,593.14 -2,462.82 3,639.38 5,978,314.08 553,226.23 2.01 4,290.38 MW13+1FRAK-CAZSC(5) 3,725.73 3,632.74 -2,466.16 3,726.18 5,978,311.31 553,313.03 098 4,372.32 MWD+IFR-AK-CAZSC(5) 3,765.12 3,672.13 -2,469.11 3,812.30 5,978,308.94 553,399.16 1.05 4,453.48 MWD+IFR-AK-CAZ-SC(5) 3,805.60 3,712.61 -2,471.62 3,898.43 5,978,306.99 553,485.30 0.50 4,534.48 MWD+IFR-AK-CAZ-SC(5) 3,846.70 3,753.71 -2,473.84 3,984.72 5,978,305.34 553,571.60 0.42 4,615.54 MWD+IFRAK-CAZSC(5) 3,888.09 3,795.10 -2,474.51 4,070.95 5,978,305.24 553,657.82 2.03 4,695.95 MWD+IFR-AK-CAZ-SC (5) 3,928.02 3,835.03 -2,472.93 4,157.66 5,978,307.40 553,744.51 2.06 4,776.00 MWD+IFRAK-CAZSC(5) 3,964.95 3,871.96 -2,469.18 4,244.99 5,978,311.73 553,831.80 2.74 4,855.81 MWD+IFRAK-CAZSC (5) 3,998.65 3,905.66 -2,465.14 4,334.27 5,978,316.35 553,921.05 3.26 4,937.35 MWD+IFRAK-CAZ-SC(5) 4,026.63 3,933.64 -2,462.90 4,425.48 5,978,319.20 554,012.23 4.82 5,021.33 MWD+IFRAK-CAZSC(5) 4,046.09 3,953.10 -2,463.24 4,518.42 5,978,319.47 554,105.16 6.75 5,107.87 MWD+IFR-AK-CAZSC(5) 4,057.25 3,964.26 -2,466.14 4,613.01 5,978,317.20 554,199.76 4.54 5,196.88 MWD+IFRAK-CAZ-SC(5) 4,062.89 3,969.90 -2,469.11 4,707.27 5,978,314.85 554,294.03 2.49 5,285.62 MWD+IFR-AK-CAZSC(5) 4,066.21 3,973.22 -2,471.43 4,B0292 5,978,313.16 554,388.78 0.68 5,374.57 MWD+IFR-AK-CAZSC(5) 4,069.05 3,97696 -2,471.14 4,897.19 5,970,314.08 554483.93 2.92 5,462.95 MWD+IFRAK-CAZ-SC(5) 4,068.80 3,975.81 -2,469.57 4,992.78 5,978,316.29 554,579.51 4.04 5,551.26 MWD+IFRAK-CAZ-SC(5) 4,065.46 3,972.47 -2,467.96 5,087.46 5,978,318.52 554,674.17 1.36 5,638.69 MWD+IFRAKCAZ-SC(5) 4,W0.94 3,967.95 -2,466.59 5,18222 5,978,320.52 564,768.90 2.19 5,726.30 MWD+IFRAK-CAZ-SC(5) Page 4 COMPASS 5000.14 Build 85 Schlumberger Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 1H-108 Project: Kuparuk River Unit TVD Reference: 1 H-108 actual @ 92.99usft (Doyon 142) Map Kuparuk 1H Pad MD Reference: 1H-108 actual @ 92.99usft (Doyon 142) SRO: Well: 1H-108 North Reference: True TVDSS (usft) 3,960.08 3,946.80 3,931.10 3,912.77 3,888.75 IH Survey Calculation Method: Minimum Curvature Wellbors: Design: -108A 1 H -108A Database: OAKEDMP2 Survey 7/WO18 9:f/8:20AM Page 5 COMPASS 5000.14 Build 85 Map Map Vertical MD (waft) 8,229.20 8,325.02 8,419.93 8,515.09 8,610.50 Inc (1 96.15 99.78 99.27 102.94 106.23 AN P) 92.84 90.59 91.47 92.20 91.95 TVD (uaR) 4,053.07 4,039.79 4,024.09 4,005.76 3,961.74 TVDSS (usft) 3,960.08 3,946.80 3,931.10 3,912.77 3,888.75 +W -S (usft) -2,468.90 -2,471.74 -2,473.43 -2,476.41 -2,479.76 +E1 -W (usft) 5,276.39 5,371.22 5,464.81 5,558.12 5,650.38 Northing (ft) 5,978,318.83 5,978,316.61 5,978,315.55 5,978,313.18 5,978,310.45 Seating (ft) 554,863.08 554,957.92 555,051.50 555,144.83 555,237.10 OLS (°1100') 4.20 4.44 1.06 3.93 3.46 Section (ft) 5,814.71 5,903.93 5,991.56 6,079.42 6,165.44 Survey Tool Name MWD+IFR-AK-CAZSC(5) MWD+IFR-AK-CAZSC (5) MWD+1FR-AK-CAZ-SC (5) MWD+IFR-AK-CAZSC(5) MWD+IFR-AKCAZSC(5) 8,705.08 8,800.08 106.65 108.19 90.90 92.17 3,954.97 3,926.53 3,861.98 3,83354 -2,482.01 -2,484.44 5,741.07 5,831.67 5,978,308.79 5,978,306.97 555,327.79 555,418.40 1.15 2.06 6,251.59 6,335.73 MWD+IFR-AK-CAZSC (5) MWD+1FR-AKCAZSC(5) 8,894.92 8,989.59 108.47 109.04 91.55 89.73 3,896.70 3,866.26 3,803.71 3,773.27 -2,487.36 -2,488,36 5,921.65 6,011.28 5,978,304.64 5,978,30423 555,508.39 555,598.02 0.69 1.92 6,421.46 6,505.17 MWD+IFR-AK-CAZ-SC(5) MWD+IFR-AKCAZSC(5) 9,082.10 109.01 87.55 3,836.10 3,743.11 -2,486.29 6,098.71 5,978,306.89 555,685.42 2.23 6,585.70 MWD+IFR-AK-CAZ-SC(5) 9,177.37 9,245.00 108.40 WSAD 85.23 85.23 3,805.55 3,784.20 3,712.55 3,691.21 -2,480.60 -2,475.27 6,188.76 6,252.71 5,978,313.17 5,978,318.92 555,775.42 555,839.33 2.39 0.00 6,667,33 6,724.83 MWD+IFR-AKCAZSC (5) PROJECTED to TD 7/WO18 9:f/8:20AM Page 5 COMPASS 5000.14 Build 85 a Cement Detail Report 11-1-108 Job: String: Conductor DRILLING ORIGINAL, 6/41201800:00 Cement Details Description Conductor Cementing Start Date 11/6,2016 10730 Cementing End Date 11/6/2016 18:00 Wellbore Name 11H-108 Comment 10 yards (5.5 sacks) of aggregate cement poured into backside by AFC. CMT/aggregate ratio of 564/3520 per yard Cement Stages Stage 0 t Description Conductor Cement Objective 1 Top Depth (ftK8) 39.0 Bottom Depth (ftKB) 119.0 Full Return? No Vol Cement... I Top Plug? No Son Plug? No Q Pump ]nit (bbl/m...Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No I Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid TypeFluitl Conductor Cement Description Estimated Top (ftKB) 39.0 Est Bum (ftKB) 119.0 Amount (sacks) 6 Class G Volume Pumped (bbl) 60.0 Yield (ft-Isack) 2.13 Mix H2O Ratio (gallsa... 5.24 Free Water (%) 1 Density (Ib/gal) 15.00 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 ReportPrinted: 8110/2018 I Cement Detail Report 1H-108 String: Surface Casing Cement Job: DRILLING ORIGINAL, 6/4/2018 00:00 Cement Details Description Surface Casing Cement Cementing start Date 6/18/2018 11:15 Cementing End Date 6118/2018 14:15 Wellbore Name 1 H-108 Comment PJSM w/ all involved parties for cementing. Pump 5 bbls of H2O to flood lines. Test cement lines to 3500 psi, good. Pump 40 bbls of CW -100, 5 bpm, 120 psi, FO 13%. Pump 76 bbis of 10.5 ppg Mud Push II w/ red dye, 5 bpm, ICP 152 psi, FCP 130 psi, FO 16%. Drop bottom plug. Pump 328 bbis of 11 ppg Lead Cement, 6 bpm, 171 psi, FO 15%. Pump 65 bbis of 12 ppg Tail Cement, 5-6 bpm, ICP 220 psi, FCP 274 psi, FO 15%, PU 117K, SO 97K. Drop top plug. Kick out plug w/ 10 bbls of H2O. Swap to rig & pump treated 9.6 ppg mud, 7 bpm, ICP 250 psi, FCP 391 psi, FO 17%. Reciprocate rasing w/ 20 strokes throughout job & land casing on hanger w/ 1000 strokes pumped by rig pump. Slow pump rate to 3 bpm at 1300 strokes, 250 psi, FO 11%. Bump the plug with 1569 strokes, pressuring up to 750 psi. Hold pressure for 5 minutes, bleed off, & floats holding. CIP @ 14:13 hrs. Total of 84 bbis of 11 ppg lead cement back to surface. Cement Stages Stage # 1 Description Surface Casing Cement Objective Top Depth (ftKB) 43.5 Bottom Depth (ftKB) 1,840.0 Full Return?Vol No Cement... 84.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bblim... 4 Q Pump Final (bbl/... 3 Q Pump Avg (bbil... 6 P Pump Final (psi) 240.0 P Plug Bump (psi) 750.0 Recip? Yes Stroke (ft) 120.00 Rotated? I No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump 40 bbls of CW -100, 76 bbis of 10.5 ppg Mud Push II, 328 bbis of 11 ppg Lead Cement, & 65 bbis of 12 ppg Tail. Cement. Cement Fluids & Additives Fluid Fluid Type Pre Flush Fluid Description Estimated Top (ftKB) 0.0 Est Btm (ftKB) 0.0 Amount (sacks) Class Volume 40.0 Pumped (bbl) Yield (f -isack) Mix H2O Ratio (gal/sa... Free Water (%) Density (lb/gal) 8.33 Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Spacer Fluid Description Estimated Top (ftKB) 0.0 Est Btm (ftKB) 0.0 1 Amount (sacks) Class Volume 1 76.0 Pumped (bbl) Yield (ft /sack) Mix H2O Ratio (gal/ss... Free Water (°h) Density (Iblgal) 10.50 Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 43.5 Est Btm (ftKB) 1,335.0 Amount (sacks) 969 Class Volume G 328.0 Pumped (bbl) Yield (ft'/sack) 1.90 Mix H2O Ratio (gal/sa... 6.70 Free Water (%) 1 Density (Ib/gal) 11.00 Plastic Viscosity (CP) 100.7 Thickening Time (hr) CmprStr 3.75 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 1,335.0 Est Btm (ftKB) 1,840.0 Amount (sacks)Class 221 Volume G 65.0 Pumped (bbl) Yield (ft'/sack) 1.65 Mix H2O Ratio (gal/sa... 5.47 Free Water (%) 1 Density (Ib/gal) 12.00 Plastic Viscosity (cP) 100.4 Thickening Time (hr) 3.00 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Stage # 2 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? No Vol Cement... Top Plug? No Btm Plug? No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) Recip? No I Stroke (it) Rotated? No I Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Page 1/2 ReportPrinted: 8110120181 Cement Detail Report a IH-108 String: Cement Plug Job: DRILLING ORIGINAL, 6/4/2018 00:00 Cement Details Description Cementing Start Date ementing End Date 1=8 Wellbore Name Cement Plug 6/29/201810:30 6/29/201813:00 1H-108A Comment Pump 1st stage of cement plug program @ 7,497' MD. Flood all lines and PT to 3,500 PSI. Close bag and lake all returns thru choke. Pump 27 BBLS 12.5# MP2 @ 4.2 BPM 100 PSI. Balch and pump 48.3 BBLS 15.8# cement at 4.5 BPM, 100 PSI. drop wiper ball and pump 3 BBLS of MP2. Swap to rig for displacement with 82.7 BBLS LSND. Pump 4 BPM @ 220 PSI, @ 772 stks reduce rate to 2 BPM, 197 PSI. Cement wet at 1112 HRS> PJSM . RU cement hose and manifold, Close ann, open choke and pump cement plug #2. 27 BBPS 12.5# MPII @ 4.2 BPM 50-156 PSI DPP. Close choke and batch up cement. With super choke 1/2 open pump 59.5 BBLS of 15.8# class G cement. 4.7 - 4.2 BPM @ 84-111 PSI DPP. Close super choke to drop wiper ball. Pump 3 BBLS MPII spacer and I BBL water. swap to dg pumps and displace at 5 BPM, 220-250 PSI DPP. 4 BPM at 642 stks.340 PSI DPP. 2 BPM from 691 STKS at 232 FCP. Pump cement plug # 3 at 5,972' MD. MU cement hose assym and close ann taking returns through super choke and closing chokes with pumps off. Pump 27 BBLS 12.5# MPII. at 4 BPM 850 ICP, 340 FCP, Mix and pump 48.3 BBLS of 15.8#. cmt at 4 BPM. 78-230 PSI. Srop wiper ball at 160 stks. 4 BPM from 420 stks 500 PSI. reduce to 3 BPM 518 PSI FCP. 617 total stks pumped. Pump Cement plug #4 of ASI. Pump 27 BBLS of 12.7 PPG mud pushll @ 3.7 BPM 170 PSI DPP. Close bag, batch up cement system. Open Annular and pump 67.7 BBLS of 15.7# AS1 cement at 4.3 BPM 90 PSI DPP. Close bag and drop wiper ball. Pump 3 BBLS Mud pushll and one barrel fresh water. Displace cement with rig pumps of LSND at 4 BPM with last 5 BBLS being pumped at 2 BPM. 470 PSI DPP. Was able to catch cement 21 BBLS into displacement. Cement wet at 0213 hrs. RU cement head and pump KO plug. PUmp 27 BBLS of 12.5# MP @ 4.8 BPM54 PSI OPP> Gose bag and batch cement. Open bag and pup 51 BBLS of ASI 15.7# cement at 4.6 BPM 100-421 PSI DPP. close bag and drop ball. Pump 3 BBLS Mud Push II and 1 BBLS fresh water behind ball then Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Primary Plug Class G Plug back from 7,500'- 7,000.0 7,500.0 No No No 7000' MD Q Pump Init (bbl/m... Q Pump Final (bbll... Q Pump Avg (bbl/...P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 2 4 230.1 No No Tagged Depth (ftKB) Tag Method _ Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump 1 st stage of cement plug program @ 7,497' MD. Flood all lines and PT to 3,500 PSI. Close bag and take all returns thru choke. Pump 27 BBLS 12.5# MP2 @ 4.2 BPM 100 PSI. Balch and pump 48.3 BBLS 15.8# cement at 4.5 BPM, 100 PSI. drop wiper ball and pump 3 BBLS of MP2. Swap to rig for displacement with 82.7 BBLS -SND. Pump 4 BPM @ 220 PSI, @ 772 stks reduce rate to 2 BPM, 197 PSI. Cement wet at 1112 HRS> Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Stm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (lb/gal) Plastic Viscosity (0) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Stage # 2 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? No Second plug Class G Plug back from 6585 - 5,972.0 6,585.0 No No 5972 Q Pump Init (bbllm... Q Pump Final (bbll... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) IRecip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 .2 4 232.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment PJSM RU cement hose and manifold, Close ann, open choke and pump cement plug #2. 27 BBPS 12.5# MPII @ 4.2 BPM 50-156 PSI DPP. Close choke . and batch up cement. With super choke 1/2 open pump 59.5 BBLS of 15.8# class G cement. 4.7 - 4.2 BPM @ 84-111 PSI DPP. Close super choke to drop wiper ball. Pump 3 BBLS MPII spacer and 1 BBL water. swap to rig pumps and displace at 5 BPM, 220-250 PSI DPP. 4 BPM at 642 stks.340 PSI DPP. 2 BPM from 691 STKS at 232 FCP. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped Ili Yield (ft /sack) Mix K20 Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 112 ReportPrinted: 8/1012D11 e Cement Detail Report 1H-108 String: Cement Plug Job: DRILLING ORIGINAL, 61412018 00:00 Cement Stages Stage # 3 Description Third plug Class G Objective Plug back from 5972 - 5472 Top Depth (ftKB) 5,472.0 Bottom Depth (ftKB) 5,972.0 Full Retum. No Vol Cement... Top Plug. No Btm Plug? No Q Pump Ind (bbl/m... 4 Q Pump Final (bblt... 3 Q Pump Avg (bbli...P 4 Pump Final (psi) 518.0 P Plug Bump (psi) Recip7 No I Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth IRKS) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump cement plug # 3 at 5,972' MD. MU cement hose assym and close ann taking returns through super choke and closing chokes with pumps off. Pump 27 BBLS 12.5# MPIL at 4 BPM 850 ICP, 340 FCR, Mix and pump 48.3 BBLS of 15.8#. cmt at 4 BPM. 78-230 PSI. Srop wiper ball at 160 stks. 4 BPM from 420 stks 500 PSI. reduce to 3 BPM 518 PSI FCR. 617 total siks pumped. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (Wisack) Mix H2O Ratio (gallsa... Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Stage # 4 Description Fourth plug AS1 Objective Top Depth IRKS) 4,311.0 Bottom Depth IRKS) 5,011.0 Full Return? No Vol Cement... I Top Plug? No I Bum Plug? No Q Pump Ind (bbl/m... 4 Q Pump Final (bbll... 2 Q Pump Avg (bbll... 3 P Pump Final (psi) 470.0 P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth IRKS) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump Cement plug #4 of AS1. Pump 27 BBLS of 12.7 PPG mud pushll Qa 3.7 BPM 170 PSI DPP. Close bag, batch up cement system. Open Annular and pump 67.7 BBLS of 15.7# ASI cement at 4.3 BPM 90 PSI DPP. Close bag and drop wiper ball. Pump 3 BBLS Mud pushll and one barrel fresh water. Displace cement with rig pumps of -SND at 4 BPM with last 5 BBLS being pumped at 2 BPM. 470 PSI DPP. Was able to catch cement 21 BBLS into displacement. Cement wet at 0213 his. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top IRKS) Est Son IRKS) Amount (sacks) Class Volume Pumped (bbl) Yield (ft /sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Iblgal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 212 Report Printed: 8/10/2018 Cement Detail Report r 11-1-108 String: KOP Job: DRILLING ORIGINAL, 6/4/2018 00:00 Cement Details Cementing Start Date Cementing End Date Wellbore Name Description KOP 6/30/201818:45 6/30/201820:00 1H-108A Comment Cement Stages Stage # 1 Objective Top Depth (ftKB) Plug? Bottom Depth (ftKB) Full Return? Vol Cement...7Ittd? Description KOP KOP 2234 - 1734 1 734.0 2,234.0 No EPpe O Pump /nit (bbl/m... O Pump Final (bbl/... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) M (rpm) 5 2 3 35.0 No Tagged Depth (ftKB) Tag Methotl Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 9-7/8 Comment RU cement head and pump KO plug. Pump 27 BBLS of 12.5# MP @ 4.8 BPM54 PSI DPP> close bag and batch cement. Open bag and pup 51 BBLS of ASt 15.7# cement at 4.6 BPM 100-421 PSI DPP. close bag and drop ball. Pump 3 BBLS Mud Push II and 1 BBLS fresh water behind ball then wsap to rig pumps for displacement of 11.47 BBLS -SND at 4 BPM, 35 PSI with last 5 BBLS at 2 BPM 42 PSI. Cement wet at 1920 his. CIP @ 1946 his. