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217-064
DATA SUBMITTAL COMPLIANCE REPORT 10/24/2017 Permit to Drill 2170640 Well Name/No. TRADING BAY UNIT M-06RD MD 15472 TVD 9911 REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run Well Log Information: Operator HILCORP ALASKA LLC Completion Date 7/12/2017 Completion Status 1-0I1 Mud Log`'0 Samples��� V Log/ C Electr Data Digital Dataset Type Med/Frmt Number Name ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data AOGCC Current Status 1 -OIL API No. 50-733.20585.01-00 UIC No Directional Survey YesV ROP,DGR,EWR-Phase-4,CTN,ALD,FORMATION MUDLOGS,LWD C (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OHI Scale Media No Start Stop CH Received 7050 15550 8/1/2017 8/1/2017 8/1/2017 8/1/2017 8/1/2017 8/1/2017 8/1/2017 8/1/2017 8/1/2017 8/1/2017 8/1/2017 8/1/2017 8/1/2017 8/1/2017 8/1/2017 8/1/2017 8/1/2017 Page I of 7 Comments Electronic Data Set, Filename: M-06 RD.las Electronic File: TBU_M-06RO.dbf ' Electronic File: TBU_M-06RD.mdx- Electronic File: TBU_M-06RD_SCL.DBF Electronic File: TBU_M-06RD_SCL.MDX Electronic File: TBU_M-06RD_tvd.dbf Electronic File: TBU_M-06RD_tvd.mdx . Electronic File: tbu_m-06rd.hdr - Electronic File: tbu_m-06rdr.dbf - Electronic File: tbu_m-06rdr.mdz Electronic File: Canrig M-06RD Daily Report #01 I June 04, 2017.pdf Electronic File: Canrig M-06RD Daily Report #02 June 05, 2017.pdf Electronic File: Canrig M-06RD Daily Report #03 June 06, 2017.pdf Electronic File: Canrig M-06RD Daily Report #04 June 07, 2017.pdf Electronic File: Canrig M-06RD Daily Report #05 June 08, 2017.pdf Electronic File: Canrig M-06RD Daily Report #06 June 09, 2017.pdf Electronic File: Canrig M-06RD Daily Report #07 June 10, 2017.pdf Tuesday, October 24, 2017 DATA SUBMITTAL COMPLIANCE REPORT 10/24/2017 Permit to Drill 2170640 Well Name/No. TRADING BAY UNIT M-06RD Operator HILCORP ALASKA LLC API No. 50-733-20585-01-00 MD 15472 TVD 9911 Completion Date 7/12/2017 Completion Status 1-0I1- Current Status 1 -OIL UIC No ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #08 June 11, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #09 June 12, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #10 June 13, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #11 June 14, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #12 June 15, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #13 June 16, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #14 June 17, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #15 June 18, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #16 June 19, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #17 June 20, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #18 June 21, 2017 emor.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #18 June 21, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #19 June 22, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #20 June 23, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #21 June 24, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #22 June 25, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #23 June 26, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #24 June 27, 2017.pdf AOGCC Page 2 of 7 Tuesday, October 24, 2017 DATA SUBMITTAL COMPLIANCE REPORT 10/24/2017 Permit to Drill 2170640 Well NamelNo. TRADING BAY UNIT M-06RD Operator HILCORP ALASKA LLC API No. 50-733.20585.01.00 MD 15472 TVD 9911 Completion Date 7/12/2017 Completion Status 1-0I1 Current Status 1 -OIL UIC No ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig N- RD Daily Report #25 June 28, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #26 June 29, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Canrig M-06RD Daily Report #27 June 30, 2017.