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Eat Bt. (ftKB) Amount (sacks) Class Volume Pumped (bbl) 51.0 Abandonment 1,734.0 2,234.0 A Cement Yield (ft /sack)Mia M20 Ratio (gal/sa... Free Water (�) Density (Ib/gal) Plastic Viscosity (cP) is ening Time (hr) CmprStr 1 (psi) 0.94 3.65 15.72 3 Additives Type Concentration Conc Unit label Additive Page 1/1 ReportPrinted: 917/2018 21 8070 29534 mbergerTransmittal #: 18JUL18-SP02 Drilling & Measurements Product Delivery Customer: ConocoPhillips Alaska, Inc. Dispatched To: AOGCC: Natural Resources Tech Lo in Date 29 -Jun -18 Well Name: 1H -108A Date Dispatched: 18 -Jul -18 Service Order #: 18AKA0012 Dispatched By: Stephanie Pacillo Product Description Hardco NIA Di ital Co Contents on CD Lo in Date 29 -Jun -18 Color Log Prints: VISION Service 2" MD / TVD x 5" MD / TVD x 2" TVD above / below 90deg incline x 5" TVD above / below 90deg incline REC E V E D JUL 18 2018 AOG C N/A Digital Data LAS/DCIS Data NIA EenonD DDirectional Surveys Survey Nad27 Directional Survey Nad83 Gyrodata Survey D CD x Data: DLIS/ LAS Graphics: PDF x Surveys: PDF/TXT x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkam conoco hilli s.com skaPTSPrintCenter slb.com Arn Tom Osterkamp Attn: ephanie Pacillo Received By: THE STATE °fALASKA GOVERNOR BILL WALKER Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU IH -108A Permit to Drill Number: 218-070 Sundry Number: 318-277 Dear Mr. Alvord: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.aloska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this `� day of July, 2018. RBDMSJUL 0 51919 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 3)LT_TSIN-M:T1: RECEIVED JUN 20. 2018 te AG.CC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug far Redrill Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: —E—]- 2. Operator Name: 2. 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 0 • Stratigraphic ❑ Service ❑ 218-070 3. Address: 6. API Number: P.0 Box 100360 Anchorage, AK 99510-0360 50-029-23608-01-00 ` 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? KRU IH -108A Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADI -025639 / ADL025635 Kuparuk River Field / West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9245 3784 1784 1723 1382 2700' total in well Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 119 119 Surface 1795 10-3/4" 1834 1767 5210 psi 2470 psi Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3-1/2" L-80 1764 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary L��J Wellbore schematic lal 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑� ` Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/29/2018 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑� GAS El WAG ❑ GSTOR F1ElSPLUG 16. Verbal Approval:,"'^b' Date: �' �� Commission Representative: �r`IL 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. , *4;y Authorized Name: Chip Alvord Contact Name: Nick Lehman Authorized Title: Alaskj Drilling Manager Contact Email: nick. r.lehman A conoco hllli S.com O / Contact Phone: 907-263-4951 Authorized SignatureDate: : COMMISSION USE Ot&Y Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity LvJ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Zyheua-ne7`Ce-/ Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Ile, Approved by:"DM�COMMISSIONER THE COMMISSION Date: i S (�Ir�"71n'y1 �Q(J Rg�MJn�� t1I p C' 1/�, 'AV' �/ Submit Form and Form 10-403 Revised 4,y. JApprgvey2JI@catiorli�N I�t�r�rr�+tl7� o date of approval. Attachmentsi Dupl' ate VVV /rlC� F' 1 �1d�S � 7 Z7 9 e' Application for Sundry to Temporarily Abandon, Well 11-1-108A Saved: 28 -Jun -18 June 28, 2018 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry to Temporarily Abandon Well 111-108A, a West Sak Sand Injector Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to temporarily abandon 1 H-1 08A, an onshore grassroots injector well from the 1 H pad, with the intent of leaving it setup for future sidetrack operations. The expected operational date for temporarily abandonment is June 291h, 2018. It is planned to use rig Doyon 142. 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: 1. Form 10-403. 2. Proposed abandonment program. 3. 1H -108A Planned Abandonment Schematic. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out 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 Nick Lehman at 907-263-4951 (nick.r.lehman@cop.com) or Chip Alvord at 265-6120. Sincerely,,, � Nick Lehman Drilling Engineer Doyon 142 1H -108A Temporary Abandonment Procedure The proposed scope of work for this sundry application is included below. 1. Doyon 142 is currently rigged up on 1H -108A (PTD # 218-070) 2. RIH with 3.5" cement stinger on 4-1/2" drill pipe to pump cement to isolate hydrocarbon bearing zones. 3. Pump 4 balanced cement plugs, 1 x 15.7ppg cement plug to isolate 250' TVD above the Ugnu sand, 2 x ✓ 15.8ppg cement plugs to isolate the WestSak sands with top of plug 250' TVD above the N -sand, and 1 x 15.8ppg cement plug to isolate toe -up section, using gelled pills to support upper plug and lower plugs. 4. Circulate clean and wait on cement based on results from UCA. 5. RIH and tag top abandonment cement plug. Notify AOGCC inspector 24 hours prior to witness tag. 6. Pull OOH to shoe and pump 15.7 ppg kickoff cement plug +/- 50' inside surface casing for future sidetrack (1H -108B). 7. Pull out of hole and lay down 3.5" cement stinger. 8. Pick up 9-7/8" clean out BHA. 9. RIH with cleanout assembly, tag top of kickoff plug, cleanout to within 50' of surface shoe, and pull out of hole. Give AOGCC 24 hours' notice to witness tag of cement. Pf is'ocr j�j'� P re_s.4vre 10. RIH with 3-1/2" tubing for freeze protecting. 4B$ r 11. Land hanger, run in lock screws, and test seals to 5,000 psi 12. Set BPV and test in direction of flow. 13. Nipple down BOPE, nipple up tree and test. Pull BPV. 14. Freeze protect 3.5" x 10-3/4" annulus (if the schedule and equipment availability allow, the Wells Group will freeze protect the well post rig). 15. Rig down and move off rig. n 0 0 n 0 x IH -108A Planned Abandonment Schematic _ 11 Mead I Tubing Hanger I Tree 13318° x 4-,;r l YD563, 5M 11-1-108A Injector We I] Design Insulakd Crossover below TH: 4-112"04;2"Tubing Proposed Temporary Conductor.20" — Abandonment Casino 1 � 1 � I t 13-'rf' HOLE & 10-3/4° 45.5#, L-80 HYD563 k — @ 1.834 ft MD * IIY. 9.3 #, L-80. EUE s 1.761' MD! 1,705' TVD t Top of Kickoff Plug 1781' MD1 023' TVD tt t t Bum of Kickoff Plug @ "U MD 1121, TVD Tot of Atendonu eni Plug 44 9 4311' MD/2,862'TVD \` � T ofUgnuCactual @15,065MD13.113'TPD — Top Btm of Atundonmem Plue#4 @ SAI l' "Y\ MD/ 3.093' TVD � t t t Top of Abandonment Plue #3 @ 5472' __ T► 013.272 TVD +---- - - Top of Mand actual @ 6,093' MD 13,513' TVD Bim of Abandonnient Plue #3 @ 5,972' ,� ) 48713 46..T TVD f ---- Top of WestSak D -Sand actual tat 6,5&5' MD 13,714' TO Top of AbWonment Phis #2 @ 5.972' {---.— Top of WestSak 8 -Sand actual @ 6,766' MD 13,790 TO MD/ 3,163' TVD --- Top of WestSak A4 -Sand actual Cdr 6,856' MD/ 3,828'TVD Bun of,Abandonment Plug #2 @ 6,585' `t - Top of WestSak A3 -Sand actual 61 6,958' NIDI 3.872TO 4{D / 3,714' TVD Top of Abandonment Flue #1 Ca 7,ODO' MD13.890'TVD Bun of Abandonrrent Plu4 # I Ca 7.500' MD 11.434' TO Top of Wedak A2 -Sand actual @ 7,179' MDI 3,963' TVD Fit 8-3i' HOLE 9,245' MD1379 TO Top of WestSak D -Sand atlual [ 9, I87MD aMI TVD �x\ Top of IV&Sak B -Sand actual @ 8,990 MD/ 3,866' TVD Top of WestSak .A4 -Sand actual @ 11.888 MD/ 3,895 TO Top of W'esft A3Sand actual 08,76.1'101110"93? 3,937 TVD TopofWcstSaA2-.Snkd actual @ 8,51T 41D 14,045' TVD Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re - drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left comer of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. rHE STATE °fALASKA GOVERNOR BILL WALKER Chip Alvord Alaska 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.aogcc.alaska.gov Re: Kuparuk River Field, West Sak Oil Pool, KRU 1H -108A ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-070 Surface Location: 50' FSL, 770' FEL, SEC. 28, T12N, R10E, UM Bottomhole Location: 2409' FNL, 226' FWL, SEC. 35, T12N, R10E, UM Dear Mr. Alvord: the permit to re -drill the above referenced service well Enclosed is the approved application for. 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. from obtaining additional permits or an approval required This permit to drill does not exempt you operations by law from other governmental agencies and does not authorize conducting drilling C untilalld appro other withda tpermits he permit in the event valsit wvas erroneously ie been issued. ssued.ition, the AOGCC reserves the Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of thdministahve Code, e Alaska A 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 �14 DATED this �- day of July, 2018. R CEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION UN 2 2 Z0�8 PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill ElLateral ❑ Redrill❑. Reentry El 1b. Proposed Well Class: Exploratory -Gas Stratigraphic Test ❑ Development - Oil ❑� - Exploratory - Oil ❑ Development - Gas ❑ Service - WAG Service -Disp E]1 Service - Winj ❑ Single Zone ❑ Service -Supply ❑ Multiple Zone ❑ c. Specify if well is proposed for: Coalbed Gas ❑ `Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: Conocolohillips Alaska, Inc. 5. Bond: Blanket LJI Single Well Bond No. 59-52-180. 11. Well Name and Number: KRU 1 H -108A 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 9,248 TVD: 3,773 12. Field/Pool(s): Kuparak River Field West Sak Oil Pool 4a. Location of Well (Governmental Section): Surface: 50' FSL & 77Y FEL, See 28, Tl 2N, R10E, UM Top of Productive Horizon: 2391' FNL & 2252' FEL, Sec 34, Tl 2N, R10E, UM Total Depth: 2409' FNL & 226' FW L, See 35, T121 RI OE, UM 7. Property Designation: ADL025639 / ADL025638 8. DNR Approval Number: 80-261 / 931695000 13. Approximate Spud Date: 6/24/2018 9. Acres in Properly: 5120 acres 14. Distance to Nearest Property: 2870' to ADLO25649 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 549570.98 y- 5980752.52 Zone- 4 10. KB Elevation above MSL (h): 93.0' GL / BF Elevation above MSL (ft): 54.0' 15. Distance to Nearest Well Open to Same Pool: 898'to lH-110 16. Deviated wells: Kickoff depth: 1950 feet Maximum Hole Angle: 108.3 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 1,780 psi Surface: 1,382 psi 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' Surf Surf 119' 119' Existing, cement to surface 13-1/2" 10-3/4" 45.5# L-80 HYD563 1795' Surf Surf 1834' - 1767' 969 sx 11.0 ppg, 221 sx 12.0 ppg 19. PRESENT WELL CONDITION SUMMARY (To be completed for Reel and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): 6527 4042 Planned top @1784' Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 1834 1767 Casing Length Size Cement Volume MD TVD Conductor/Structural 119.00 20" Existing, cement to surface Surface 1,795.00 10-3/4" Existing, 969 sx 11 ppg Lead, 221 sx 12ppg Tail, Circulated 84 blots cement to surface Kickoff Plug 500.00 103/4" / 8-3/4" Planned, 281 sx 17ppg for kickoff 3 x Abandonment Plugs 1,783.00 83/4" Planned, 827 sx 15.8ppg for abandonment Perforation Depth MD (ft): Perforation Depth TVD (it): Hydraulic Fracture planned? Yes No Q 20. Attachments: Property Plat [I BOP Sketch 0 Drilling Program 0 Time V. Depth Plot E] Shallow Hazard Analysis Diverter Sketch Seabed Report E] Drilling Fluid Program ❑ 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: 171,121 / 7 S Date ? 2 - Xr ue -Zd 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be l� deviated from without prior written approval. Contact Name: Nick Lehman Authorized Name: Chip Alvord Contact Email: nick.r.lehmanCvlconocophillios.com Authorized Title: Alaska Dr!Jing Manager. / Contact Phone: 907-2634951 Authorized Signature: x 6e Date: r6 Commission Use Only Permit to Drill �J �ra,�l Number: moi/ U� /V API Number: �^' �^ 50-a; -} u -W Permit ApproveSee Date: 2 cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coall methan , gas hydrates, or gas contained in shales: �/ Other: QQ ) ,^/ Samples req'd: Yes ❑ o f Mud log req'd: Yes❑ oLJ 06 r 40 01/V/.gJ •'</''/ E HS measures: Yes No❑ Directional svy req'd: Ves No ?b 3S� IUs Spacing exception regd: Yes ❑ Ni Inclinationonly svy req'd: Yes❑ i Post initial injection MIT req'd: Yes❑ Ni APPROVED BY I./J. Approved by: COMMISSIONER THE COMMISSION Date: KLi ORIGINAL Submit Form and Form 10401 Revised 5/2017 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate � Application for Permit to Re -Drill, Well 11-1-108A Saved: 22 -Jun -18 June 22, 2018 Alaska Oil and Gas Conservation Commission 333 West 7" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Re -Drill Well 111-108A, a West Sak Sand Injector Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to re -drill an onshore grassroots injector pilot well from the IH pad utilizing existing IH -108 surface casing. The expected start date for this sidetrack is June 24", 2018. It is planned to use rig Doyon 142. 1H -108A is planned to be a slant well thru the West Sak sands to help validate future wells. The 10-3/4" surface casing from 111-108, set at 1834' MD / 1767' TVD will be utilized. The well will be sidetrack off planned kickoff plug below surface casing shoe and the production section will be drilled with 8-3/4" bit and to ±9248' MD / 3,773' TVD. The - wellbore will be plugged back and abandoned, and kickoff plug installed at surface casing shoe. Future sidetrack from 1H -108A will be determined once data has been processed from 1H -108A. 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: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. 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 Nick Lehman at 907-263-4951 (nick.r.lehman@cop.com) or Chip Alvord at 265-6120. Sincerely, Nick Lehman Drilling Engineer Application for Permit to Drill Document Kuparuk Well IH -108A Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as KRU 1H -108A Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill mast be accompanied by each of the follon•ing iteens. esceplfn? air hent already on file with the commission and identified in the application: (2) a plat identifying the properiv and the properri s owners and showing (A) the coordinates ofthe proposed location of the well at the surface. al the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the in, location of the well at the surface, referenced to the state plane coordinate systenh for this state as main mined by the National Geodetic Survey in the National Oceaniaand Annospheric Administration: (C) the proposed depth oftlse well at the lop of each objecInept enatian and ca total depth: Location at Surface 50' FSL & 770' FEL, Sec 28, T 12N, R 10E, UM NCS Coordinates Northings: 5,980752.52' Eastings: 549,570.98 i RKB Elevation 93.0' AMSL Pad Elevation 54.0' AMSL Location at Top of Productive Interval (West Sak D Sand) 2391' FNL & 2252' FEL, Sec 34, T12N, R10E, UM NGS Coordinates Northings: 5,978,338.18' Eastings: 553,389.99' Measured Depth, RKB: 6,547' Total Vertical Depth, RKB: 3,707' Total Vertical Depth, SS: 3,614' Location at Total Depth 2409' FNL & 226' FWL, Sec 35, T12N, R10E, UM NGS Coordinates Northings: 5,978,338.13' Eastings: 555,868.26' Measured De th, RKB: 9,248' I Total Vertical De th, RKB. 3,773' Total Vertical Depth, SS: 1 3,680' and (D) other infatuation required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) (fa well is to be intentionally deviated, dee application for it Permit to Drill (Form 10-401) must (1) ineLule n plat, drmvn 10 a suitable scale, showing the path of the proposed wellbore, incbrding all adjacent wellbores within 200 feet ofatry portion of the proposed well: Please see Attachment: Directional Plan And (2)for all wells within 200feet of the proposed wellbore (A) list the names of the operators of'those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished it cops' ofthe, application by certified mail; or (B) nate than the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application fo' a Pe ..it to Drill anal be accmnpan ied M each o'da following hams, escepl for an Leo already as file with the a.in ... ission and identified in the application: (3) a diagron and description of the blowon prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable: Please reference BOP schematics on file for Doyon 142 and attachment. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for Permit to Drill inns( be mconapanied by each ofthefdlou•ing items, exceptforan item already on file frith the commission and identified an the application: (4) inforhnation on drilling hazards, inchading (A) The rn tomato dmrnhole presswe that may be encountered, criteria used to determine it, and radioman potential surfae pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 1H -108A is calculated using an estimated maximum reservoir pressure of 1,780 psi (based on IH -1 05 MDT pressure of 1749 psi, 8.6 ppg equivalent, and corrected to depth), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak A2 sand at 3,979' TVD: A Sand Estimated. BHP = 1,780 psi A Sand estimated depth = 3,979' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 398 psi (3,979' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 1,382 psi • (1,780 psi — 398 psi) (B) data on potential gas zones: The well bore is not expected to penetrate any shallow gas zones. And (C) data conrerning potential causes of hole problems such as abnormally geo-pressured strata, lost cirmdation zones, and ¢ones that have a propensity for differential sticking; See attached 1H -108A Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item ah eadv on file with he commission and identj(ed in the application: (5) a desa iption of the procedure for conducting formation integrity tests, as required ander 20 AAC 25.030(f); A procedure is on file with the commission for performing LOT'S. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An apialh alma for n Permit m Drill most be acx'ompanied by each of the following items, e.reept for an item alreudr malile with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25,030. and a description of aqv slotted liner, pre-perfooved liner, or screen to be installed Casing and Cement Program Casin and Cementin Pro ram Csg/!bg OD Hole Weighs Length Top MD/IVD Ban MDITVD (in) Sine (Ib/fQ Grade Conn. 01) (h)Cement Program 20 42 94 H40 Welded 80 Surf 1191119 Existing Existing Cement to Surface with 10-3/4 13-I/2 45.5 L$0 HYD563 1,795 ' Surf 1,845 11,767 969 sx LiteCRETE Lead 11.0 ppg 221 sx LiteCRETE Tail 12.0 ppg 84 bbls cement circulated to surface 8-3/4" _Open Hole Abandonment and Kickoff Plue Desi¢n 3 x 15.8ppg abandonment balanced plugs and 1 x 17.Oppg kickoff balanced plug will be installed in the well to isolate hydrocarbon bearing zones and provide kickoff point for future sidetrack. 35% excess annular volume will be used in calculations. 8-3/4" Abandonment Cement Plug Calculations Spot 1x Balanced plug 250' ND above top of Ugnu zone and 2x Balanced plugs 250' ND above top of N -Sand Cement yield= 1.16 ftA3/sk Plug#3 Planned TOC,'MD= 3921 Plug#2Planned TOC,'MD= 5534 Plug#1 Planned TOC,'MD= 6034 Plug#3 Cal cuIation (4621'- 3921') x0.0744 bbl/ftx 1.35(35%excess) 70.3 bbls / 396.6 ftA3/ 341 sks Plug #2 Calculation (6034'- 5534') x 0.0744 bbl/ft x 1.35(35°%excess) 50.3 bills / 283.0 ftA3/ 244 sks Plug #1 Calculation (6547'- 6034') x 0.0744 bbl/ft x 1.35(35%excess) 51.6 bills / 290.0 ftA3/ 250sks Kickoff Plug Calculations Spot ix 500ft 17ppg Balanced kickoff plug +/-Soft inside 30-3/4" surface casing Cementyield= 1.00 ftA3/sk Plug#3 Planned TOC,'MD= 1784 Cement inside 30-3/4"csg (1834'-17M x 0.0962 bbl/ft x 1.0(096 excess) 4.81 bbls Cement below 10-3/4'ag (2284'- 1834') x0.0744bbl/ftx 1.35 (35% excess) 45.20 MIS Total Cement 50.0 bills or 281 ft -3 or 281 sks 11-11-108A Abandonment / Sidetrack Plan 103/4" SURF 1784 ft 50' above shoe –SW kkkotf plug 1834 ft Previous shoe 8.75" OH > - 2284 ft 450' below shoe Plug #3top at 3921' MD3921 ft ` 250' W D above Ugnu-11111111111111 Abandonment plug #3 Plug #3 btm at 4621' MD 4779 ft Top of Ugnu - hydrocarbons Hi -Vis Spacer Plug #atop at 5534' MD t 5534 ft 250' TVD above N -sand Abandonment plug #2 Plug #2 btm at 6034' MD Plug#1 top at 45034' MD 6158 ft Top ofN-Santl - hydrocarbons Abandonment plug #1 Plug #1 btm at 6547' MD 6547 ft WestSak D -Sand ft WestSak B -Sand 6839 ft WestSak A4 -Sand HI -Vis Spacer ' 6961 ft WestSak A3 -Sand 7233 ft WestSak A2 -Sand 8427 t WestSakA2-Sand - Invented LA6747 8732 ft WestSak A3 -Sand - Inverted 8876 ft WestSak A4 -Sand - Inverted 8982 ft WestSak a -Sand - Inverted 9163 ft WestSak D -Sand - Inverted 9248 ft TD Diverter System Information Reauirements of 20 AAC 25.005(c)(7) An application fora Permit to Drill naoY be arcmnpanied by each oflhe fallowing items, erc'epl for an hent already on file will, the oammissia, and identified in the application: (7) a diagram and description ofthe divener s;vsrern as required by 20 AA C 25.035.unless this regairement i.s.aired be the, aanission under20AAC 2A035(h)(2): Please reference diverter schematic attached. Please note that surface has already been drilled, cased, and cemented off. This is included for reference only as we will not be needing diverter on 1H -108A. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An apphealwn for a Permit to Drill rna.s, be accompanied by each of the follou,ing items, excepiJor art item already on file with the conmtission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Mud Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (d(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Reauirements of 20 AAC 25.005 (e)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Production 8-3/4" Hole Mud System LSND (WBM) Density 9.0-10.0 PV ALAP YP 20-30 Funnel Viscosity N/A Initial Gel 9 - 11 10 -minute Gel < 20 API Filtrate < 6 HTFIP Fluid Loss at 160' F < 10 H 9.5-10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (d(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Reauirements of 20 AAC 25.005 (e)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An np )l aarion fora Penni/ to Drill now be aecarnpanied by each ofthe jollo,vin,g betas. escepi for on item alreadr on file with the cmntnission and identifierI in the applinaion.' The proposed drilling program is included below. Please refer to attachment for proposed well schematic. Z </ A,1&.4r ns t-. e- to 4w 61'coeekI abP-Cvrsz 1. PU 8.75" bit and 6.75" drilling assembly, with MWD/LWD (gamma ray, resistivity, and density). RIH, tag kick off plug, clean out cement to surface casing shoe. 2. Displace to 9.0 - 9.2 ppg LSND water-based drilling Fluid. 3. Perform sidetrack below surface casing shoe and directionally drill 8-3/4" production hole to TD of 9,.248' MD / 3,773' TVD. Note: Successful FIT was performed on IH -108 surface shoe to 12.Oppg EMW. 4. Circulate hole clean. POOH. 5. RIH with 3.5" cement stinger on 4-1/2" drill pipe to pump cement to isolate hydrocarbon bearing zones. 6. Pump 3 balanced 15.8 ppg cement plugs, I to isolate 250' TVD above the Ugnu sand and 2 to isolate the WestSak sands with top of plug 250' TVD above the N -sand, using gelled pill to support upper plug and lower plug. 6� 7. Circulate clean and wait on cement based results fro U�p 56 3-r,4T-em ?lc�,Ti✓ESS �nF,. o • �e N �/!�' a325 `fVA e�ti- 8. RIH and tag top abandonment cement plug. Notify AOGCC inspector 24 hours prior to witness tag. 9. Pull OOH to shoe and pump 17.0 ppg kickoff cement plug +/- 50' insi�esurface casing for sidetrack (IH-IO8B). be+�11-__- IV q ne ht :ar �rl�a,t L08 10. Pull out of hole and lay down 3.5" cement stinger. 6e t� L6-' stK' 11. Pickup 8-3/4" drilling BHA and TIH to drill the IH -108B WestSak slant injector. 12. Tag up on cement plug, polish off cement, and drill cement in casing to within 10' of shoe. 13. Transfer to PTD for lH-I08B. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An applirarion for' a Permit to Drill must be aeootnpanied bearn o/'theJollaming bents, eaepi for an hent already on file with the commission and identified in the application: /6) a general description of hon the operatorptans to dispose of drilling road and cuttings and a statement of whether the operator intends to request authorization under 20 AA C 25.050 for an annular disposal operatimt in the well.: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (DS 1B CRI) or Prudhoe DS -4. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic, Current and Proposed Attachment 4 Diverter Layout Diagram Attachment 5 BOP Configuration 14:22, June 212018 9 O n 0 E o 20 Y O 2 ti 1H -108A wp01 Permit Fa Ran Summa Measured Depth - 10 to ala' 11-1-108 actual @ 92.99usft (Doyon 142) 0 950 1i Horizontal Departure `o_ �0 7H-108 Checked by: ccepted by: Approved by: n v CE DeLapp II Erik Stark DE Name \ o V jEquivalent Magnetic Distance i 0 2100 2450 2800 3150 3500 3850 4200 4550 Measured Depth Depth Fmm Depth To Survey/Plan tool Pad Elevation: 54.00 120.60 1280.30 1H-108 SM1 GWD70 GYUGC-SS 130199 175D.D3 iH-108 Srvy2MWD-GMAG MWD+IFR-AK-CPZ-SC 1047.94 195090 1H-108 SM 3 MWD+GMAG MWD+IFR-AK-CPZ-SC ocasing aals avala 195000 3500.00 ZOBAwp01 ry111IN) MWD 195000 9247,83 iH-108A wp01 DH -108A) MD+IFR-AK-CAZ-SC Sec MO Inc Pat TVD +N/-5 +E/ -W Dleg TFace VSect Target 1 195000 3282 122.26 1888.31 -233.86 359.95 0.00 0.00 420.32 23235.41 7589 139.37 2601.25 -928.77 1098.73 3.50 23.801361.48 33845.51 7589 139.37 274997-1377.84 1484.02 0.00 000 883.83 46541 75 64 90 90.38 3704.99 -243839 3881.82 1.75 -111.31 4317.07 1 H-1 OBA T01 WSD 062118 56961.41 64.90 90.38 3882.99 -2441.29 4061.85 0.00 0.00 4671.92 111-108A T02 A3 062118 67785.89 8964 90.38 406326-2446.53 4859.82 3.00 0.005477.02 7789348 89.64 90.38 4063.94 -2447.24 4967.41 0.00 0.00 5517,48 8 7908.00 90.00 90.38 4063.99 -2447.33 4981.92 2.50 0.60 5531.03 1 H -10M T03 A2 082118 98202,44 97.36 90.38 4045.10 -2449.27 5275.54 2.50 -0.045805.21 108285.05 97.36 90.38 4034.52-2449.80 5357.47 0.00 0.005881.71 11 8721.06 108.26 90.38 3937.99 -2452.59 5781.98 2.50 0.01 6278.09 11-008A T04 A3 W2118 12 9247 6310826 9038 3772,99 -2455.87 628292 0.00 0.00 6745.00 111-108A T05 WSD 062118 a DLS, -111,31- TF, for 2696.24' �S, 0' TF, for 824.48' )LS, 0.6' TF, for 14.51' 34', for 294.44' )LS, 0.01' TF, for 436.01' J. 3772 99' ND repared by 1 Checked by: ccepted by: Approved by: CE DeLapp II Erik Stark DE Name \ o tin Ir A_.1 :r Magnetic Model& Date: 1 q Sec MO Inc Pat TVD +N/-5 +E/ -W Dleg TFace VSect Target 1 195000 3282 122.26 1888.31 -233.86 359.95 0.00 0.00 420.32 23235.41 7589 139.37 2601.25 -928.77 1098.73 3.50 23.801361.48 33845.51 7589 139.37 274997-1377.84 1484.02 0.00 000 883.83 46541 75 64 90 90.38 3704.99 -243839 3881.82 1.75 -111.31 4317.07 1 H-1 OBA T01 WSD 062118 56961.41 64.90 90.38 3882.99 -2441.29 4061.85 0.00 0.00 4671.92 111-108A T02 A3 062118 67785.89 8964 90.38 406326-2446.53 4859.82 3.00 0.005477.02 7789348 89.64 90.38 4063.94 -2447.24 4967.41 0.00 0.00 5517,48 8 7908.00 90.00 90.38 4063.99 -2447.33 4981.92 2.50 0.60 5531.03 1 H -10M T03 A2 082118 98202,44 97.36 90.38 4045.10 -2449.27 5275.54 2.50 -0.045805.21 108285.05 97.36 90.38 4034.52-2449.80 5357.47 0.00 0.005881.71 11 8721.06 108.26 90.38 3937.99 -2452.59 5781.98 2.50 0.01 6278.09 11-008A T04 A3 W2118 12 9247 6310826 9038 3772,99 -2455.87 628292 0.00 0.00 6745.00 111-108A T05 WSD 062118 a DLS, -111,31- TF, for 2696.24' �S, 0' TF, for 824.48' )LS, 0.6' TF, for 14.51' 34', for 294.44' )LS, 0.01' TF, for 436.01' J. 3772 99' ND repared by Checked by: ccepted by: Approved by: CE DeLapp V Osara Erik Stark DE Name Spider View 1 H -1 08A wp01 7 Plan View While dilifing production section stay within target polygon laterally of plan, unless notified otherwise. 700— 'Z ^o 0- 10 10 3/4"--ii� c N-700 D 0 0 0 CL 3 E1400-; o 0D o Z O T 2 X00 o CO -2100-I, oo M C) i co 1H-108AT01 WSD0621 8 -2800 1 H-1 08A T04 A3 062118 11H -108A T02 A3 062118 1 H-1 08A T05 Fl—H- 1 08A T03 A2 06211 WSD 0621 -3500 0 700 1400 2100 2800 3500 4200 4900 5600 6300 West( -)/East(+) (700 usft/in) El 750 c_ 51500 0 LO r- 10 10 3/4" a� 2250 U (D 37 1H -108A wp01 1000 - Iv�vpp0 ti i Z i O �z 1 H -1 08A T01 WSD 0621 8 °o 0 11-1-108A T03 A2 062118 1 H-1 08A T02 A3 062118'. 1 H-1 08A T05 WSD 0681 8 Oe 11-1-108A T04 A3 062118 t�h ^oho 0 M �® w 0 750 1500 2250 3000 3750 4500 5250 6000 6750 Vertical Section at 111.35° (750 usft/in) ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad Rig: 1H-108 500292360800 Plan: 1 H-1 08A wp01 Standard Proposal Report 22 June, 2018 ConocoPhillips ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Rig: 1H-108 Wellbore: 1 H-1 08A Design: 1H-108Awp01 Schlumberger Standard Proposal Report Local Coordinate Reference: Well Rig: 1 H-108 TVD Reference: 1 H-108 actual @ 92.99usft (Doyon 142) MD Reference: 1 H-108 actual @ 92.99usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1983 North System Datum: Mean Sea Level Geo Datum: American Datum Using Well Reference Point Map Zone: 1983Alaska Zone 4 Using geodetic scale factor Site Kuparuk I Pad Site Position: Noting: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usk Slot Radius: 0" Gild Convergence: 0.37 ° Well Rig: IH -108 Design Well Position +N/ -S 781.33 usft Northing: Latitude: +EAW 378.96 usft Easting: Longitude: Position Uncertainty PLAN 0.00 usft Wellhead Elevation: Ground Level: 54.00 usft Depth From (TVD) -NI-S +E/ -W Direction Wellbore 1H -108A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) V) (nT) BGGM2017 6/1/2018 17.08 80.93 57,467 6/222018 10.46..29AM Page 2 COMPASS 5000.14 Build 85 Design iH-108Awp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 1,950.00 Vertical Section: Depth From (TVD) -NI-S +E/ -W Direction (usft) (usft) (usft) (°) 38.99 0.00 0 O 111.35 Plan Survey Tool Program Date 8/22/2018 Depth From Depth To (usk) (usft) Survey (Wellbore) Tool Name Remarks 1 1,950.00 3,500.00 1H -108A wp01 (1H-1 08A) MWD MWD - Standard 2 1,950.00 9,247.63 1H -108A wp01 (1H -108A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/222018 10.46..29AM Page 2 COMPASS 5000.14 Build 85 r Schlumberger ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 111-108 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: 1H-108 actual @ 92.99usft (Doyon 142) Project: Kuparuk River Unit MD Reference: 1H-108 actual fid- 92.9gusft (Doyon 142) Site: Kuparuk 1 H Pad North Reference: True Well: Rig: 1H-108 Survey Calculation Method: Minimum Curvature Wellbore: 1H -108A Depth Inclination Design: 1 H -108A wp01 +N/ -S +E/ -W Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Rate Rate Rate TFO lust) (I (°) (usft) (usft) (usft) (°I100usft) (°1100usft) (°/100usft) (°) Target 1,950.00 32.82 122.26 1,866.31 -233.66 359.95 0.00 0.00 0.00 0.00 3,235.41 75.89 139.37 2,601.25 -928.77 1,098.73 3.50 3.35 1.33 23.80 3,845.51 75.89 139.37 2,749.97 -1,377.84 1,484.02 0.00 0.00 0.00 0.00 6,541.75 64.90 90.38 3,704.99 -2,438.79 3,681.82 1.75 -0.41 -1.82 -111.31 1H-1ORA T01 WSD Of 6,961.41 64.90 90.38 3,882.99 -2,441.29 4,061.85 0.00 0.00 0.00 0.00 1H -108A T02 A3062' 7,785.89 89.64 90.38 4,063.26 -2,446.53 4,859.82 3.00 3.00 0.00 0.00 7,893.48 89.64 90.38 4,063.94 -2,447.24 4,967.41 0.00 0.00 0.00 0.00 7,908.00 90.00 90.38 4,063.99 -2,447.33 4,981.92 2.50 2.50 0.03 0.60 1H -108A T03 A2062' 8,202.44 97.36 90.38 4,045.10 -2,449.27 5,275.54 2.50 2.50 0.00 -0.04 8,285.05 97.36 90.38 4,034.52 -2,449.80 5,357.47 0.00 0.00 0.00 0.00 8,721.06 106.26 90.38 3,937.99 -2,452.59 5,781.98 2.50 2.50 0.00 0.01 1H -108A T04 A3062' 9,247.63 108.26 90.38 3,772.99 -2,455.87 6,282.02 0.00 0.00 0.00 0.001H -108A T05 WSD OE 6/222018 10:4629AM Page 3 COMPASS 5000.14 Build 85 r Schlumberger ConocoPhil lips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 1H-1 OB Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: 1 H-108 actual Q 92.99usft (Doyon 142) Project: Kuparuk River Unit MD Reference: 1H-108 actual @ 92.99usft (Doyon 142) SRO: Kuparuk 1 H Pad North Reference: True Well: Rig: 1H-108 Survey Calculation Method: Minimum Curvature Wellbore: 1 H-1 08A Azimuth Depth Design: 1H-108Awp01 Section Rate Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) 1°) (usft) (usft) (usft) (usft) (°1101 (°/100usft) (°/100usft) 1,950.00 32.82 122.26 1,866.31 -233.66 359.95 420.32 0.00 0.00 0.00 KOP: 3.5°/100' DLS, 23.8° TF, for 1285.41' 2,000.00 34.43 123.51 1,907.95 -248.70 383.19 447.44 3.50 3.22 2.50 2,100.00 37.68 125.73 1,986.79 -282.16 431.59 504.70 3.50 3.25 2.21 2,163.06 39.74 126.96 2,037.99 -305.54 463.34 542.78 3.50 3.28 1.96 K15 2,200.00 40.96 127.64 2,066.14 -320.03 482.37 565.78 3.50 3.29 1.83 2,300.00 44.27 129.31 2,139.73 -362.17 535.34 630.47 3.50 3.31 1.67 2,400.00 47.61 130.79 2,209.26 -408.42 590.32 698.51 3.50 3.33 1.48 2,500.00 50.96 132.13 2,274.49 -458.61 647.10 769.66 3.50 3.35 1.33 2,600.00 54.32 133.34 2,335.16 -512.56 705.46 843.66 3.50 3.36 1.21 2,700.00 57.70 134.45 2,391.06 -570.05 765.18 920.21 3.50 3.38 1.11 2,800.00 61.08 135.49 2,441.97 -630.87 826.05 999.05 3.50 3.39 1.03 2,900.00 64.48 136.46 2,487.71 -694.81 887.83 1,079.87 3.50 3.39 0.97 3,000.00 67.87 137.37 2,528.10 -761.62 950.30 1,162.38 3.50 3.40 0.92 3,100.00 71.28 138.24 2,562.99 -831.04 1,013.23 1,246.26 3.50 3.40 0.87 3,200.00 74.68 139.08 2,592.26 -902.83 1,076.37 1,331.21 3.50 3.41 0.84 3,235.41 75.89 139.37 2,601.25 -928.77 1,098.73 1,361.48 3.50 3.41 0.82 Hold for 610.1' 3,300.00 75.89 139.37 2,617.00 -976.31 1,139.52 1,416.78 0:00 0.00 0.00 3,400.00 75.89 139.37 2,641.37 -1,049.91 1,202.67 1,502.40 0.00 0.00 0.00 3,500.00 75.89 139.37 2,665.75 -1,123.52 1,265.83 1,586.01 0.00 0.00 0.00 3,600.00 75.89 139.37 2,690.12 -1,197.13 1,328.98 1,673.63 0.00 0.00 0.00 3,700.00 75.69 139.37 2,714.50 -1,270.73 1,392.13 1,759.25 0.00 0.00 0.00 3,800.00 75.89 139.37 2,738.87 -1,344.34 1,455.28 1,844.86 0.00 0.00 0.00 3,845.51 75.89 139.37 2,749.97 -1,377.84 1,484.02 1,883.83 0.00 0.00 0.00 Start 1.76°/100' DLS, -111.31° TF, for 2696.24' 3,900.00 75.55 138.45 2,763.41 -1,417.64 1,518.72 1,930.64 1.75 -0.63 -1.68 4,000.00 74.92 136.76 2,788.90 -1,489.05 1,583.91 2,017.36 1.75 -0.62 -1.69 4,100.00 74.31 135.06 2,815.42 -1,558.30 1,650.99 2,105.04 1.75 -0.61 -1.70 4,200.00 73.72 133.35 2,642.97 -1,625.33 1,719.89 2,193.63 1.75 -0.60 -1.71 4,300.00 73.13 131.63 2,871.50 -1,690.07 1,790.56 2,283.02 1.75 -0.58 -1.72 4,400.00 72.56 129.90 2,900.99 -1,752.46 1,862.93 2,373.13 1.75 -0.57 -1.73 4,500.00 72.01 128.16 2,931.42 -1,812.44 1,936.93 2,463.89 1.75 -0.55 -1.74 4,600.00 71.47 126.40 2,962.76 -1,869.96 2,012.49 2,555.20 1.75 -0.54 -1.75 4,700.00 70.95 124.64 2,994.97 -1,924.96 2,089.53 2,646.99 1.75 -0.52 -1.76 4,778.91 70.55 123.24 3,020.99 -1,966.55 2,151.33 2,719.69 1.75 -0.51 -1.77 Ugnu C 4,800.00 70.44 122.86 3,028.03 -1,977.39 2,168.00 2,739.16 1.75 -0.50 -1.78 4,900.00 69.95 121.08 3,061.91 -2,027.20 2,247.81 2,831.63 1.75 -0.49 -1.79 5,000.00 69.48 119.28 3,096.58 -2,074.36 2,328.89 2,924.31 1.75 -0.47 -1.80 5,100.00 69.03 117.47 3,131.99 -2,118.80 2,411.17 3,017.13 1.75 -0.45 -1.81 5,200.00 68.60 115.65 3,168.13 -2,160.49 2,494.57 3,109.98 1.75 -0.43 -1.82 5,300.00 68.19 113.82 3,204.95 -2,199.40 2,579.01 3,202.79 1.75 -0.41 -1.83 5,400.00 67.80 111.98 3,242.43 -2,235.48 2,664.40 3,295.46 1.75 -0.39 -1.84 5,500.00 67.43 110.13 3,280.52 -2,268.70 2,750.69 3,387.92 1.75 -0.37 -1.85 .5,589.21 67.11 108.48 3,314.99 .2,295.91 2,828.34 3,470.14 1.75 -0.35 -1 As Ugnu B 5,600.00 67.08 108.27 3,319.19 -2,299.04 2,837.77 3,480.07 1.75 -0.34 Ass 5,700.00 66.75 106.41 3,358.41 -2,326.46 2,925.57 3,571.83 1.75 -0.33 -1.87 5,800.00 66.44 104.53 3,398.13 -2,350.93 3,014.02 3,663.11 1.75 -0.31 -1.88 5,864.45 66.26 103.31 3,423.99 .2,365.13 3,071.32 3,721.65 1.75 -0.29 -1.88 Ugnu A _ 6222018 10,46.29AM Page 4 COMPASS 5000.14 Build 85 { Schlumberger ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 1H-108 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: 1H-108 actual @ 92.99usft (Doyon 142) Project: Kupamk River Unit MD Reference: 1H-108 actual @ 92.99usft (Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Rig: 111-108 Survey Calculation Method: Minimum Curvature Wellbore: 1H -108A Azimuth Depth Design: 1H-108Awp01 Section Rate Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/S +E/ -W Section Rate Rate Rate (usft) (') (') (usft) (usft) (usft) (usft) (°1100usft) ('1100usft) ('/100usft) 5,900.00 66.16 102.64 3,438.33 -2,372.44 3,103.01 3,753.83 1.75 -0.28 -1.89 6,000.00 65.90 100.75 3,478.96 -2,390.96 3,192.49 3,843.90 1.75 -0.26 -1.89 6,100.00 65.66 98.85 3,519.99 -2,406.48 3,282.35 3,933.25 1.75 -0.24 -1.90 6,158.08 65.53 97.74 3,543.99 -2,414.11 3,334.69 3,984.77 1.75 -0.22 -1.91 Na 6,200.00 65.45 96.94 3,561.38 -2,418.98 3,372.51 4,021.78 1.75 -0.21 -1.91 6,300.00 65.26 95.02 3,603.08 -2,428.46 3,462.90 4,109.41 1.75 -0.19 -1.91 6,400.00 65.09 93.11 3,645.07 -2,434.89 3,553.43 4,196.07 1.75 -0.16 -1.92 6,500.00 64.95 91.18 3,687.30 -2,438.28 3,644.01 4,281.66 1.75 -0.14 -1.92 6,541.75 64.90 90.38 3,704.99 -2,438.79 3,681.82 4,317.07 1.75 -0.12 -1.93 Hold for 419.66' 6,546.47 64.90 90.38 3,706.99 -2,438.82 3,686.09 4,321.06 0.00 0.00 0.00 WS_D 6,600.00 64.90 90.38 3,729.70 -2,439.14 3,734.57 4,366.32 0.00 0.00 0.00 6,676.13 64.90 90.38 3,761.99 -2,439.59 3,803.51 4,430.69 0.00 0.00 0.00 WS_C 6,700.00 64.90 90.38 3,772.11 -2,439.74 3,825.13 4,450.88 0.00 0.00 0.00 6,746.86 64.90 90.38 3,791.99 -2,440.01 3,867.56 4,490.50 0.00 0.00 0.00 WS -13 6,800.00 64.90 90.38 3,814.53 -2,440.33 3,915.68 4,535.44 0.00 0.00 0.00 6,838.81 64.90 90.38 3,830.99 -2,440.56 3,950.83 4,568.25 0.00 0.00 0.00 WS -A4 6,900.00 64.90 90.38 3,856.94 -2,440.92 4,006.24 4,619.99 0.00 0.00 0.00 6,961.41 64.90 90.38 3,882.99 -2,441.29 4,061.85 4,671.92 0.00 0.00 0.00 Start 3'/100' DLS, 0' TF, for 824.48' - WS_A3 7,000.00 66.06 90.38 3,899.01 -2,441.52 4,096.96 4,704.70 3.00 3.00 0.00 7,100.00 69.06 90.38 3,937.17 -2,442.13 4,189.38 4,791.00 3.00 3.00 0.00 7,200.00 72.06 90.38 3,970.45 -2,442.75 4,283.66 4,879.04 3.00 3.00 0.00 7,232.88 73.05 90.38 3,980.31 -2,442.95 4,315.03 4,908.33 3.00 3.00 0.00 WS A2 7,300.00 75.06 90.38 3,998.75 .2,443.38 4,379.56 4,968.58 3.00 3.00 0.00 7,400.00 78.06 90.38 4,021.98 -2,444.01 4,476.81 5,059.39 3.00 3.00 0.00 7,500.00 81.06 90.38 4,040.10 -2,444.66 4,575.14 5,151.21 3.00 3.00 0.00 7,600.00 84.06 90.38 4,053.05 -2,445.31 4,674.29 5,243.78 3.00 3.00 0.00 7,700.00 87.06 90.38 4,060.79 -2,445.97 4,773.97 5,336.86 3.00 3.00 0.00 7,785.89 89.64 90.38 4,063.26 -2,446.53 4,859.82 5,417.02 3.00 3.00 0.00 Hold for 107.69' 7,800.00 89.64 90.38 4,063.35 -2,446.62 4,873.93 5,430.20 0.00 0.00 0.00 7,893.48 89.64 90.38 4,083.94 -2,447.24 4,967.41 5,517.48 0.00 0.00 0.00 Start 2.6°1100' DLS, 0.6' TF, for 14.51' 7,900.00 89.80 90.38 4,063.98 -2,447.28 4,973.92 5,523.57 2.50 2.50 0.03 7,908.00 90.00 90.38 4,063.99 -2,447.33 4,981.92 5,531.03 2.50 2.50 0.03 Adjust TF to -0.04', for 294.44' 8,000.00 92.30 90.38 4,062.14 -2,447.94 5,073.90 5,616.92 2.50 2.50 0.00 8,100.00 94.80 90.38 4,055.95 -2,448.60 5,173.69 5,710.11 2.50 2.50 0.00 8,200.00 97.30 90.38 4,045.41 -2,449.25 5,273.13 5,802.95 2.50 2.50 0.00 8,202.44 97.36 90.38 4,045.10 -2,449.27 5,275.54 5,805.21 2.50 2.50 0.00 Hold for 82.61' 8,285.05 97.36 90.38 4,034.52 -2,449.80 5,357.47 5,881.71 0.00 0.00 0.00 Start 2.6°/100' DLS, 0.01' TF, for 436.01' 8,300.00 97.73 90.38 4,032.56 -2,449.90 5,372.30 5,895.55 2.50 2.50 0.00 8,400.00 100.23 90.38 4,016.94 -2,450.55 5,471.06 5,987.77 2.50 2.50 0.00 &2212018 10:46:29AM Page 5 COMPASS 5000.14 Build 85 r Schlumberger ConocoPhi I I i ps Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 1H-108 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: 1 H-108 actual @ 92.99usft (Doyon 142) Project: Kuparuk River Unit MD Reference: 1 H-108 actual @ 92.99usft (Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Rig: 1H-108 Survey Calculation Method: Minimum Curvature Wellbore: 111-108A Azimuth Depth Design: 1 H -108A vvp01 Section Rate Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S *El -W Section Rate Rate Rate (usft) (°) (°) (usft) Wait) (usft) (usft) (°1100usft) (°7100usft) (°1100usft) 8,426.65 100.90 90.38 4,012.06 -2,450.72 5,497.26 6,012.23 2.50 2.50 000 WS -A2-2 8,500.00 102.73 90.38 3,997.03 -2,451.19 5,569.05 6,079.27 2.50 2.50 0.00 8,600.00 105.23 90.38 3,972.87 -2,451.83 5,666.07 6,169.86 2.50 2.50 0.00 8,700.00 107.73 90.38 3,944.50 -2,452.45 5,761.95 6,259.39 2.50 2.50 0.00 8,721.06 108.26 90.38 3,937.99 -2,452.59 5,781.98 6,278.09 2.50 2.50 0.00 Hold for 526.67' 8,732.08 108.26 90.38 3,934.54 -2,452.65 5,792.45 6,287.86 0.00 0.00 0.00 WS -A3-2 8,800.00 108.26 90.38 3,913.25 -2,453.08 5,856.94 6,348.09 0.00 0.00 0.00 8,875.89 108.26 90.38 3,889.47 -2,453.55 5,929.01 6,415.38 0.00 0.00 0.00 WS -A4-2 8,900.00 108.26 90.38 3,881.92 -2,453.70 5,951.91 6,436.76 0.00 0.00 0.00 8,981.95 108.26 90.38 3,856.24 -2,454.21 6,029.73 6,509.43 0.00 0.00 0.00 WS B-2 9,000.00 108.26 90.38 3,850.58 -2,454.33 6,046.87 6,525.43 0.00 0.00 0.00 9,045.98 108.26 90.38 3,836.18 -2,454.61 6,090.53 6,566.20 0.00 0.00 0.00 WS_C-2 9,100.00 108.26 90.38 3,819.25 -2,454.95 6,141.83 6,614.10 0.00 0.00 0.00 9,163.47 108.26 90.38 3,799.36 -2,455.34 6,202.10 6,670.38 0.00 Coo 0.00 WS -13-2 9,200.00 108.26 90.38 3,787.91 -2,455.57 6,236.79 6,702.77 0.00 0.00 0.00 9,247.63 108.26 90.38 3,772.99 . -2,455.87 6,282.02 6,745.00 0.00 0.00 0.00 TD: 9247.63' MD, 3772.99' TVD 622/2018 10:46:29AM Page 6 COMPASS 5000.14 Build 85 Schlumberger ConocoPh i I I i ps Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 1H-108 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: 1H-108 actual Qa 92.99usft (Doyon 142) Project: Kuparuk River Unit MD Reference: 1H-108 actual @ 92.99usft (Doyon 142) Site: Kupamk 1H Pad North Reference: True Well: Rig: 1 H-108 Survey Calculation Method: Minimum Curvature Welibore: 1 H-1 08A Dip Dir. TVD Design: 1H-108Awp01 Northing Easting Design Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting -Shape V) 11 (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1H -108A T01 WSD 0621 0.00 0.00 3,704.99 -2,438.79 3,681.82 5,978,090.00 1,693,300.00 70° 21'4.474 N 149' 34' 14.201 W - plan hits target center -Circle (radius 100.00) 1H -108A T05 WSD 0621 0.00 0.00 3,772.99 -2,455.87 6,282.02 5,978,090.00 1,695,900.00 70° 21'4.289 N 149° 32'58.205 W - plan hits target center - Circle (radius 1,320.00) 1 H-1 08A T05 WSD 0621 0.00 0.00 3,772.99 -2,455.87 6,282.02 5,978,090.00 1,695,900.00 70° 21'4.289 N 149° 32' 58.205 W - plan hits target center - Circle (radius 100.00) 1 H-1 08A T02 A3 06211 E 0.00 0.00 3,882.99 -2,441.29 4,061.85 5,978,090.00 1,693,680.00 70" 21'4.447 N 149° 34'3.094 W - plan hits target center - Circle (radius 100.00) 1H -108A T02 A3 06211E 0.00 0.00 3,882.99 -2,441.29 4,061.85 5,978,090.00 1,693,680.00 70° 21'4.447 N 149° 34'3,094 W - plan hits target center - Circle (radius 1,320.00) 1H -108A T04 A3 06211E 0.00 0.00 3,937.99 -2,452.59 5,781.98 5,978,090.00 1,695,400.00 70" 21'4,325 N 149'33'12.819 W - plan hits target center - Circle (radius 100.00) 1 H-1 08A T03 A2 06211 E 0.00 0.00 4,063.99 -2,447.33 4,981.92 5,976,090.00 1,694,600.00 70° 21'4,382 N 149" 33'36.203 W - plan hits target center - Circle (radius 1,320.00) 1 H-1 08A T03 A2 06211E 0.00 0.00 4,063.99 -2,447.33 4,981.92 5,978,090.00 1,694,600.00 70° 21'4.382 N 149° 33'36.203 W - plan hits target center - Circle (radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name () ( ) 1,834.00 1,767.05 10 3/4" 10-3/4 13-1/2 6222018 10:46:29AM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Database: Company: Project: Site: Well: Wellbore: Design'. Formations Plan Annotations OAKEDMP2 ConocoPhillips (Alaska) Inc. -Kupt Kupawk River Unit Kupamk 1H Pad Rig: 111-108 1H -108A 1 H -108A wp01 Measured Vertical Local Coordinates Depth Depth +NI -S (usft) (usft) (usft) 1,876.75 1,803.99 T3 2,163.06 2,037.99 K15 4,778.91 3,020.99 Ugnu C 5,589.21 3,314.99 Ugnu B ' 5,864.45 3,423.99 UgnuA 6,158.08 3,543.99 Na 6,546.47 3,706.99 WS_D 6,676.13 3,761.99 WS_C 6,746.86 3,791.99 WS_B 9,163.47 3,799.36 WS—D-2 6,838.81 3,830.99 WS—A4 9,045.98 3,836.18 WS—C-2 8,981.95 3,856.24 WS B-2 6,961.41 3,882.99 WS—A3 8,875.89 3,889.47 WS—A4-2 8,732.08 3,934.54 WS A3-2 7,232.88 3,980.31 WS A2 8,426.65 4,012.06 WS—A2-2 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Name Lithology, Measured Vertical Local Coordinates Depth Depth +NI -S +E/ -W (usft) (usft) (usft) (usft) 1,950.00 1,866.31 -233.66 359.95 3,235.41 2,601.25 -928.77 1,098.73 3,845.51 2,749.97 -1,377.84 1,484.02 6,541.75 3,704.99 -2,438.79 3,681.82 6,961.41 3,882.99 -2,441.29 4,061.85 7,785.89 4,063.26 -2,446.53 4,859.82 7,893.48 4,063.94 -2,447.24 4,967.41 7,908.00 4,063.99 -2,447.33 4,981.92 8,202.44 4,045.10 -2,449.27 5,275.54 8,285.05 4,034.52 -2,449.80 5,357.47 8,721.06 3,937.99 -2,452.59 5,781.98 9,247.63 3,772.99 -2,455.87 6,282.02 Comment Schlumberger Standard Proposal Report Well Rig: IH -108 1 H-108 actual @ 92.99usft (Doyon 142) 1 H-108 actual @ 92.99usft (Doyon 142) True Minimum Curvature Dip Dip Direction V) ) KOP: 3.5"/100' DLS, 23.8° TF, for 1285.41' Hold for 610.1' Start 1.75'/100' DLS, -111.31' TF, for 2696.24' Hold for 419.66' Start 3.1100' DLS, 0° TF, for 824.48' Hold for 107.59' Start 2.5°/100' DLS, 0.6° TF, for 14.51' Adjust TF to -0.04°, for 294.44' Hold for 82.61' Start 2.5"/100' DLS, 0.01" TF, for 436.01' Hold for 526.57' TD: 9247.63' MD, 3772.99' TVD 622/2018 10: 46'29AM Page 8 COMPASS 5000.14 Build 85 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Rig: 1H-108 1H -108A 500292360800 1 H -108A wp01 ConocoPhillips Clearance Summary Anticollision Report 21 June, 2018 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad -Rig: 1H-108-1H-108A-1H-108Awp01 Well Coordinates: Datum Height: 1 H-108 actual @ 92.99usft (Doyon 142) Scan Range: 1,950.00 to 9,247.63 usft. Measured Depth. Scan Radius is 1,120.86 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 wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips ConocoPhillips Anticollision Report for Rig: 1H-108 - 1 H -108A wp01 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk lH Pad -Rig: 1H-108-1H-108A-1H-108Awp01 Scan Range: 1,960.00 to 9,247.63 usft. Measured Depth. Scan Radius is 1,120.86 usft. Clearance Factor cutoff is Unlimited, Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measuretl 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 Kuparuk 1H Pad 1H -05 -1H -05-1H-05 1,954.92 100.25 1,954.92 55.10 2,025.00 2.220 Clearance Factor Pass - Major Risk 1H -05 -1H -105-1H-105 1,953.27 99.41 1,953.27 54.26 2,025.00 2.202 Clearance Factor Pass - Major Risk 1H -09 -1H -09-1H-09 4,225.54 160.84 4,225.54 48.51 3,650.00 1.432 Centre Distance Pass - Major Risk 1H -09 -1H -09-1H-09 4,319.22 165.27 4,319.22 42.54 3,750.00 1.347 Clearance Factor Pass - Major Risk 1H -101 -1H -101-1H-101 4,242.91 248.88 4,242.91 167.90 4,150.00 3.074 Clearance Factor Pass - Major Risk 1H -101 -1H -101-1H-101 4,277.21 246.28 4,277.21 170.64 4,200.00 3.256 Centre Distance Pass - Major Risk 1H -101-1H-101 Ll -1H-101 L1 4,242.91 248.88 4,242.91 167.90 4,150.00 3.074 Clearance Factor Pass - Major Risk 1H -101-1H-101 L1 -1H-101 L1 4,277.21 246.28 4,277.21 170.64 4,200.00 3.256 Centre Distance Pass - Major Risk iH-1D1-1H-101 L2 -1H-101 L2 4,242.91 248.88 4,242.91 167.90 4,150.00 3.074 Clearance Factor Pass - Major Risk 1H -101-1H-101 L2 -1H-101 L2 4,277.21 246.28 4,277.21 170.64 4,200.00 3.256 Centre Distance Pass - Major Risk 1H -101-1H-101 L3-iH-101 L3 4,242.91 248.88 4,242.91 167.90 4,150.00 3.074 Clearance Factor Pass - Major Risk 1H -101-1H-101 L3 -1H-101 L3 4,277.21 246.28 4,277.21 170.64 4,200.00 3.256 Centre Distance Pass - Major Risk 11-1-101-iH-101 L4 -1H-1011-4 4,242.91 248.88 4,242.91 167.90 4,150.00 3.074 Clearance Factor Pass - Major Risk 1H -101-1H-101 L4 -1H-101 L4 4,277.21 246.28 4,277.21 170.64 4,200.00 3.256 Centre Distance Pass - Major Risk 1H -102 -1H -102-1H-102 3,425.54 126.40 3,425.54 69.90 3,250.00 2.237 Centre Distance Pass - Major Risk 1H -102 -1H -102-1H-102 3,497.11 128.02 3,497.11 59.89 3,325.00 1.879 Clearance Factor Pass - Major Risk 1H-102-1H-102LI-iH-10211 3,425.54 126.40 3,425.54 69.90 3,250.00 2.237 Centre Distance Pass - Major Risk 1H -102 -1H -102L1 -1H-10211 3,497.11 128.02 3,497.11 59.89 3,325.00 1.879 Clearance Factor Pass - Major Risk 1H -102 -IH -10212 -1H -102L2 3,425.54 126.40 3,425.54 69.90 3,250.00 2.237 Centre Distance Pass - Major Risk IH -102 -1H -1021 -2 -1H -102L2 3,497.11 128.02 3,497.11 59.90 3,325.00 1.679 Clearance Factor Pass - Major Risk IH -102 -1H -1021.3 -1H -102L3 3,425.54 126.40 3,425.54 69.90 3,250.00 2.237 Centre Distance Pass - Major Risk 1H -102 -1H -1021-3-1H-10213 3,497.11 128.02 3,497.11 59.90 3,325.00 1.879 Clearance Factor Pass - Major Risk 1H-102-1H-102L4-iH-10214 3,425.54 126.40 3,425.54 69.90 3,250.00 2.237 Centre Distance Pass - Major Risk 1H-102-iH-102L4-1H-102L4 3,497.11 128.02 3,497.11 59.90 3,325.00 1.879 Clearance Factor Pass - Major Risk 1H -103 -IH -103-1H-103 1,969.50 133.40 1,969.50 104.05 1,925.00 4.544 Centre Distance Pass - Major Risk 1H -103 -1H -103-1H-103 3,128.66 187.21 3,128.66 101.32 3,025.00 2.179 Clearance Factor Pass - Major Risk 1H-103-1H-1031-1-1H-103LI 1,969.50 133.40 1,969.50 104.05 1,925.00 4.544 Centre Distance Pass - Major Risk 1H-103-1H-103L1-iH-103LI 3,128.66 187.21 3,128.66 101.32 3,025.00 2.179 Clearance Factor Pass - Major Risk 21 June, 2018 - 15:37 Page 2 of 6 COMPASS ConocoPhillips Anticollision Report for Rig: 1H-108 -1 H -108A wp01 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad -Rig: 1H-108-iH-108A-1H-108Awp01 Scan Range: 1,950.00 to 9,247.63 usft. Measured Depth. Scan Radius is 1,120.86 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit 21 June, 2016 - 15:37 Page 3 of 6 COMPASS 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 1H -103 -1H -103L2 -1H-1031_2 1,969.50 133.40 1,969.50 104.05 1,925.00 4.544 Centre Distance Pass - Major Risk 1H -103 -1H -103L2 -1H-10312 3,128.66 187.21 3,128.66 101.32 3,025.00 2.180 Clearance Factor Pass - Major Risk 1H-103-iH-103L3-1H-103L3 1,969.50 133.40 1,969.50 104.05 1,925.00 4.544 Centre Distance Pass - Major Risk 1H -103 -1H -1031.3 -1H -103L3 3,128.66 187.21 3,128.66 1D1.32 3,02500 2.180 Clearance Factor Pass - Major Risk 1H-103-1H-103L4-iH-103L4 1,969.50 133.40 1,969.50 104.05 1,925.00 4.544 Centre Distance Pass - Major Risk 1H -103 -1H -103L4 -1H-10314 3,128.66 187.21 3,128.66 101.32 3,025.00 2.180 Clearance Factor Pass - Major Risk 1H -109 -1H -109-1H-109 1,957.40 102.12 1,957.40 68.06 1,975.00 2.998 Clearance Factor Pass - Major Risk 1H-11 - 1 H-11 - 1H-11 4,256.32 189.95 4,256.32 64.04 3,775.00 1.509 Centre Distance Pass- Major Risk 1H-11-iH-11-1H-11 4,278.42 190.06 4,278.42 63.95 3,800.00 1.507 Clearance Factor Pass - Major Risk 1H -110 -IH -110-1H-110 1,961.67 206.12 1,961.67 158.52 1,975.00 4.331 Clearance Factor Pass - Major Risk 1H -110 -1H -110-1H-110 1,961.67 206.12 1,961.67 158.52 1,975.00 4.331 Clearance Factor Pass - Major Risk 1H -111 -1H -111-1H-111 1,956.87 245.91 1,956.87 211.28 2,000.00 7.101 Clearance Factor Pass - Major Risk 1H-113-1H-113-iH-113 1,971.57 358.72 1,971.57 321.75 2,025.00 9.704 Clearance Factor Pass - Major Risk 1H -114 -1H -114-1H-114 1,955.03 380.85 1,955.03 347.47 2,050.00 11.412 Clearance Factor Pass - Major Risk 1H -12 -1H -12-1H-12 2,504.68 144.85 2,504.68 79.39 2,475.00 2.213 Clearance Factor Pass - Major Risk 1H -13 -1H -13-1H-13 3,318.96 341.78 3,318.96 250.52 2,900.00 3.745 Centre Distance Pass - Major Risk 1H -13 -1H -13-1H-13 3,390.45 347.22 3,390.45 242.47 3,000.00 3.315 Clearance Factor Pass - Major Risk 1H -15 -1H -15-1H-15 3,486.27 182.33 3,486.27 62.43 3,450.00 1.521 Clearance Factor Pass - Major Risk 1H-15-iH-15-1H-15 3,526.69 179.38 3,526.69 72.82 3,500.00 1.683 Centre Distance Pass - Major Risk 1H -21 -1H -21-1H-21 2,773.15 419.69 2,773.15 338.97 2,750.00 5.199 Clearance Factor Pass - Major Risk 1 H-401 (UGNU) - 1 H-401 - 1 H-401 1,950.00 1,016.74 1,950.00 976.38 2,675.00 25.195 Clearance Factor Pass - Major Risk Plan: 1H -106 -Plan: 1 H-1 06 - 1 H-1 06wp22 1,965.61 666.99 1,965.61 634.81 2,125.00 20.726 Clearance Factor Pass - Major Risk Plan: 1H -107 -Plan: 1 H-1 07 - 1 H-1 07wp22 1,958.06 709.51 1,958.06 676.27 2,175.00 21.349 Clearance Factor Pass - Major Risk Plan: 1H -112 -Plan: 1H-112 - 1H-112wp22 1,950.00 403.74 1,950.00 373.84 2,125.OD 13.504 Clearance Factor Pass - Major Risk Plan: 1H -112 -Plan: 1 H-112 - 1H-112wp23 1,957.98 520.58 1,957.98 492.54 2,175.00 18.561 Clearance Factor Pass - Major Risk Plan: IH -115 -Plan: IH-115-1H-115wp21 1,954.05 417.93 1,954.05 386.16 2,075.00 13.157 Clearance Factor Pass - Major Risk Rig: 1H -108 -1H -108-1H-108 2,274.21 20.70 2,274.21 8.86 2,275.00 1.748 Clearance Factor Pass - Major Risk 21 June, 2016 - 15:37 Page 3 of 6 COMPASS ConocoPhillips Anticollision Report for Rig: 1H-108 -I H -108A wpO1 Survey tool proaram From To Survey/Plan (usft) (usft) 120.48 1,266.38 1,361.99 1,750.03 1,847.94 1,950.00 1,950.00 3,500.00 1H-108Awp01 1,950.00 9,247.63 1H-10BAwp01 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. 21 June, 2018 - 15.37 Page 4 of 6 Survey Tool GYD-GC-SS MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit COMPASS 15:39, June 212016 1H-108A wp01 Ladder View 0 o 300 -7i 0 i ,200 — , i - ci' 1 �' it •. � 0 '100 0100- 0 0 2850 3800 4750 5700 6650 7600 8550 Measured Depth SURVEY PROGRAM CASING DETAILS Depth FrcBepth To Survey/Plan Tool No casing data is available 120.48266.38 1 H-108 Srvy 1 - SLB_GS/V®70;VFt36108) 1361.99750.03 1 H-108 Srvy 2 - SLB_NVAfIZI4-81 6&444 viA1D8)C 1847.94950.00 1 H-108 Srvy 3 - SLB_MRN03 GIMMK4eAZ)8)3 1950.00500.00 1 H-108A wp01 (1 H-10WD 1950.08247.63 1H-108Awp01 (1H-10WD+IFR-AK-CAZ-SC m 0 x c9 0 m n d U d c , 0 , c , U 0 2000 2250 2500 2750 3000 3250 3500 3750 Partial Measured Depth 16:09, June 21 2018 1 H-1 08A wp01 1950.00 To 9247.63 AC Wells Only 1H-101 �q fgi L2 1 1H-102L2 iNal ff'PL �H-10 H4 0aa1 FI 110 03 03L2 - 1H-103 1H- 1H-11 1H-115wp21 c 0- 0 1 - 1 2 1H-113 c r 1ff-1 0 0 z iH-110 1H-401 } w 21 H-13 M-1 1H-15 1H-108A wp 1 1H-1-07wp22 1H-106wp22 tki-09 1H-11 Easting (2000 usfUin) AC Flipbook i O m CL LL 0 0 0 M O F- O O O r VM CD CL 3 20 co O 1 2 0 t!7 O 0 V 0 M M 0 M 0 N 0 N d1 co 0 O M M 0 m M 0 O M M 0 a O V� 0 O M 0 m Nt d' 0 O 00 It 0 O a Lo L O M m 0 a7 r U) 0 O N co 0 00 r co 0 M N r 11 0 r r r` 0 M N Ow 0 M� r 0 N a7 1 O O M Hill O g c- N O t (Y) N O M Lr) N O N r N O N O N O � � M 1 O CD M M O Lf) Lo M 11 O O 00 M't O LQ O O O M V O Lo Lo 19t Wil O OLf) 00 V O O L0Lr) O O CO O O 1— Lo O O N M O O r M O O N r O r r r O co N 00 O co !� 00 W rl- N I co UONOM000(D OOpO 06M6— U LL VJ N LL 00000000 C7+ + + OOOO Q m N Wok O' Q r N WMroWmaOroW N M M M M M M M M M �� 3 M Q wNM (7 N��O�00100�6�0�616� {- M O O O (O Z m C �p��tn�OCOO��COM oa�nr�m�ovooco co �n ,nov W NI�O�M ONi U U �O�UJ r-��MmN�� amrn 0q Z ONN�6>I�cO�ONNI�N �MMMCD I�I�I�NOJN 61 0 �1�00 LL N M V� N I i 0 CL 0 CDO Q Q :ri L0 I -- CD C) CDN r O CL 3 00 0 1 2 1P 0 LC) 6' 0 T N 0 qt M N 0 M Ln N 0 N 1� N 0 N O= N r M 0 O M M 0 LO Ln M 0 O QO M 0 Ln O V 0 O M C' 0 LO Ln V 0 O w It 0 to O Ln f- O M L.0 0 O Il- LO 0 M N (D 0 W ti (D� 0 W N 0 r ti t` 0 M N 00 0 O r- 00 0 d' N 0 O O Lr) O N O N O Co N O N N O N N O CO O (D co O Lf) (� O O M O Ln d' O O V O LO Mt O O d' O Ln OO O O LD O M LO� O 0 O 00 O O W ti� O 1- O O 00 O OD 0 M, I ]L NL 1L o Q Q d M m UOOOM000(00000 a� U LL LLLLO M 0 0 0 0 0 0 0 0 K U' ++ + J m F N �_ 0 C) CIDp C) CID W 'NMrr c00�W roM W W w W p U aN0)61000000000 d ~0:5 :a :52 Y Zof NMMmOl 61�0]6]�610] kp-t�"1000c0 L(p0001� N m N NO�-��OMOV�COM t0 X110 V NM �OVNf� VOJVOVOO(O zo) �m(N')A U p O6In— (n groin VOO p �fJM7aCOM 000 NNV pV mO>Oo Z p�NO �p�f�ro6�NNI�N 0�1�00 MMM(Orr�MM�m I i 0 0^ w 45 r O Q 3 Co O 2 iG O N O N O M N O 0 N O r- N O M N co O OM M O LO LO M O a W M O O '[t O CO CD d' O 0 O N V O O LO i t- MM 0 I O � 0 O N O O OD O O ONO r O � ti O N� 0 O O0 M N 0 O O to O V N O d' N O M N O N N O N N O M O O M O 0 M O O co M O LO V O O V O LO V O O d' O LO OLO O O LO O O LO O O 0 O O 0 O M ti O ti I- O 0 O O 0 O W I d m UONOMOOOt00000 U �>Cl W w NON WN N(YnM M mMM M M M >2 F Q N M "M Mm Q N M 00:52 �° N6�m000000000 f M O O O t0 Z L (p O O O h N N ❑O��tn SOI OJOV�(OM (O h 2O Y OV��VN70 VOO(O M M U U 0��6MNNO�I� g NTV00 0 �M7�(OWp000JNV pVmrnoo Z p�NM�mf�roO�N Nf�N O I�00 �MMcO (O I�I�I�o�o�Wm I ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad Rig: IH -108 500292360800 11-1-108A Plan: 1 H-1 08A wp01 Error Ellipse Survey Report 22 June, 2018 Schlumberger Error Ellipse Report leg ConowPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Ri Company: +N/ -S Reference: Hell actual @ 92.89usft (Doyon 142) Project: Kuparuk River UnitND 0.00 usft Easting: 1 H-108 actual 92.99usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: Ground Level: 54.00 us _ Well: Rig: 114-108 North Reference: Survey Calculation Method: True Minimum Curvature Wellbore: 1H -108A Output errors are at 1.00 sigma Design: 1 H -108A wp01 OAKEDMP2 Database: Project Kuparuk River Unit, North Slope Alaska, United States System Datum: Mean Sea Level Map System: Using Well Reference Point Geo Datum: Using geodetic scale factor Map Zone: Site Kuparuk 1 H Pad Northing: Latitude: Site Position: Longitude: From: Map Easting: 0" Gdtl Convergence: 0.37 ° Position Uncertainty: 0.00 usft Slot Radius: leg Rig: 1H-108 Tie On Depth: 1 950.00 fell Position +N/ -S 0.00 usft Northing: Latitude: (usft) +E/ -W 0.00 usft Easting: Longitude: osition Uncertainty 0.00 0.00 usft Wellhead Elevation: Ground Level: 54.00 us _ Wellbore 1H -108A Magnetics Model Name BGGM2017 Design Audit Notes: Version: Vertical Section: Survey Tool Program From (usft) 120.48 1,361.99 1,847.94 1,950.00 1,950.00 1H -108A Wp01 Sample Date Declination (°) 6/1/2018 Dip Angle (°1 17.08 80.93 Field Strength (nT) 67,467 Phase: PLAN Tie On Depth: 1 950.00 Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 38.99 0.00 0.00 111.35 Date 6112/2018 To (usft) Survey (Wellbore) 1,266.38 1H-108 Srvy 1-SLB_GWD70 (1H-108) 1,750.03 1 H-108 Srvy 2 - SLB _MWD+GMAG (11-1-1 1,950.00 1 H-108 Srvy 3 - SLB_M WD+GMAG (1 H-1 3,500.00 1 H-1 08A W p01 (1 H-1 08A) 9,247.63 1H -108A wp01 (1H -108A) Tool Name Description GYD-GC-SS Gyrodata gyro single shots MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 6222018 10:59:42AM Page 2 COMPASS 5000.14 Build 85 Company: ConocoPhillips(Alaska) Inc.-Kup1 Project: Kupawk River Unit Site: Kuparuk 1 Pad Well: Rig: 1H-108 Wellbore: 111-108A Design: 1H -108A WP01 Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Plan Survey Tool Program Date 8/22/2018 Depth from Depth To lust) (usft) Survey (Wellbore) Tool Name Remarks 1 120.48 1,266.38 IH -108 Srvy1-SLB_GWD70(I GVD-GC-SS Gyrodate gyro single shots 2 1,361.99 1,750.031H-108 Sly 2 -SLB MWD+GM MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3 1,847.94 1,950,001H-108 Srvy 3-SLB_MWD+GM MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 1,950.00 3,500.00 1H -108A wp01 (1H -108A) MWD MWD - Standard 5 1,950.00 9,247.63 IH-108AWPOI (111-108A) MWD+IFR-AK-CAZ-SC Measured Inclination DePlti (usttl 1.95000 2,00000 2100.00 2,163.% 2.210.00 MWD+IFR AK CAZ SCC Well Rig: 1H-108 1 H-108 actual @ 92.99usft (Doyon 142) 111-108 actual @ 92.99usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station Measured Inclination DePlti (usttl 1.95000 2,00000 2100.00 2,163.% 2.210.00 1°1 32.82 34.43 3]68 39.74 40.% Aalmum I') 122.26 123.51 12573 128.% 12764 vertical mpe, 4usft) 1,886.31 190].95 1988.]9 2,03].89 2,%8.14 ..,Wde Eear Bias (uaft) Juan) 1.68 0.11 168 -011 16] -013 1.69 -0.15 189 -0.15 4Hera1 Eeor (usft) 260 2.60 3.14 392 3.92 Bias (usft) 007 OW 0.26 0.47 047 WBiwl E4r9r lust) 110 1.10 1.10 1.11 1.11 Bus lum) 043 0./3 D.47 050 0.50 Magnitude Semlmai0r of Bias Error luzftl lumtl 046 260 046 260 0.57 3.1/ 0.72 392 0]2 392 semlmfner Emr WIIu91 T0o1 (ust) (°) 1w 12530 MWD(1.4) 194 12530 MM(1, 4) 1.97 12472 MWD (1,Q 2.03 125.17 MM (1, 4) 203 125.1] MWD (1, 4) 2,300.00 2,400.00 2,500.00 2.800.00 2,700.00 46.27 4781 50.93 54.32 57]0 129.31 13079 132.13 133.34 134./5 2,139.73 2,209.26 2,274.49 2,335,16 2.391.06 1.76 1.% 2.00 2.18 2.38 -0.17 -0.19 0.22 -0.24 -027 4.88 5.95 7.15 842 976 070 097 1.28 158 1.92 1.16 134 1.35 1.51 170 0.54 0.57 0.81 0.64 066 093 1.10 1.46 1.)] 2.11 488 59a 7.17 845 9.79 210 2.19 229 240 2.51 125.99 MM (1, 4) 128.89 MM (1. 4) 127.78 MWD(114) 12083 MM (1. 4) 12943 MWD (1, 4) 28(10.00 2900.00 3,000.00 3,100.00 3.20000 61.00 6448 e).0] 71.28 ]468 135.49 136.46 13].3] 13824 139.08 2,44197 2,48)]1 2528.10 2,56299 2,59226 2.59 282 3.% 3.31 358 -0.30 -0.33 -037 -0.42 -0,47 11.15 1250 14.05 15.54 17.05 229 260 3.08 350 394 1.93 2.18 2.46 2.]6 107 069 071 0.73 0]5 0.76 247 2.86 3.27 389 4.13 1119 1266 14.12 1563 17.15 262 273 2.83 292 100 130.19 MM (1. 