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: M-06RD Final Well Report.docx, ED C 28457 Digital Data (% 8/1/2017 Electronic File: M-06RD Final Well Report.pdf ' ED C 28457 Digital Data 8/1/2017 Electronic File: TBU M-06RD - Sin Formation Log. P MD.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: TBU M-06RD - Sin Formation Log ' P TVD.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: TBU M-06RD - Drilling Dynamics Q Log MD.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: TBU M-06RD - Drilling Dynamics - P Log TVD.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: TBU M-06RD - Formation Log , P MD.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: TBU M-06RD - Formation Log TVD.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: TBU M-06RD - Gas Ratio Log - P MO.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: TBU M-06RD - Gas Ratio Log Q TVD,pdf ED C 28457 Digital Data 8/1/2017 Electronic File: TBU M-06RD - LWD Combo Log . ? MD.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: TBU M-06RD - LWD Combo Log' P TVD.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: M-06 RD - Sin Formation Log MD.tif ED C 28457 Digital Data 8/1/2017 Electronic File: M-06 RD - 5in Formation Log TVD.tif ED C 28457 Digital Data 8/1/2017 Electronic File: M-06 RD - Drilling Dymanics Log " MD.tif ED C 28457 Digital Data 8/1/2017 Electronic File: M-06 RD - Drilling Dymanics Log TVD.tif AOGCC Page 3 of 7 Tuesday, October 24, 2017 DATA SUBMITTAL COMPLIANCE REPORT 1 012412 01 7 Permit to Drill 2170640 Well Name/No. TRADING BAY UNIT M-06RD Operator HILCORP ALASKA LLC API No. 50-733-20585-01-00 MD 15472 TVD 9911 Completion Date 7/12/2017 Completion Status 1 -OIL ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data ED C 28457 Digital Data AOGCC Page 4 of 7 Current Status 1 -OIL UIC No 8/1/2017 Electronic File: M-06 RD - Formation Log MD.tif 8/1/2017 Electronic File: M-06 RD - Formation Log TVD.tif - 8/1/2017 Electronic File: M-06 RD - Gas Ratio Log MD.tif, 8/1/2017 Electronic File: M-06 RD - Gas Ratio Log TVD.tif 8/1/2017 Electronic File: M-06 RD - LWD Combo Log , MD.tif 8/1/2017 Electronic File: M-06 RD - LWD Combo Log TVD.tif 8/1/2017 Electronic File: Show Report #1.pdf ' 8/1/2017 Electronic File: Show Report #2.pdf - 8/1/2017 Electronic File: Show Report #3.pdf 8/1/2017 Electronic File: Show Report #4.pdf 8/1/2017 Electronic File: Show Report #5.pdf- 8/1/2017 Electronic File: Show Report #6.pdf - 8/1/2017 Electronic File: Show Report #7.pdf • 8/1/2017 Electronic File: Show Report #8.pdf 8/1/2017 Electronic File: Show Report #9.pdf - 8/1/2017 Electronic File: Hilcorp Alaska LLC M-06RD , Show Report #1 11660-11760.xls 8/1/2017 Electronic File: Show Report #1 Pixler Plot.pdf 8/1/2017 Electronic File: Hilcorp Alaska LLC M-06RD - Show Report #2 12000-12350.xls 8/1/2017 Electronic File: Show Report #2 Pixler Plot.pdf 8/1/2017 Electronic File: Hilcorp Alaska LLC M-06RD - Show Report #3 12425-12525.x1s 8/1/2017 Electronic File: Show Report #3 Pixler Plot.pdf - 8/1/2017 Electronic File: Hilcorp Alaska LLC M-06RD . Show Report #4 12680-12770.xis 8/1/2017 Electronic File: Show Report #4 Pixler Plot.pdf 8/1/2017 Electronic File: Hilcorp Alaska LLC M-06RD - Show Report #5 12790-12870.x1s 8/1/2017 Electronic File: Show Report #5 Pixler Plot.pdf Tuesday, October 24, 2017 DATA SUBMITTAL COMPLIANCE REPORT 10/24/2017 Permit to Drill 2170640 Well Name/No. TRADING BAY UNIT M-06RD Operator HILCORP ALASKA LLC API No. 50-733-20585.01-00 MD 15472 TVD 9911 Completion Date 7/12/2017 Completion Status 1-0I1 Current Status 1 -OIL UIC No ED C 28457 Digital Data 8/1/2017 Electronic File: Hilcorp Alaska LLC M-06RD Show Report #6 13030-13270.xis ED C 28457 Digital Data 8/1/2017 Electronic File: Show Report #6 Pixler Plot.pdf ' ED C 28457 Digital Data 8/1/2017 Electronic File: Show Report #6 error.pdf ED C 28457 Digital Data 8/1/2017 Electronic File: Hilcorp Alaska LLC M-06RD Show Report #7 13605-13740.x1s ED C 28457 Digital Data 8/1/2017 Electronic File: Show Report #7 Pixler Plot.pdf' ED C 28457 Digital Data 8/1/2017 Electronic File: Hilcorp Alaska LLC M-06RD Show Report #8 13820-14710.x1s ED C 28457 Digital Data 8/1/2017 Electronic File: Show Report #8 Pixler Plot.pdf . ED C 28457 Digital Data 8/1/2017 Electronic File: Hiloorp Alaska LLC M-06RD . Show Report #9 14795-15472.xis ED C 28457 Digital Data 8/1/2017 Electronic File: Show Report #9 Pixler Plot.pdf ' Log C 28457 Log Header Scans 0 0 2170640 TRADING BAY UNIT M-06RD LOG HEADERS Log C 28457 Mud Log 25 Col 7280 15472 8/1/2017 Final MudLog Data 2" MD/TVD Gas Ratio Log 2" MD/TVD Drilling Dynamics Log 2" MD/TVD LWD Combo Log 2" MD/TVD Formation Log 5' MD/TVD Formation Log ED C 28458 Digital Data 7250 15472 8/1/2017 Electronic Data Set, Filename: TBU M- 06RD_DGR_ABG_EWR_CTN_ALD.las ED C 28458 Digital Data 8/1/2017 Electronic File: TBU M-06RD DGR_EWR_ALD_CTN MD.cgm ED C 28458 Digital Data 8/1/2017 Electronic File: TBU M-06RD DGR_EW R_ALD_CTN TVD.cgm ED C 28458 Digital Data 8/1/2017 Electronic File: TBU M-06RD - Definitive Surveys.pdf ED C 28458 Digital Data 8/1/2017 Electronic File: TBU M-06RD - Definitive ' Surveys.txt ED C 28458 Digital Data 8/1/2017 Electronic File: TBU M-06RD DGR _EWR_ALD_CTN MD.emf ED C 28458 Digital Data 8/1/2017 Electronic File: TBU M-06RD DGR EWR ALD CTN TVD.emf AOGCC Page 5 of 7 Tuesday, October 24, 2017 DATA SUBMITTAL COMPLIANCE REPORT 10/24/2017 Permit to Drill 2170640 Well Name/No. TRADING BAY UNIT M-06RD Operator HILCORP ALASKA LLC API No. 50-733-20585-01-00 MD 15472 TVD 9911 Completion Date 7/12/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 28458 Digital Data P 8/1/2017 Electronic File: TBU M-06RD DGR_EW R_ALD_CTN MD.pdf ED C 28458 Digital Data 8/1/2017 Electronic File: TBU M-06RD IV DGR_EWR_ALD_CTN TVD.pdf ED C 28458 Digital Data 8/1/2017 Electronic File: TBU M-06RD DGR _EWR ALD_CTN MD.tif ED C 28458 Digital Data 8/1/2017 Electronic File: TBU M-06RD DGR_EWR_ALD_CTN TVD.tif Log C 28458 Log Header Scans 0 0 2170640 TRADING BAY UNIT M-06RD LOG HEADERS ED C 28459 Digital Data 14947 15386 8/1/2017 Electronic Data Set, Filename: Hilcorp_TBU_M- 06RD_ConCu R01_L007Up_ REPEAT_ CBL- VDL-GR-CCL.Ias ED C 28459 Digital Data 6930 15398 8/1/2017 Electronic Data Set, Filename: Hilcorp_TBU _M- 06RD_ConCu_R01_L008Up_MAIN_CBL-VDL- GR-CCL.las ED C 28459 Digital Data 8/1/2017 Electronic File: Hilcorp_TBU_M- 