4) 130.0 MM (1, 4) 131.5] MWD (1, 4) 132.21 MWD (1, 4) 13281 MWD (1, d) 3,235.41 3,30000 3, tDO,OO 3,50000 3,600.00 75.89 7589 7589 75.89 75.09 13937 139.37 139.37 1393) 13637 2,601.25 2,61700 2.641.37 2,%575 2,690,12 3.64 3.85 4.21 4.55 263 -0.49 -0.49 -049 -049 -058 1759 18W 20 .10 2177 9.39 4.10 439 4.85 531 -009 3.19 3.40 3.]4 4% 2.36 076 0.77 0]8 079 0.80 429 458 S.OJ 549 1.12 1770 18.70 20.2] 21.85 942 3.03 307 3.16 3.20 256 133.02 MWD (1, 4) 133.30 MM (1. 4) 13387 M (1.4) -6C (2, 4) 134.29 MWDHFR-AK-CAZSC 134.68 MW IFR-AK-CAZ-SC(2,6) 3,]0000 3,800.00 3,84551 3.00.OD 4,000.00 75.89 75.89 75.89 75.55 7492 139.37 139.3] 139.37 138.45 136.76 2,71450 2]38.8] 2,]498] 2,763.41 2.788.90 2.79 2.95 3.03 3.13 331 .0.59 -0.59 -059 -058 -0.57 995 10.52 1017 11.04 11.45 -0.09 -0.09 -0.09 -008 0.05 2.53 2.69 2]6 2.85 301 0.81 0.83 0.83 ON 0.05 1.16 1.21 1.22 125 129 8.98 10.54 10.00 1105 11.45 2.59 262 2.63 265 267 13501 MWDHFR-AK-CAZ-SC 12, 4) 135.30 MW4HIFR-AK-CAZ-SC(2,4) 13542 MW IFR-AK-CAZSC(2,4) 13553 MWD+IFR-AK-CK-SC (2, d) 13584 MWD-IFR-AK-CAZ-SC(2,4) 4,100.00 4300.00 4,3000D 4,400.00n.56 4,500.00 74.31 ]372 7313 72.01 13506 13335 13183 129.90 128.16 2,815.42 2.842.97 2,871.50 2,%0.99 2,931.42 3.49 3.88 3.07 4% 6.26 .0.56 A.54 -0 .53 -0.52 -0.50 11.% 12.29 12.72 1116 13.59 4).02 0.01 0.0/ 000 0.11 3.18 3.36 3.50 3.67 383 086 086 089 0.91 093 134 1.38 143 148 1.54 11.87 12.30 12]5 1322 1169 2.70 273 2.]8 2,80 2.83 135.70 MM.IFR-AKLAZ-SC(2.4) 13580 MWDHFWAK-CAZ-SC(2,4) 135.61 MIFR-AK-CAZ-SC(2,4) 135.48 MWDHFR-AN-CIS-SC (2, 4) M 13526 MWDNFR-AK-OAZ-SC(2.4) 4.600.00 71.47 128.40 2,96276 446 -0.49 14.02 015 3.99 094 159 14.18 287 13500 MWOHFR-AK-CAZ-S0(2,4) 8/222018 10..59:42AM Page 3 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -KUP1 Project: Kupan3k River Unit Site: Kuparuk lH Pad Well: Rig: 1H-108 Wellbore: 1H -108A Design: 1H-10BAWP01 Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Rig: 1H-108 1 H-108 actual @ 92.99usft (Doyon 142) 1 H-108 actual @ 92.99usft (Doyon 142) True Minimum Curvatura 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station Menuree IncrinMion NP[h Waal 4,]0000 4,778.91 4,800.00 4,900.00 5.00000 5,10000 5,200.00 5,300.00 5.400.00 5,Onto 5.589.21 5fi6000 5,]00.00 5,80000 5,864.45 5 ,90000 5 ,00.00 510000 515808 8,200.00 B=w 840000 8,500.00 5541]5 8,546.4] 6,60000 6.676.13 6,]00.00 6,746.86 6,800.00 8,030.01 6.90.00 6,%141 7,000.00 7,100.00 7200 7,232.88 1300.00 7,40.00 7,50000 7,600.00 ]]0.00 ],]85.89 ]8 00 7,893.48 7,900.00 7,908.% 50W-00 8.1000 8,20000 8,202.64 8,28505 0,3000 8400.00 Azimuth Vertical OepN r) rl (-an) 70.95 12484 2,994.97 70.55 12324 3,020.99 70.// 122.86 3.028.03 6995 121.08 3061.91 69.48 119.28 3.096.58 69.03 11]./7 3.131.99 68.0 11565 3,168.13 68.19 113.82 3.204.95 6180 111.96 3,242.43 67,43 110.13 328052 8].11 100.68 3,31/.99 6100 108.2) 3.319.19 68.]5 108.61 3,35841 %.M 104.53 3,398.13 66.26 103.31 3./23.99 68.16 ]0051 34J0.33 6590 102.]5 3436% 6590 90.85 3.519.99 85.53 Was 3,54399 6545 %94 3,56138 65.26 9502 3,W3.W 65.09 93.11 3,6450) 6495 91.18 3.88].30 64.0 90.J8 3,]04.99 64.90 0.38 3]06.99 6490 9038 3,72970 64.90 0.30 3,]8199 64.0 9038 3,]]2.11 6490 9030 3,791.0 64,90 9038 3.814.0 61.90 90.38 3.030.98 84.90 90.38 3,85894 64.90 90.38 3.882.99 65.0 9038 3,89901 69.0 9038 3,937.17 7252 90.38 3970.45 7305 90.38 3,90031 75.0 0.38 3,998.]5 78M 90.38 4,021.90 81.06 90.30 4,010.10 64.06 9038 4,053.05 87.% 0.30 40039 09.84 9038 4,0328 8964 0.3B 4,06335 8986 90.38 4,063.94 8980 9038 4,03.90 90.0 90.38 4.00399 9230 90.30 4.062.14 96.0 90.38 4,05595 97.30 9038 4,04541 97% 9038 4,015.10 9138 9038 4,03452 9].]3 90.36 /,032.58 10.23 90.38 4,018,94 Hig0si4e Ertor (waft) 667 4.89 469 5.11 5.33 5.57 5.81 805 631 657 884 6.64 ].11 ].40 7.69 169 198 8.20 859 8.59 80 021 9.52 9.66 9.]4 974 em 9.08 10.02 10.02 10.18 10.16 10.25 10.17 998 9.80 963 963 9.48 9.34 9.23 9.14 9.08 9.11 9.27 9.2) 926 9.26 9.27 9.30 9.30 944 9.44 949 Bias (waft) -040 -043 -0.67 -0.46 445 -044 4./3 -0.42 .0.41 -040 440 -0.40 -040 439 -0.39 -0.39 -039 -040 -040 -0.40 -0./1 -062 -0.43 -0.43 443 -043 -0.43 .0.43 -043 -0.43 -0.43 -043 .043 -049 -065 -081 4.97 -09) -1.13 -129 -1.46 -182 -1.]6 -178 -176 -177 -1.78 -1.90 -201 -2.17 -2.ti -2.1] -2.19 -232 Island Ertor (vise 14.45 14.08 1488 15.29 1530 16.09 164) 1684 17.20 17.53 11W 17.86 18.18 1845 1871 18.]1 18.% 19.19 leis 19.39 1956 19]4 19.80 19.9J 20.25 20.25 20.79 20.79 21.36 21.34 21.09 21.89 22.23 22.44 2300 23.57 24.14 2414 24.72 2529 25.85 26.40 288] 26.94 27.45 27.48 27.53 28.02 28.54 2905 29.0 2948 29.50 3008 Bias (usft) 0.19 0.23 0.23 0.28 032 037 042 047 0.52 0.58 083 063 0.69 0.75 081 0.81 0.0) 094 1.01 1.0 1.0)76.68 111 1.2 1.244 124 1.24 1.24 1.24 1.24 124 124 1.24 1.24 1.24 124 124 1.24 1.24 124 124 1.24 124 124 1.24 124 124 1.24 1.24 1.24 124 1.24 1.24 1.24 1.24 Vanicar Error (ustt) 4.16 432 432 448 4.84 480 4.96 5.12 528 543 5.59 559 535 5.90 806 6W 6.21 6.3) fi52 6.52 6.03 6,83 698 ]OS 113 ].13 7.29 129 7.44 144 ].59 7.59 1% 7.74 190 806 8.22 822 839 8.56 8.73 8.91 905 908 924 925 9 26 9.42 960 974 9.]] 9.92 994 10.11 Mngniwae semimajor semimina Bias of Blas Ertor Ertor 1Ul0 TOW (usft) (usft1 (usft1 (usft) 1'1 0% 154 14.6] 2.90 13469 MWDNFR-AK-CAZ-SC(2,4) 0.98 1.70 15.17 2.95 134.31 MND+IFR-AK-CAZSC (2, d) 0.98 1.70 15.17 295 13434 MND+IFR-M-CA -SC (2.4) 100 1.76 1567 299 13394 MWD+IFR-AK-CAZ-$C(2.4) 1.03 1.82 16.17 3.03 in 50 MWD+IFR-AK-CAZ-SC(2,4) 1.05 1.00 1860 3.08 13303 MWD+IFR AK -0 2-SC(2,4) 1.07 190 1].19 3.14 132.52 MWWIFR-AK-CAZ-SC(2,Q 1.10 2.01 17.69 3.19 13199 MWD*IFR-AK-CPZ-SG (2, 4) 112 207 18.20 325 131.43 MWD+1FR-AK-CALSC(2.4) 1.15 2.14 18.70 3.31 130.84 MWD+IFR-AK-CMSC(2.4) 1.18 220 1921 J38 13024 MND+IFR-MRC -SC (2,4) 1.18 2.20 1921 3.38 13024 MWD+IFR-AK-GAZ-SC (2, 47 1.20 2.2] 19.]0 345 129.61 MND+IFR-AK-CM 1.23 2.34 20.20 3.52 1288] MWD+IFR-AK-CAZ-SC (2, 4) 1.26 241 2089 380 128.31 MWD+1FR-AK-0AZSC(2,4) 1.2fi 2.41 20.69 3.60 128.31 MWD+IFR-AK-CAZ-SC(2.4) 1.30 240 21.18 368 12183 MND+IFR-AK-CAZ-SC(2,4) 1.33 256 21.% 3.]6 12894 MWD+IFR-AK-cAZ-SC(2,4) 1,36 2.63 22.13 3.85 126.24 M=+IFR-AK-CM 13 2.83 22.13 3.85 128.24 MWD+IFR-AK-CAZ-SC(2.q 1.399 2.70 22.60 3.95 125.53 MND+IFR-AK-CAZ-SC(2,Q 143 238 23.52 405 12480 MWD+IFR-A AZ-SC(2A) 148 2.05 23.52 4.15 124.0] MWD+IFR-AK-CAZ-SC (2,4) 140 2.88 23.71 /.19 123]6 MWDNFR-AK-CPZ-$CSC (2, 4) 1.00 2.93 23,97 /24 123.34 MWD+IFR-AK-CAZ-S (2,4) 150 293 239] 4.24 123.34 MWD+IFR-A&CAZ-SC(2,4) 1.54 3.01 2444 4.29 12285 MWD+IFR-AK-CAS (2,4) 1.54 3.01 2440 6.29 122.fi5 MNIO+IFR-AK-CAZ-BC (2, 4) 1.57 3.M 24.91 4.35 121.98 MWL»IFR-N(-CAZ-SC(2,4) 1.57 3.09 24.91 435 12198 MNDAFR-N(-CA-SC(2,41 1.61 117 2538 441 12133 MWD+IFR-AK-CAZ-SC(2.4) 1.61 3.1] 25.38 4.41 12133 MND+IFR-AK-CAZ-SC(2,4) 104 3.22 2588 645 120.96 MWD+IFR-AK-CAZ-SC (2,q 165 325 25.86 4.47 120.70 MWD+1FR-AK-CIS-SC(2, 4) 1.60 333 2635 4.54 12008 MVVDNFR-AK-CAZ-SC (2,4) 171 340 26.05 460 119.47 MWD+IFR-AK-0AZSC(2.4) in 3.47 27.36 4.67 118.88 MM+1FR-AK-CAZ-SC0.4) 1.73 3.47 27.36 4.67 11868 MW IFR- -C-0-SC (2.4) 1.75 3.54 2186 d.]2 11830 MVJD+IFR-AK-CPZ-SC (2. d) 1.76 360 28.37 4.00 11)]5 MWDNFR-AK-CAZ-SC(2,4) 137 166 2887 4.81 117.22 MWD+1FR-AK-CAZ-SC(2.4) 1.78 371 29.38 4.85 11671 MWD+IFR-ARCAZ-SC(2,4) 1.)8 3.75 29]8 488 116.29 MWD+IFR-AK-CAZ-SC(2. 4) 178 3]5 29.04 4.% 116.22 MWD+IFR-AK-CM-SC (2Q 178 380 3030 491 11578 MWD+IFR- -GL -SC (2.4) 178 3.80 30.33 4.92 115.75 MND+IFR-AK-CM-SC(2.4) 1.70 3.80 30.3] 492 115]2 MWDNFR-AK-CAZ-S(2,Q 178 304 30.81 4.95 11530 MWDNFR-AK-CPZ-SC(2.4) 1 7 388 31.28 4.97 114.87 MWD+IFR-AK43AZSC(2,4) 17] 391 3174 500 11/.46 MWD+IFR-AK-CA-SC(2,4) 177 391 3175 50 114.45 MVVDNFR-AK-CM-SC(2,4) 1.74 394 32.13 5.02 114.12 MWD+IFR-AK-CAZ-SC(2,4) 1.77 3.94 3220 503 1140 MWDNFR-AK-CPZ-SC (2.Q 1.76 397 3265 5.05 Men MWD+IFR-AK-CAZ-W(],d) 622/2018 10:59:42AM Page 4 COMPASS 5000,14 Build 86 Company: Con000Phillips(Alaska) Inc.-Kup1 Project: Kuparuk River Unit Site: Kupamk 1 H Pad Well: Rig: 1H-108 Wellbore: 1 H-1 08A Design: 1 H-1 08A wp01 Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Rig: 1H-108 1 H-108 actual @ 92.99usft (Doyon 142) 1 H-108 actual @ 92.99usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station Measured Depth (.an) Inclination l°) A9malh (°) vesical Depth luau) Hi9hsMe E., sits (van) (usft) "Wool Error Ivan) alas (ush) vesical E., luali Blas (osn) Magnitude of sins Nah) saulmalor Eno, (uth) eemiminor Eno, Nasi Azimuth Tool (") 84213.85 0,500.00 8,600.00 8j%.% 8)21.06 108.90 102,73 105.23 107.73 108.26 90.38 90.38 9038 90.38 80.38 4,012.% 3,997.03 3.972.87 3,944.50 3.937.99 9.55 9.55 9.83 9.72 9.74 .245 -2.45 -2.58 -2.70 -2.72 30.55 30.55 31.M 31.48 31.50 1.24 1.24 1.24 124 124 1028 1028 1045 10.62 10.65 1.75 1.75 1.75 1.74 1.74 3.99 3.89 4.01 482 4.02 3310 33.10 33.53 33.95 34.03 588 5.08 5.10 5.13 513 11330 MVM -IFR -MC -SC (2.4) 113.30 MVVD+lFR-AK-CAZ-SC(2,4) 11295 MwD+IFR-AR-CAZ-&C(2,4) 11261 MWDNFR-AK-CAZ-SC(2,4) 112.54 MND+IFR-AK-CAZ-W(2,4) 8,73208 8alow 8,875.89 8,900.00 8,901.95 10828 10826 108.2(1 106.26 109.26 90.30 9038 NMI 90.38 90.38 3,934.54 3,913.25 3,88947 3881.92 3,856.24 9.86 9.86 10.02 1002 10.17 -2.72 -272 -272 -272 .2.72 31,94 3194 3240 32.40 3286 1.24 124 1.24 1.24 1.24 10.70 10.78 10.94 10.94 11.10 174 174 1.73 1.73 1.73 40 4.03 404 404 4.05 3436 3436 U.78 3478 35.20 5.16 $16 5.19 5.19 523 112.28 MM+IFR-Ali-CAZSC(2,4) 11228 MVa0+1FR-AK-CAZSC(2,4) 111.95 M0➢tIFR-AK-CAZSC(2,4) 111.95 MMICMFR-AK-0AZ-SC(2.4) 111.63 MWDNFR-AK-CAZ-50(2,4) 9,00.00 9.04598 9,10003 9,163.47 9.20D 00 108.26 108,213 10826 108.26 108.26 9038 90.38 90.38 9030 90.38 3,850.58 3,836.18 3,819.25 3,79938 3,767.91 10.17 10,33 10.33 10,49 10.49 -2.72 -2.72 -2,72 -2.72 -222 3286 33.33 33.33 33.80 3380 124 124 1.24 124 1.24 11.10 11.26 11.26 11.42 1142 1.73 1.73 1.73 132 1]2 405 405 408 4.07 4.07 35.20 35.63 35.63 08.08 Won 5.23 5.27 527 5.31 5.31 11163 M=+1FR-AK-CAZ-SC(2,4) 111.31 MND+IFR-AK-CAZ-SC(2,4) 111.31 MMHFR-AK-CAZ-W(2.4) 111.00 Mw IFR-AK-CAZ-SC(2,4) 111.00 MN IFR-AK-0AZSC(2,4) 9,247.63 108.26 90.38 3,772.99 1057 .2.72 34.03 1.24 11.49 V2 4.07 3827 533 110.85 MVJDNFR-AK-CAZ-SC(2,4) Design Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N1S +E1 -W Northing Easting -Shape (°) (') (vitt) (usft) (usft) (usft) (usft) Latitude Longitude 1 H-108AT01 WSD 0621 0.00 0.00 3,704.99 -2,438.79 3,681.82 5,978,090.00 1,693,300.00 70° 21'4.474 N 149° 34' 14.201 W - plan hits target center - Circle (radius 100.00) 1 H-1 08A T05 WSD 0621 0.00 0.00 3,772.99 -2,455.87 6,282.02 5,978,090.00 1,695,900.00 70° 21'4+289 N 149° 32' 58.205 W - plan hits target center - Circle (radius 1,320.00) 1H -108A T05 WSD 0621 0.00 0.00 3,772.99 -2,455.87 6,282.02 5,978,090.00 1,695,900.00 70° 21'4.289 N 149° 32' 58.205 W - plan hits target center - Circle (radius 100.00) 1 H-1 08A T02 A3 06211E 0.00 0.00 3,882.99 -2,441.29 4,061.85 5,978,090.00 1,693,680.00 70° 21'4,447 N 149° 34'3.094 W - plan hits target center - Circle (radius 100.00) 1 H-1 08A T02 A3 06211E 0.00 0.00 3,882.99 -2,441.29 4,061.85 5,978,090.00 1,693,680.00 70° 21'4.447 N 149° 34'3+094 W - plan hits target center - Circle (radius 1,320.00) 1 H-1 08A T04 A3 06211E 0.00 0.00 3,937.99 -2,452.59 5,781.98 5,978,090.00 1,695,400.00 70° 21'4.325 N 149° 33' 12.819 W - plan hits target center - Circle (radius 100.00) 1 H-1 08A T03 A2 06211E 0.00 0.00 4,063.99 -2,447.33 4,981.92 5,978,090.00 1,694,600.00 70" 21'4.382 N 149" 33'36.203 W - plan hits target center - Circle (radius 1,320.00) 1H -108A T03 A2 06211E 0.00 0.00 4,063.99 -2,447.33 4,981.92 5,978,090.00 1,694,600.00 70° 21'4.382 N 149" 33' 36.203 W - plan hits target center - Circle (radius 100.00) 6222018 10:59:42AM Page 5 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -KUP1 Project Kupamk River Unit Site: Kupamk 1H Pad Well: Rig: 1H-108 Wellbore: 1H -108A Design: 1H-108AWP01 Casing Points Formations Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: output errors are at Database: Well Rig: 1H-108 1 H-108 actual Q 92.99usft (Doyon 142) 1H-108 actual @ 92.99usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Casing Hole Measured Vertical Diameter Diameter Depth Depth (usft) (usft) Name 10-3/4 13-1/2 1,834.00 1,767.05 10 3/4" Measured Vertical Local Coordinates Depth Depth +N1 -S (usft) (usft) (usft) 2,163.06 2,037.99 K15 4,778.91 3,020.99 Ugnu C 5,589.21 3,314.99 Ugnu B 5,864.45 3,423.99 UgnuA 6,158.08 3,543.99 Na 6,546.47 3,706.99 WS_D 6,676.13 3,761.99 WS_C 6,746.86 3,791.99 WS_B 9,163.47 3,799.36 WS D-2 6,838.81 3,830.99 WS A4 9,045.98 3,836.18 WS—C-2 8,981.95 3,856.24 WS B-2 6,961.41 3,882.99 WS A3 8,875.89 3,889.47 WS_A4-2 8,732.08 3,934.54 WS_A3-2 7,232.88 3,980.31 WS A2 8,426.65 4,012.06 WS A2-2 'lan Annotations Checked By. Name Measured Vertical Local Coordinates Depth Depth +N1 -S +El -W (usft) (usft) (usft) (usft) 1,950.00 1,866.31 -233.66 359.95 3,235.41 2,601.25 -928.77 1,098.73 3,845.51 2,749.97 -1,377.84 1,484.02 6,541.75 3,704.99 -2,438.79 3,681.82 6,961.41 3,882.99 -2,441.29 4,061.85 7,785.89 4,063.26 -2,446.53 4,859.82 7,893.48 4,063.94 -2,447.24 4,967.41 7,908.00 4,063.99 -2,447.33 4,981.92 8,202.44 4,045.10 -2,449.27 5,275.54 8,285.05 4,034.52 -2,449.80 5,357.47 8,721.06 3,937.99 -2,452.59 5,781.98 0 1a, a1 1777 99 -2.455.87 6,282.02 Approved By: Dip Dip Direction Lithology (1) (1) Comment KOP: 3.5°/100' DLS, 23.8" TF, for 1285.41' Hold for 610.1' Start 1.75"/100' DLS, -111.31° TF, for 2696.24' Hold for 419.66' Start 3°/100' DLS, 0- TF, for 824.48' Hold for 107.59' Start 2.5°/100' DLS, 0.6° TF, for 14.51' Adjust TF to -0.04°, for 294.44' Hold for 82.61' Start 2.5°/100' DLS, 0.01- TF, for 436.01' Hold for 526.ST TD: 9247.63' MD, 3772.99' TVD Date: 6/222018 10:59:42AM Page 6 COMPASS 5000.14 Build 85 Pool Report i O O os g g o m� VUUUV UU Q O O O 4 O O r i ge°i s w 60-11 O � O n O o s 00 a o oy�go 333aa 00 as yi S! _ C noO A.t LOd 0 rte. 9�Ht ao <o _ r�£OL, F=ttt N z ttt7 7� a n�� H� O O a e n M q O v 6E 0 f�•> T�Bf�f 20 m 6 v �+ LL O a+ ON 3 O� 3 a� a� co O _ m o r O N O O O � m 0 G O O 0 O O O J O O O O O O O O O O �(ui/l}sn (+)y}aoN/(-)ulnog �' v OOOZ) E E M- F 0 I 1H-108Awp01 Surface Location Q CPAI Coordinate Converter From: Datum: NAD83 Region:alaska • Latitude/Longitude Decimal Degrees • UTM Zone: r-` (- South 4-- State Plane Zone: 4 Units: us -ft C Legal Description (NAD27 only) To Datum: NAD27 Region: alaska C Latitude/Longitude IDecimalDegrees 11 r UTM Zone: True r South (� State Plane Zone: I' � Units: us -ft r Legal Description (NAD27 only) --Starting Coordinates: ----- -— Ending Coordinates: ---- — -- X: 11689602.60 X: 549570.976245029 Y: 15980504.33 Y: 5980752.52152466 ................................ _...1 ,Transform :. Quit Help I 1H-108Awn01 Surface Casina I 8 CPAI Coordinate From -------- ---. ----- Datum: NAD83 Region: alaska r Latitude/Longitude Decimal Degrees C' UTM Zone: f— r South r State Plane Zone: F--:-:] Units us—f (" Legal Description (NAD27 only) 4@ Datum: NAD27 Region: alaska C Latitude/Longitude IDecimalDegrees r UTM Zone: True r South r State Plane Zone: q - I Units: us -ft r Legal Description (NAD27 only) - Starting Coordinates: -- Ending Coordinates:— X: oordinates: X: 11689912.88 X: 1549881.250222205 Y: 15980304.37 Y: 5980552.56036882 Transform j Quit Help 1H-108Aw 01 Sidetrack Point L� CPAI Coordinate Converter a From: -__-..._____------__.-... _._ -To:- Datum NAD83 Region: jalaska Datum: NAD27 Region: alaska . i Latitude/Longitude Decimal Degrees` --- r Latitude/Longitude IDecimalDegrees�� C UTM Zone: ! j- South ( r UTM Zone: True (— South I * State Plane Zone:q Units: us -ft . C• State Plane Zone: q . Units: us -ft . * Legal Description (NAD27 only) C Legal Description (NAD27 only) Starting Coordinates: --- — --- Ending Coordinates: X: 11689964.05 ( X: 549932.41923845 y 15980273.06 Y. 5980521.25013937 -- Transform Quit Help 1H-108Aw 01 Top of Production Horizon B CPAI Coordinate Converter o From.---------- - To: -. - Datum: INAD83 Region: alaska Datum: INAD27 I Region: jalaska 11 C' Latitude/Longitude IDecimalDegrees �� r Latitude/Longitude Decimal Degrees C UTM Zone: r South r UTM Zone: True F South C•- State Plane Zone: F------3 Units: us -ft r State Plane Zone: F___-] Units: us -ft {' Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates:— Ending Coordinates:— X: 11693421.69 X: 553389.991371883 Y: 15970090 Y: 15978338.17650335 I Transform:71 fruit Help 1 H-108Awp01 TD Ct. CPAt Coordinate Converter o O From: Datum: NAD83 Region: alaska * Latitude/Longitude IDecimalDegrees —� * UTM Zone: �— r South * State Plane Zone: F-73- Units: fusft i^ Legal Description (NAD27 only) To: Datum: INAD27 I Region: Fa—la—,k—a----,l C Latitude/Longitude Decimal Degrees r UTM Zone: True r South C� State Plane Zone:q Units: us it [" Legal Description (NAD27 only) Starting Coordinates: --- E nding Coordinates'. X: 11695900 X: 555868.263131698 Y: 15978090 Y: 5978338.12981672 .................Transform........._.._....; Quit Help I 1H-108Awp01 Surface Location I M CPAI Coordinate Converter Datum: NAD83 - Region: alaska * Latitude/Longitude IDecimalDegrees —� f UTM Zone: South * State Plane Zone:q Units: us -It r Legal De::criptior, LNAC27 nnly) =in -To: Datum: NAD27 Region: alaska f Latitude/Longitude Decimal Degrees r UTM Zone: True r South r State Plane Zone:q Units: us -fl C Legal Description (NAD27 only) Starting Coordinates:--- - Legal X: 11689602.60 Y: 15980504.33 1H-108Awp01 Surface Casin Description------ --- ----- Township: 012 FN—, -1 Range: 010 E Meridian: U Section:28 FNL 5230.4878 FEL 1770.33475 Yransform-::�: Quit Help M CPAI Coordinate Converter l o (E Ill From: --- -----. -.. - _ _- Datum:NAD83 Region: alaska • Latitude/Longitude IDecimalDegrees • UTM Zone: I — r South G' State Plane Zone: q - Units: us -ft C Legal DF,nription (NAD27 only) - Starting Coordinates: X: 11689912.88 Y: 15980304.37 Datum: NAD27 Region: alaska (" Latitude/Longitude IDecimal Degrees r UTM Zone: True r- South I- State Plane Zone: q i Units: us -ft G Legal Description (NAD27 only) Legal Description -- — Township: 012 N Range: 010 E Meridian: P -D Section: 33 FNL .1 152.53488 JFEL 1461.81426 Transform Quit Help 1 1H-108AwDO1 Sidetrack Point I Q CPAI Coordinate Converter Datum: NAD83 Region: alaska . * LatitudOLongitude IDecimalDegrees * UTM Zone: r— I- South C• State Plane Zone: rq Units: us -ft . r Legal De=nu�diun (R1AC)2 or�lvl Starting Coordinates: — --- -- X: 11689964.05 Y: 15980273.06 To Datum: NAD27 Region: alaska r Latitude/Longitude IDecimalDegrees�� i C UTM Zone: True r- South • State Plane Zone: F---3 Units: us -it l-- Legal Description (NAD27 only) Legal Township: 012 FN—,—i Range: 010 E Meridian: U Section: 33 FNL . 1194.1097 f—FEL--'-1 1410,91490 Transform Quit Help 1H-108Awp01 Top of Production Horizon Elt CPAs Coordinate Converter -From:-----.. _ Datum: NAD83Region: (alaska _ r Latitude/Longitude IDecimaiDegfees�� r UTM Zone: r— F South rC State Plane Zone: F ---J Units: PST r Legal Dezcriptroti trIAD27 onl, l Starting Coordinates: —---- --- X: 11693421.69 y 15978090 00 To: Datum: INAD27 Region: alaska r Latitude/Longitude IDecimalDegrees • UTM Zone: True r South r State Plane Zane: 1' Units: us -ft . C.Legal Description (NAD27 only) Legal Description------- Township: escription -Township: 012 N Range: 010 V-.] Meridian:U Section:34 FNL 2391.2739 FEL 2252.4283 Transform 1 0uit Help 1H-108Awp01 TD M CPAP Coordinate Canverter [ o I 0 . 1J From: Datum: NAD833 Region: alaska Latitude/Longitude Decimal Degrees f UTM Zone: F— r South C% State Plane Zone:q Units: us -ft r Legal Description (NAD27 only) Starting Coordinates: -- X: 11695900 Y: 15970090 To. Datum: NAD27 Region: jalaska T C'- Latitude/Longitude IDecimalDegrees, • UTM Zone: True r South • State Plane Zone: q Units: us -ft Cs Legal Description (NAD27 only) -Legal Description— Township: escription Township: 012 N . Range: 01p Meridian: Section: 35 FNL 2409.3958 FEL - 5054.0117 ........................ansf.................................... .Trorm Quit Help Tollerable Collision Risk Worksheet As -built EV I DATE I BY CK APP DESCRIPTION IREV DATE BY r CK APP DESCRIPTION 1 2/05/0 MRT I CC I IRev. Per K05014ACS 2 102/01/IA J I LGM I Rev. Per K170005ACS N25 DS1H 30 29 28 27 2° IG _ 36 31 IH 3. ELEVATIONS ARE B.P.M.S.L. HCS 32 33 34 35 36 i *14 PROTRACTED SECTIONS 28 AND 33, /� �5 TlIN OE 912 UMIAT MERIDIAN, ALASKA. 5 6 4 3 2 5. ®120 1 ASGRID NORTH 0119 2 7 CPF1 10 satin 916 0118 6 s „ z e13 0117 ALL DISTANCES SHOWN ARE GROUND. •1 4+0 0116 *2 07 0115 918 18 7 16 15 14 1� 0114 GRAPHIC SCALE 1E LEGEND 0113 0112 100 200 400 to In 2A 24 19 20 21 2 23 0 AS—BUILT CONDUCTOR 0111 ®110 VICINITY MAP • EXISTING CONDUCTOR 0109 SCALE: 1" = 2 MILES 0104 SEE SHEET 2 & 3 FOR COORDINATE TABLE 0108 0103 28 27 ._wi07 33+ 34 ConocoPhillips 0102 0106 DS1H 0101 WELL CONDUCTOR NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSOC. DS1H 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. *UGNU 01 4• ALL CONDUCTORS ARE LOCATED WITHIN *14 PROTRACTED SECTIONS 28 AND 33, �5 TOWNSHIP 12 NORTH, RANGE 10 EAST, 020 912 UMIAT MERIDIAN, ALASKA. 019 *22 e11 5. DATES OF SURVEY: 12-26-16 THRU *10 1-31-17 FIELD BOOKS L16-35, L16-40, *17 *6 L17-02 & 1_17-03. 916 *21 e15 e13 6. ALL DISTANCES SHOWN ARE GROUND. •1 •9 *2 07 03 918 GRAPHIC SCALE 0 100 200 400 �8 •4 1 inch = 200 ft. SEE SHEET 2 & 3 FOR COORDINATE TABLE LOUNSBURY & ASSOCUM, INC. SI_1i Y.- ENGINEERS P -N MS AREA: IH MODULE: XXXX UNIT: Di ConocoPhillips DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FlLE NO. I DRAWING N0. __, _.,,,, PART: I REV: 1 1 12/05/051MRT I CC I IRev. Per K05014ACS 1 2 102/01/171 JAH I LGM I IRev. Per K170005ACS 1 CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 33, T. 12 N., R. 10 E., UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geo ra hic Coordinates Section Offset. Elev. Y X Lot. Long. F.N.L F.E.L.O.G. PAD 1 5,979,969.32' 549,197.55' N 70' 21' 21.836" W 149' 36' 01.664" 732' 1151' 49.9' 54.4' 2 5,979,939.43' 549,199.75' N 70' 21' 21.542" W 149' 36' 01.605" 762' 1149' 49.8' 54.2' 3 5,979,909.70' 549.201.04' N 70' 21' 21.249" W 149' 36' 01.573" 791' 1148' N/A N/A 4 5,979,789.20' 549,210.20' N 70' 21' 20.064" W 149' 36' 01.328" 911' 1140' N/A N/A 5 5,980,174.54' 549,543.27' N 70' 21' 23.832" W 149' 35' 51.517" 528' 803' N/A N/A 6 5,980,054.85' 549,551.90' N 70' 21' 22.654" W 149' 35' 51.288" 648' 796' N/A N/A 7 5,979,935.13' 549,560.55' N 70' 21' 21.476" W 149' 35' 51.058" 768' 788' N/A N/A 8 5,979,815.46' 549,569.18' N 70' 21' 20.299" W 149' 35' 50.829" 888' 781' N/A N/A 9 5,979,964.85' 549,559.64' N 70' 21' 21.769" W 149' 35' 51.079" 738' 789' 50.2' 54.6' 10 5,980,084.49' 549,550.97' N 70' 21' 22.946" W 149' 35' 51.309" 619' 796' 50.3' 54.4' 11 5,980,114.39' 549.548.80' N 70' 21' 23.240" W 149' 35' 51.367" 589' 798' 50.4' 54.3' 12 5,980,144.15' 549,546.49' N 70' 21' 23.533" W 149' 35' 51.428" 559' 800' 50.3' 54.3' 13 5,979,993.93' 549,557.42' N 70' 21' 22.055" W 149' 35' 51.138" 709' 791' 50.3' 54.4' 14 5.980,204.14' 549,542.05' N 70' 21' 24.123" W 149' 35' 51.547" 499' 804' 50.1' 54.2' 15 5,979,999.18' 549,195.34' N 70' 21' 22.130" W 149' 36' 01.722" 702' 1153' 50.0' 54.5' 16 5,980,029.08' 549,192.10' N 70' 21' 22.424" W 149' 36' 01.811" 671' 1156' N/A N/A 17 5,980,058.86' 549,191.00' N 70' 21' 22.717" W 149' 36' 01.838" 642' 1156' 49.7' 54.4' 18 5,979,904.84' 549,564.14' N 70' 21' 21.178" W 149' 35' 50.959" 799' 785' 50.4' 54.5' 19 5,980,118.88' 549.186.59' N 70' 21' 23.308" W 149' 36' 01.955" 582' 1160' 49.5' 54.6' 20 5,980,148.10' 549,183.14' N 70' 21' 23.595" W 149' 36' 02.050" 552' 1164' N/A N/A 21 5,980,024.57' 549,555.22' N 70' 21' 22.356" W 149' 35' 51.196" 679' 793' 50.2' 54.4' 22 5,980,089.04' 549,188.93' N 70' 21' 23.014" W 149' 36' 01.893" 612' 1158' 49.6' 54.7' UGNU 01 5,980,234.12' 549,542.20' N 70' 21' 24.418" W 149' 35' 51.536" 469' 804' 50.0' 54.1' *101 5,980,602.66' 549,581.92' N 70' 21' 28.040" W 149' 35' 50.304" 101' 761' 48.0' 54.0' *102 5,980,662.56' 549,577.46' N 70' 21' 28.630" W 149' 35' 50.423" 41' 765' 48.0' 54.0' *106 5,980,632.86' 549,579.90' N 70' 21' 28.337" W 149' 35' 50.357" 70' 762' 48.0' 54.0' *107 5,980,692.31' 549,575.52' N 70' 21' 28.922" W 149' 35' 50.474" 11' 766' 48.0 54.0' * CONDUCTOR ASBUILT THIS SURVEY LOUNSBURY x AMCUTE6, INC. IVRYOR9 RNGMEM PL NRRR AREA: IH MODULE: XXXX UNIT: U1 ConocoPhillips WELL DS1H CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FILE N0. DRAWING N0. PART: REV: LK6108d31 2/05/05 CEA-DIHX-6108D31 2 of 3 2 1 1 102/01/171 JAH I LGM I (Create Per K170005ACS I I I I I I CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28, T. 12 N., R. 10 E., UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geo ra hic Coordinates Section Offset. Elev. Y I X tat. Long. F.S.L F.E.L. O.G. PAD *103 5,980,722.55' 549,573.20' N 70' 21' 29.220" W 149' 35' 50.536" 19' 768' 48.0' 54.1' *104 5,980,782.43' 549,568.74' N 70' 21' 29.809" W 149' 35' 50.655' 79' 772' 48.0' 54.1' *108 5,980,752.52' 549,570.98' N 70' 21' 29.515" W 149' 35' 50.595" 49' 770' • 48.0' 54.0' *109 5,980,812.20' 549,566.50' N 70' 21' 30.102" W 149' 35' 50.714" 109' 774' 48.0' 54.0' *110 5,980,842.21' 549,564.40' N 70' 21' 30.398" W 149' 35' 50.770" 139' 776' 48.0' 54.0' *111 5,980,872.05' 549,562.21' N 70. 21' 30.691" W 149' 35. 50.828" 169' 778' 48.0' 54.1' *112 5,980,902.08' 549,559.94' N 70' 21' 30.987" W 149' 35' 50.889" 199' 780' 48.0' 54.0' *113 5,980,932.00' 549,557.76' N 70' 21' 31.281" W 149' 35' 50.947" 229' 782' 48.0' 54.0' *114 5,980,961.86' 5499555.50' N 70' 21' 31.575" W 149' 35' 51.006" 259' 784' 48.0' 54.1' *115 5,980,991.68' 5499553.43' N 70' 21' 31.868" W 149' 35' 51.062" 289' 786' 48.0' 54.1' *116 5,981,021.61' 549,551.58' N 70' 21' 32.163" W 149' 35' 51.110" 319' 787' 48.0' 54.1' *117 5,981,051.73' 549,548.80' N 70' 21' 32.459" W 149' 35' 51.185" 349' 790' 48.0' 54.0' *118 5,981,081.22' 549,546.95' N 70' 21' 32.750" W 149' 35' 51.234" 378' 791' 48.0' 54.0' *119 5,981,111.42' 549,544.52' N 70' 21' 33.047" W 149' 35' 51.299" 408' 794' 48.0' 54.2' *120 5,981,141.33' 549,542.48' N 70' 21' 33.341" W 149' 35' 51.353" 438' 795' 48.0' 54.1' * CONDUCTOR ASBUILT THIS SURVEY �`'• 49th AH F'CC LS -12663 !1�♦ SURVEYOR'S CERTIFICATE 1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY ....../ DONE BY ME OR UNDER MY DIRECT SUPERVISION AND 1 �A THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION JAF _ C ARE CORRECT AS OF JANUARY 31, 2017 Conocophillips Alaska, Inc. LOUNSBURY e ASSOCLITES, INC. IWR)RS ENGINEERS PLANNERS MODULE: XXXX DS1 H WELL CONDUCTOR CADD F1LE NO. DRAVANG N0. PART: REV: LK610801 12/27/16 CEA-DIHX-6108D31 1 3 OF 3 1 1 Appendix ■ Tier 1: Standard ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ Drilling within 300 of horizontal inclination AND drilling within 300 of magnetic East/West azimuth in extreme northern or southern locations ■ Tier 3: Critical Steering ■ Driller's Target of 50' Radius or Less ■ Lease line constraint ■ Small Geologic Target ■ Failure of Major Risk Rule (Close Approach) ■ Defined during directional planning, based on the positional uncertainty ■ Theoretical intersection of the path of the well being planned with an offset well ■ If HSE risks are eliminated, the Tolerable Collision Risk assessment can be implemented ■ Tier 4: Single section containing both Tier 2 and Tier 3 challenges • �- 6 33ss::= ConocoPhillips ■ Tier 1 (Standard): ■ Directional interval across which no special mitigations are needed ■ Tier 2 (Challenging Orientation): ■ Increase non-magnetic insulation of MWD tool in the BHA ■ Take rotational check shots and/or increase survey frequency at the start of a BHA run ■ Alter well directional plan, if feasible ■ Consider gyro surveys where feasible ■ Tier 3 (Critical Steering): ■ Increase survey frequency across critical interval ■ Increase correction frequency across critical interval ■ Take rotational check shots and/or increase survey frequency if the critical interval is at the start of a BHA run ■ Define escalation based on deviation from plan ■ Minor Risked close approach intervals with a high financial or scope risk should strongly consider the use of relevant mitigations ■ Tier 4 (Critical Steering & Challenging Orientation): ■ Consider all Tier 2 & 3 mitigations IH -108A Drilling Hazards Summary 8-3/4" Open Hole Hazard Risk Level Mitigation Strategy Running sands and gravels Low Maintain planned mud parameters, increase mud weight, use weighted sweeps. Stuck pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight. Abnormal reservoir pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, add LCM. Differential sticking Moderate Follow mud program, keep pipe moving when able. Anti -collision Moderate Follow real time surveys very closely. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pum ing out or back reaming. Getting casing to bottom Moderate Utilize proper drilling and hole cleaning practices, follow mud program. Fault crossings and concretions Moderate Use developed best practices for concretion drilling. 1H -108A Drilling Hazards.doc 6/22/2018 0 O n P= FUR a M oc A Insulated Conductor: 20" Casing Top of Kickoff Plug @ 1784' MD / 1,723' TVD Bunt of Kickoff Plug 2284' MD / 2,121' T Top of Abandonmen 3,550' MD / 2,870' f Btm of Abandor MD / 3,120' TV. Top of Abandon. MD / 3,277' TVI Burt of Abandc MD / 3,470'T' Top of Abanc MD / 3,470 Burt of Man MD / 3,729' Wellhead 13-3/8" SM 1 H-108 Injector Well Design Post -Abandonment Planned Wellbore Schematic i C @ 4,155'MD / 3120'TVD Top of N -Sand @ 5,208' MD / 3,528' TVD Top of WestSak D -Sand @ 5,735' MD / 3,729' TVD as $ r__ 8-3/4" Open Hole TD @ e s` 6,527' MD uff Wellhead 1 H n -108A Injector Well Desi C 13-3/8" SM 1 5 7 0 4C A Insulated Conductor: 20" Casing Top of Kickoff Plug @ 1784' MD / 1,723' TVD Btm of Kickoff Plug C@ 2284' MD / 2,128' TVD Top of Abandonment Plug #3 @ 3921' _] a MD / 2,771' TVD M v Ban of Abandonment Plug #3 @ 4 MI) /2,970'TVD , V7,7 Top of Abandonment Plug #2 @ 5,534' MD / 3,294' TVD Btm of Abandonment Plug #2 @ 6,034' /3, TVD Topop of Abandonment Plug #1 @ 6,034' MD 13,493' TVD Boo of Abandonment Plug #1 @ 6,547' MD / 3,707' TVD Pre -Drill Wellbore Schematic .