06RD_ConCu_R01_L007Up_REPEAT_ CBL-. VDL-GR-CCL.dlis ED C 28459 Digital Data 8/1/2017 Electronic File: Hilcorp_TBU_M- 06RD_ConCu_R01_L008Up_MAIN_CBL-VDL- GR-CCLAlis ED C 28459 Digital Data 8/1/2017 Electronic File: Hilcorp_TBU_M-06RD_CBL- VOL_05Ju117_F I NAL. Pdf Well Cores/Samples Information: Name Cuttings INFORMATION RECEIVED Completion Report oY Production Test Informatiol- NA Geologic Markers/Tops 0 Sample Interval Set tart Stop Sent Received Number Comments V/17279 15472 7/24/2017 1613 Directional / Inclination Data YO Mud Logs, Image Files, Digital Data YO NA Core Chips Mechanical Integrity Test Information Y Composite Logs, Image, Data FilesY Core Photographs Y / Daily Operations Summary V Cuttings Samples 0 NA Laboratory Analyses Y, N� AOGCC Page 6 of 7 Tuesday, October 24, 2017 DATA SUBMITTAL COMPLIANCE REPORT 10124/2017 Permit to Drill 2170640 Well Name/No. TRADING BAY UNIT M-06RD Operator HILCORP ALASKA LLC MD 15472 TVD 9911 Completion Date 7/12/2017 Completion Status 1-0I1 Current Status 1-0IL COMPLIANCE HISTORY Completion Date: 7/12/2017 Release Date: 5/2/2017 Description Date Comments Comments: Compliance Reviewed By: API No. 50-733-20585-01-00 UIC No Date: _ 7041 (. _ AOGCC Cage 7 of 7 Tuesday, October 24, 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAc 25.110 GINJ ❑ WINJ ❑ WAG[-] WDSPL ❑ No. of Completions: _1 1b. Well Class: Development Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Abend.: 7/12/2017 14. Permit to Drill Number / Sundry: . 217-064 / 317-219 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: June 5, 2017 15. API Number: 50-733-20585-01-00 4a. Location of Well (Governmental Section): Surface: 1035' FNL, 592' FWL, Sec 33, T9N, R13W, SM, AK Tap of Productive Interval: 1754' FNL, 1849' FWL, Sec 28, T9N, R13W, SM, AK Total Depth: 1107' FSL, 1139' FWL, Sec 28, T9N, R13W, SM, AK 8. Date TO Reached: June 24, 2017 16. Well Name and Number: TBU M-06RD - 9. Ref Elevations: KB: 160' GL: 0 BF: 72' 17. Field / Pool(s): McArthur River Field West Foreland Oil Pool 10. Plug Back Depth MD/TVD: 15,346' MD / 9,894' TVD 18. Property Designation: ADLO18730 41b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 214232 y- 2499431 Zone- 4 TPI: x- 215569 y- 2503993 Zone- 4 Total Depth: x- 214804 y- 2501593 Zone- 4 11. Total Depth MD/ VD: 15,472' MD 19,91 1'TVD 19. DNR Approval Number: N/A 12. SSSV Depth MD/TVD: 460' MD / 460' TVD 20. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes a (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 183' (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 7,279' MD / 4,880' TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary ROP (Rato of Penetration), DGR (Dual Gamma Ray), EWR-Phase 4, CTN(Compensated Thermal Neutron), ALD (Azimuthal Lithodensity, Formation Mudlogs MD1TVD, LWD Combo Log mdrrVD, Gas Ratio MDrrVD, Drilling Dynamics MD/TVD, CBL (Cement Bond Loc) 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 7" 26# L-80 7,003 15,467' 4,719' 9,911' 8-1/2" L - 785 sx / T - 255 sx 24. Open to production or injection? Yes Q No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): **See Attached Schematic for Pert Data" �np� cTip!