� 10-3/4" 45.5#, L-80 HYD563 @ 1,834' MD - Existing 4—-- Top of Ugnu C prognosed @ 4,779' MD / 3021' TVD a a .q-- Top of N -Sand prognosed @ 6,158' MD / 3,544' TVD .t-- Top of WestSak D -Sand prognosed @ 6,547' MD / 3,707' TV D ,f_� 8-3/4" Open Hole Planned TD @ 9,248' MD 1014N 13TH :AG NMV80 inAa Attachment 5 BOP Configuration The following ram configuration will be utilized for the West Sak wells. Further details regarding the BOPE specifications can be found with the Doyon 142 documentation on file with the State. Loepp, Victoria T (DOA) From: Sent: To: Cc: Subject: Follow Up Flag: Flag Status: That will not be a problem at all. 10 minutes & charted? PT'O a/8 -oda Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Friday, June 29, 2018 3:32 PM Rixse, Melvin G (DOA); Lehman, Nick R Shumway, Kelsey; Doyon 142 Company Man; Davies, Stephen F (DOA); Herbert, Frederick 0; Schwartz, Guy L (DOA); Loepp, Victoria T (DOA); Regg, James B (DOA) RE: [EXTERNAL]RE: 1H -108A Sundry request to temporarily abandon - 1500 psi pressure test on kick off plug Follow up Flagged From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Friday, June 29, 2018 3:31 PM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Cc: Shumway, Kelsey <Kelsey.Shumway@conocophillips.com>; Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com>; Doyon 142 Company Man <d142cm@conocophillips.com>; Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Herbert, Frederick O <Frederick.O.Herbert@conocophillips.com>; Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Regg, James B (DOA) <j im. regg@a laska.gov> Subject: [EXTERNAL]RE: 1H -108A Sundry request to temporarily abandon - 1500 psi pressure test on kick off plug Kelsey, AOGCC will also require a 1500 psi pressure test on the top kick off plug before running the kill string. Please confirm. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin. Rixse@alaska.gov). From: Rixse, Melvin G (DOA) Sent: Friday, June 29, 201812:13 PM To:'Lehman, Nick R' <Nick.R.Lehman(@conocophillips.com> Cc: Shumway, Kelsey <Kelsev.Shumway@conocophillips.com>; Brunswick, ScottA <Scott.A.Brunswick@conocophillips.com>; Doyon 142 Company Man <d142cm@conocophiilips.com>; Stephen F Davies (DOA) (steve.davies@alaska.gov) <steve.davies@alaska.gov>; Herbert, Frederick O <Frederick.O.Herbert@conocophillips.com>; Guy L Schwartz (DOA) (guy.schwartz@alaska.gov) Nick R Lehmon(cDConocoP,,.., Ps.com From: Lehman, Nick R Sent: Thursday, lune 28, 2018 5:54 PM To:'Rixse, Melvin G (DOA)' <melvin rixse@alaska.sov> Cc: Shumway, Kelsey <Kelsev Shumway conocophillips.com>;'Scott Brunswick' <Scott.A Brunswick@conocophillips.com> Subject: 1H -108A Sundry request to temporarily abandon Mel, Attached is the sundry request to temporarily abandon 11-1-108A with the intent of performing a future sidetrack. As requested, I added in section of plugging back 11-1-108A that was originally in approved PTD into this Sundry request. I will have the original and 1 x copy delivered to AOGCC in the morning. As discussed, please let me know if you see any issues with this or if we have approval to proceed. Thanks, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick R Lehman ConocoPhillips.cam Davies, Stephen F (DOA) From: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Sent: Friday, June 22, 2018 6:36 PM To: Rixse, Melvin G (DOA) Cc: Loepp, Victoria T (DOA); Davies, Stephen F (DOA); Regg, James B (DOA); Fair, Holly S (DNR); Schwartz, Guy L (DOA) Subject: RE: [EXTERNAL]PTD(218-067) RE: 1H-108 Plugback and Sidetrack Proposal Thank you for your time and help with this Mel. Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick R Lehman ConocoPhillips.com From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Friday, June 22, 2018 3:45 PM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Regg, James B (DOA) <jim.regg@alaska.gov>; Fair, Holly S (DNR) <holly.fair@alaska.gov>; Schwartz, Guy L (DOA) <guy.schwartz@a laska.gov> Subject: RE: [EXTERNAL]PTD(218-067) RE: 1H-108 Plugback and Sidetrack Proposal Nick, AOGCC grants verbal approval for the planned lateral 1H -108A as in the attached document with the following additional requirements: 1. Bi -weekly BOPE test to 3500 psi 2. The final uppermost kick off plug must extend a minimum of 100' below the 10-3/4" casing shoe A completed PTD will be provided to CPAI early next week when business hours allow final processing. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231) or (Melvin Rixservlalaska.gov). cc. Steve Davies, Victoria Leopp, Jim Regg, Holly Fair, Guy Schwartz From: Lehman, Nick R [mailto•Nick R Lehman@conocophillips.com] Sent: Friday, June 22, 2018 12:21 PM To: Rixse, Melvin G (DOA) <melvin.rixseCdalaska.l;ov> Subject: RE: [EXTERNAL]PTD(218-067) RE: 1H-108 Plugback and Sidetrack Proposal Mel, Attached is signed PTD for 1H -108A. I am currently printing out extra copies and will deliver the original & 1 x copy to AOGCC office here shortly. Thanks, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick R Lehman@ConocoPhillips. corn From: Rixse, Melvin G (DOA) <melvin rixse@alaska.gov> Sent: Thursday, June 21, 2018 3:05 PM To: Lehman, Nick R <Nick R Lehman conocophillips.com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Regg, James B (DOA) <iim.regg@alaska.gov_>; Schwartz, Guy L (DOA) <guv.schwartzc@alaska.gov>; Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Doyon 142 Company Man <d142cm@conocophillips.com>; Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com>; Seamount, Dan T (DOA) <dan Seamount@alaska.gov>; French, Hollis (DOA) <hollis.french@alaska.gov> Subject: RE: [EXTERNAL)PTD(218-067) RE: 1H-108 Plugback and Sidetrack Proposal Nick, You have approval to proceed with the cement abandonment, as described in your attached scanned sundry request for 1H-108 PB1. AOGCC will expect to see your original sundry request later today. I will review your revised 10-401 for the alternate sidetrack after you deliver it tomorrow. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231) or (Melvin RixseC@alaska.gov). cc. Victoria, Jim Regg, Guy Schwartz, Steve Davies, Dan Seamount, Hollis French From: Lehman, Nick R [mailto:Nick R Lehman@conocophillips.coml Sent: Thursday, June 21, 2018 2:35 PM To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gop Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov_>; Regg, James B (DOA) <iim.regg@alaska.gov>; Schwartz, Guy L (DOA) <guv.schwartz@alaska.gov>; Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Doyon 142 Company Man <d142cm conocophillips.com>; Brunswick, Scott A <Scott A Brunswick@conocophillips.com> Subject: RE: [EXTERNAL]PTD(218-067) RE: 1H-108 Plugback and Sidetrack Proposal Melvin, Thanks for your feedback. Attached is finalized sundry request, the application will be submitted here shortly. Currently, we are backreaming OOH at —4300' MD. I'm expecting we'll be out of hole ready to start running in hole sometime late tonight. We are currently working the directional plan for the sidetrack — as soon as I have that finalized, I will submit the 10-401 for 1H -108A sidetrack. Thanks, Nick Lehman Drilling Engineer 1 ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Lehman@COnocoPhillips.com From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.aov> Sent: Thursday, June 21, 2018 12:20 PM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Regg, James B (DOA) <jim.regg@alaska.2ov>; Schwartz, Guy L (DOA) <guv.schwartz@alaska.eov>; Davies, Stephen F (DOA) <steve.davies@alaska.eov> Subject: [EXTERNAL]PTD(218-067) RE: 11-1-108 Plugback and Sidetrack Proposal Nick, As discussed on the phone, AOGCC will need the following: 1) Revised 10-401 if bottom hole location for new lateral is > 500' from the planned wellbore 2) 10-403 for the cement plug back of PB1 3) 24 hour notice to AOGCC for an inspector to witness of tag of cement plug at 3550' MD. The cement plug back drawing you submitted below shows adequate cementing for abandonment of the PB1 lateral. I would expect an approval for the 10-403 you will be submitting soon. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231( or (Melvin.RixsePalaska.gov(. cc. Victoria Loepp, Jim Regg, Guy Schwartz, Steve Davies From: Lehman, Nick R [mailto:Nick R Lehman@conocophillips.com] Sent: Thursday, June 21, 2018 10:26 AM To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.aov> Cc: Brunswick, Scott A <Scott.A.Brunswick @conocophiIli ps.com> Subject: FW: 1H-108 Plugback and Sidetrack Proposal Melvin, Based on Victoria's out -of -office reply, you are her point of contact until July 9th. Please see email below, I will give you a call shortly to discuss. Thanks, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick.R.Lehman@ConocoPhillips.com From: Lehman, Nick R Sent: Thursday, lune 21, 2018 10:23 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc:'Scott Brunswick' <Scott.A.Brunswick@conocophillips.com> Subject: 1H-108 Plugback and Sidetrack Proposal Victoria, Early this morning while drilling the 1H-108 WestSak injector, we encountered water in the WestSak sands. Based on what we've seen, we would like to plugback and sidetrack below surface casing to help with planning path forward for next producer. Below is a proposed schematic for cement plug depths with as -drilled formation tops listed to the side. I am working on the 10-403 sundry form, but I would like to discuss this with you when you have a minute. I will give you a call shortly. 10 3/4" SURF 11-1-108 Abandonment / Sidetrack Plan 1784 ft 50' above shoe 138 bbls / 500' kickoff plug 1834 ft Previous shoe 8.75oh 2284 ft 450' below shoe 38 bhIs/ 500' abandonment olue Thanks, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Lehmon pConocoftllips. com 5735 ft Top of WestSak D - wet 3550ft 250'TVDaboveUgnu 38 1)[31s / 500' Top of WestSak B - wet 6023 ft Top of WestSak A4 - wet abandonment plug Top of WestSak A3 - wet 4155 ft Top of Ugnu - hydrocarbons Hi -Vis Spacer TD 4557 ft 250' ND above N -sand 38 6 b N / 500' abandonment plug 5208 ft Top of N -Sand - hydrocarbons 38 bhIs/ 500' abandonment olue Thanks, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Lehmon pConocoftllips. com 5735 ft Top of WestSak D - wet 5845' ft Portion of WestSak D - h 5926 ft Top of WestSak B - wet 6023 ft Top of WestSak A4 - wet 6134 ft Top of WestSak A3 - wet 6359 ft Top of WestSak A2-hyd 6527 ft TD 5 TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: kI _12 c4zk d)le 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 0--- No. , API No. 50-_-_----. be function of the original (If last two digits (If Production should continue to reported as a in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name (_PH) and API number (50- - -� from records, data and logs acquired for well name on permig. 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' sam le 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 (Com _panv Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements / / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, ✓✓✓ composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL -490150 - -Well Name: KUPARUK RIV U WSAK 1H_108A__ _ _ _Program DEV _ __ Well bore seg ElALASKA I PTD#. 2180700 Company CONOCOPHILLIPS INC _- _ Initial Class/Type _ DEV / PEND _GeoArea 890 Unit 11160 On On/Off Shore Annular Disposal ❑ Administration 17 Nonconven. gas. conforms to AS31.05.0300A.A).0.2.A-D) - NA - - - - ....... .. ......... . Date: Commissioner: Date 1 Permit fee attached -.. --. -. _. NA -- - ----------- -- -. -.. -------- --- 4��,,L, 2 lease number appropriate. - Yes Surf Loc & Top Prod Int lie in ADL0025639; TO lies. in ADL0025638.- 3 Unique well. name and number ..... Yes - - - 4 Well located in defined pool Yes Kuparuk River, West Sak Oil Pool - 490150, governed by CO 406C - - - - - - 5 Well located proper distance from drilling unit boundary- Yes CO 406C, Rule 3; no restrictions as to well spacing except that no pay shall be opened in a. well closer 6 Well located proper distance from other wells Yes than 500 feet to an external. property line where ownership or landownership changes. - - - - - 7 Sufficient acreage. available in drilling unit... - - Yes Well is more than 500 feet from an external property line. - 8 If. deviated, is wellbore plat. included .. - - - Yes 9 Operator only affected pares - - - - Yes 10 Operator has. appropriate bond in force Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 11 Permit can be issued without conservation order......... Yes 12 Permit can be issued without administrative. approval .. Yes SFD 6/25/2018 13 Can permit be approved before 15 day wait- - - - - - - Yes - - 14 Well located within area and strata authorized by Injection Order # (put 10# in comments). (For NA - - - - 15 All wellswithin1/4. mile area -of review identified (For service well only)...... .. NA ...... 16 Pre -produced injector duration of pre -production less than 3 months. (For service well only) NA - 18 Conductor string. provided - Yes - This is a planned sidetrack from existing surface casing shoe. ................... li Engineering 19 Surface casing protects all known USDWs _ - - - _ - - - - - - - - Yes - - _ Planned sidetrack from existing surface casing shoe 20 CMT vol adequate to circulate on conductor. & surf csg ....................... NA ...... Planned sidetrack from existing surface casing shoe - - ....... - 21 CMT vol adequate to tie-in long string to surf csg--- - - --- - - - - - - - - - - - - - - - - - NA - - _ - - _ This is a sidetrack below the existing surface casing shoe. - - - - - - - 22 CMT will coverall knownproductivehorizons - - - - - - - - - - - - - Yes - The sidetrack willbe completely abandoned with cement plugs, isolating hydrocarbons and the planned sidetrack _ 23 Casing designs adequate for C, T, B & permafrost- - - _ - - - ..... Yes . Existing surface casing, no other pipe planned to be run - - - - - - - - 24 Adequate tankage. or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - Yes 25 If a_ re -drill, has a 10-403 for abandonment been approved - . ......... . . . .. NA - - .. - 1 H-108 was a -planned plug -back 26 Adequate.wellbore separation proposed- - - - - - - - - - - - - - - - - - - - - - - Yes - _ - _ - 27 If diverter requited, does it meet. regulations - - - - - - - - - . - .. NA.. Appr Date 28 Drilling fluid program schematic& equip. list. adequate. ..... - - - - - - Yes MGR 6/29/2018 29 BOPEs, do they meet regulation . . .. . ...... . .. . . ........ . . . . . . Yes - 30 B.OPE.press rating appropriate; test to (put psig in comments)- - - - _ - - - Yes - - - - - - - - - - - - - - 31 Choke manifold complies. w/AP[ RP -53 (May 84) . . . . . . . . . . . . . ........... Yes 32 Work will occur without operation shutdown _ _ _ .. _ - _ - - - _ _ Yes - 33 Is presence. of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - Yes - - _ Standard Kuparuk monitors............... ... 34 Mecbanical.condition of wells within AOR verified (For service well only) - - - _ - - - _ - - - NA _ - _ - - _ Planned producer ..... - - - 35 Permit can be issued w/o hydrogen sulfide measures . . . . . . . . . . . . ..............No - 112S measures required. Well 1H-102 measured 20 ppm H2S on November 20, 2017. Geology 36 Datapresentedon potential overpressure zones _____ _ _ Yes - - - - Expected reservoir pressure is 8.6_ppg EMW; will be drilled with 9.0 - 10.0 ppg-mud. - - - Appr Date 37 Seismic analysis of shallow gas zones.. - - -NA- - - - - - - - - - - - - - - - - SFD 6/25/2018 38 Seabed condition survey.(if off -shore) . . . . . . . . . . . . . . . .. . ........ . . . . . . . NA 39 Contact name/phone for weekly. progress reports [exploratory only] ......... _ . - NA .. Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date b i s -71'�/1 8 4��,,L, 7 I Z I t�,