� RECEIVED f AUG 0 2 2017 - �` -- At% 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 2-7/8" 12,903 550' MD / 550' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No Q Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 7/13/2017 Method of Operation (Flowing, gas lift, etc.): ESP Date of Test: 7/24/2017 Hours Tested: 24 Production for Test Period Oil -Bbl: 64 Gas -MCF: 125 Water -Bbl: 1785 Choke Size: N/A Gas -Oil Ratio: 188 Flow Tubing Press. 86 Casing Press: 50 Calculated 24 -Hour Rate � Oil -Bbl: 664 Gas -MCF: 125 Water -Bbl: 1785 Oil Gravity - API (torr): 31 Form 10-407 Revised 5/2017 ,( 7/l�/17 G CONTI[JU�% O� AGE 2 RBDMS Ir "� - 3 2017 Submit ORIGINIAL o6f `� � ! X7/7 �' fi(% 28. CORE DATA Conventional Corals): Yes ❑ No 0 Sidewall Cores: Yes ❑ No ❑D If Yes, list formations and intervals cored (MD/TVD, Fromfro), 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 ❑Z If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 12,972' WF-1 9,630' information, including reports, per 20 AAC 25.071. G1 11,427' 8,711' G5 11,650' 8,913' Coal 59 11,836' 9,074' HK2 11,882' 9,111' HK7 12,788' 12,928' 9,581' 9,619' RECEIVED 11111".WFT WF2 13,562' 9,718' WF3 15,073' 9,857' AUG U 22017 p(�'' Formation at total depth: JWest Foreland 31. List of Attachments: Schematic, Daily Drilling, Completion Reports, Gag Cmt Report, Definitive Directional Survey, Surveillance. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Paul Mazzolini Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: Cdln of hdcor .COm Contact Phone: 777-8389 Authorized0a1v2 Signature: Date: I INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 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: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only llltcarP Alaaka, LL( RKB to TBG Head -73' 28" 13-3/8" Est. roc @ 920' Stage Collar @ 5,806' TOC @ 6,100' Hauge, 7,003' -' I..:�pt lt;p5 TOW 7,2]9' 9-5/8-- Il+, TOC @ 8,514' 7" -' wF y. / l -t �e' WF -2 WF -3 PBTD: 15,346' TD: 15,472' Max Hole Angle 85.99' @ ±14,013' Steelhead Platform Well: M-06rd PTD: 217-064 SCHEMATIC API: 50-733-20585-01 Last Completed: 07/12/17 CASING DETAIL Size Wt Grade Conn ID Top Btm 28" 73' Conductor (TVD) 27" Surf 470' 13-3/8" 68 L-80 BTC 12.415" Surf. 1,401' 9-5/8" 47 L-80 BTC -M 8.681" Surf 7,279' (TOW) 7" 26 L-80 DWC/C 6.276" 7,003' 15,467' TUBING DETAIL 2-7/8" 6.4 L-80 8 round EUE 1 2.441" Surf 12,766' lr NF1 RV ln!TAll No Depth MD Depth TVD ID OD Item 73' 73' (MD) (TVD) Tubing Hanger 1 460' 460' 2.313" 4.91" SSSV- Haliburton TS824 TRSV NE 2 550' 550' 2.930" 8.500" ESP Dual Packer D&L Oil Tools w/WFT vent valve 3 636' 635' 2.313" 3.230" X -nipple 328' 12,766' 9,576' N/A 4.000" Discharge, Bolt -On 13,628' 12,767' 9,576' N/A 4.000" Pump -333 stage Summit SF2700AR Open 12,835' 9,594' N/A 4.000" Intake 4 12,837' 9,594' N/A 4.60000" Seals- Tandem Summit 400 series BPBSL 14,023' 12,854' 9,599' N/A 4.5" Motor, -5ummit240HP/2975V/58A Open 12,903' 9,612' N/A 4.560" Gauge (Zenith)/ Centralizer/ Anode 103' 6 07/07/17 Open WF -2 14,223' "Note -Straight Hole Pump Tangent Section 12,712' to 12,932' Updated By: JUL 07/14/17 PERFORATION DATA Zone (MD) (MD) (TVD) (TVD) Feet SPF Date Status WF -1 12,972' 13,108' 9,630' 9,662' 136' 6 07/07/17 Open WF -1 13,127' 13,455' 9,666' 9,706' 328' 6 07/07/17 Open WF -2 13,596' 13,628' 9,722' 9,726' 32' 6 07/07/17 Open WF -2 13,650' 13,685' 9,728' 9,732' 35' 6 07/07/17 Open WF -2 13,754' 14,023' 9,738' 9,761' 269' 6 07/07/17 Open WF -2 14,056' 14,159' 9,763' 9,771' 103' 6 07/07/17 Open WF -2 14,223' 14,269' 9,777' 9,781' 46' 1 6 1 07/07/17 1 Open WF2 14,313' 14,362' 9,785' 9,790' 49' 6 07/07/17 Open WF2 14,369' 14,410' 9,790' 9,794' 41' 6 07/07/17 Open WF -2 14,461' 14,649' 9,799' 9,815' 188' 1 6 1 07/07/17 Open WF -2 14,770' 14,800' 9,825' 9,827' 30' 6 07/07/17 Open WF -2 14,812' 15,160' 9,829' 9,868' 348' 6 07/07/17 Open Updated By: JUL 07/14/17 UHilcorp Energy Company Composite Report Well Name: MRF M-06RD Field: McArthur River County/State: Cook Inlet Offshore Steelhead, Alaska (LAT/LONG): ovation (RKB): API #: Spud Date: Job Name: 1711197P M-06RD PreDrill Contractor APE #: 1711197P APE $: . 5/27/2017 Rig & blow down lines in upper well bay of B1 leg. Prep rig for skid. Rig accepted at 06:00 hrs.,Disconnect lines in lower well bay of B1 leg. Remove earthquake clamps, stairs, lay skate ramp over.,Skid upper section of sub base 9', to center weight load. Secure upper section & install earthquake clamps.,lnstall lower grippers, remove earthquake clamps on lower sub, install lower guide plates, & work on handrail install on top of SCR house.,Skid sub base 5' towards B-2 leg., Rig down skate & move to center deck. Un -lug main power to the rig & secure for skid. Hook up umbilical electrical to rig.,Skid towards B-2 leg. Secure rig with earthquake clamps. Rig up wire line on M-06.,RIH with wire line, making a guage run 3.56" to 8600' MD. Rig down wire line. SIMOPS remove kill & choke hoses in the BOP deck. Disconnect Koomey hoses in upper well bay.,RIH with wire line, making a guage run 3.56" to 8600' MD. Rig down wire line. SIMOPS remove kill & choke hoses in the BOP deck. Disconnect Koomey hoses in upper well bay.,Skid rig to make room for crane to transfer service lines ff B-1 to B-2 Ieg.,Move service lines V B-1 to B-2 with crane. Install new kill & choke lines in BOP deck. Install service lines in B-2 leg. 5128/2017 Hook up service lines in NE wellbay. Install new kill & choke hoses w/ new rotating cushion tees.,Rig up Pollard a -line. RIH w/ 3.5" jet cutter & out 4-1/2" tubing at 8598' WLM(cut tubing in the middle of the pup below the packer). Rig down lubricator & move a -line unit. SIMOPS clean grease from skid rails, cont. kill & choke install, & store old kill & choke in crate for spare.,Crane NE hatch covers to NW leg. SIMOPS clean NW trough of mud debris.,Remove east side outer jack cylinder & gripper to west side outer of sub base.,Continue to skid rig towards NE leg. SIMOPS centrifuge OBM to drop weight to 8.9 ppg.,Remove east side inner jack cylinder & gripper to west side inner of sub base. Remove handrails, reroute umbilical cable, & prep/grease skid mils.,Skid rig to NE leg, centering over M-06.,Move north & south diverter lines to access wellhead. SIMOPS install hand mils.,Finish moving diverters & loosen earthquake clamps on upper sub box. Center rotary table over M-06. SIMOPS install hand rails & grating walkways.,lnstall & tighten earthquake clamps. SIMOPS install hand rails & grating walkways., Install service lines from well bay to the rig. SIMOPS flush accumulator lines from unit to NE upper well bay.,Prepping deck to move skate into position. SIMOPS flush accumulator lines from unit to NE upper well bay. Production circulating down tubing taking returns from IA & shipping to Trading Bay.,M-06RD wellhead pressures; 9-5/8X4-112=590 psi, 13-3/8X9-5/8= 0 psi, 28X133/8= 0 psi, Fluid loss to well today: 0 bbls Total: 0 bbls 5/29/2017 Prepping deck to move skate into position, install grating walkways, & flush accumulator lines from unit to NE upper well bay. Production circulating down tubing, 3bpm, 590 psi, taking returns from IA & shipping to Trading Bay.,Move skate via crane into position & rig up. Lug up electrical to the rig. Disconnect electrical umbilical & store. Flush accumulator lines from unit to NE upper well bay, filter accumulator oil, & C/O 4 way valve for choke on accumulator unit. Production circulated 557 bbls of FIW down tubing, 3bpm, 590 psi, taking returns from IA & shipping to Trading Bay.,String up cables on pipe skate. Change out saver sub on the top drive. Fill glycol lines on the rig. Cut out & remove mud trough box.,Rig up & route hose from the rig to the small vac unit. Rig up to re -position skate., Reposition skate & rig back up.,lnstall BPV, nipple down the tree & flow line, remove same from wellbay. Clean & inspect hanger void. Function lock down screws & install blanking plug. SIMOPS grease choke manifold.,Nipple up spacer spool, lower & upper high pressure riser onto wellhead.,Finish nipple up of high pressure risers. Set BOP stack on risers, nipple up same. Install kill & choke hoses. Install Koomey lines in NE upper well bay & route up to BOPE. "M-06RD wellhead pressures; 9-5/8X4-1/2=0 psi, 13-3/8X9-5/8= 0 psi, 28X13-3/8= 0 psi, Fluid loss to well today: 0 bbls Total: 0 bbls" 5/30/2017 Cont. N/u BOPE, install flow nipple flanges & flow nipple, finish install of accumulator Iines.,Pressure up accumulator system, function test BOPE from all stations, m/u subs for 4 1/2" lj., Pull flow nipple & modify, open & inspect upper ram blocks, re -install flow nipple., Install 4 1/2 li du test eq. fill stack & manifolds, tighten leak on air boot flange on annular, shell test 250 & 3500psi, repair leak on riser hub connection, repair test pump, re -test good.,Test BOPE as per Hilcorp & AOGCC standards, test w/ 4 1/2" & 5" tj's, 25013500psi, test Witnessed by AOGCC inspector Matt Herrera, had PIP on CMV #5, serviced & retested good, F/P on lower IBOP, changed out valve tested good, tested all gas alarms good.,Change out lower IBOP & gripper dies.,M-06RD wellhead pressures; 9-5/8X4-1/2=0 psi, 13-3/8X9-5/8= 0 psi, 28X13-318= 0 psi, Fluid loss to well today: 0 bbls Total: 0 bbis 5/3112 01 7 C/o regulator on test pump, r/u & test HP line f/pump room to rig floor through TDS t/4600 psi f/ 15min good.,Ud test tools.,Troubleshoot & repair indicator lights on BOPE remote panels, housekeeping cellar, re -plumb, air to super choke, change out PRV on accumulator.,R/u pull blanking sub & BPV, m/u landing jt.,Pressure up well bore U500psi hold 1/20 min.,Back out LD pins, pull hanger free w/string up wt 145k, CBU through gasbuster @ 6BPM, 230 psi, shut down monitor well, static.,Pull & Ud hanger, du handling eq. 111/d 4 1/2" completion., POOH I/d 4 112" TC -II, f/8598' 06364' up wt 120k, do wt 115k, Vd SSSV, 1 - GLM, 1 chem inj sub, 69 #a 4 1/2" tubing, SS ctrl line , recover 73 SS bands.,Cont. POOH I/d 4 1/2 completion V6364', 05728', up wt 115k, do wt 110k.,Cont. POOH I/d 4 1/2" tubing, lid 187jts, 3 GLM, SSSV, chem inj sub.,M-06RD wellhead pressures; 9-5/8X4-1/2=0 psi, 13-3/8X9-5/8= 0 psi, 28X13-3/8= 0 psi, Fluid loss to well today: 0 bbls Total: 0 bbls 6/1/2017 Cont. I/d 4 1/2" completion, I/d total of 263 jts, 1-SCSSV, 4- GLM, chem inj. sub, sliding sleeve, 14 pups, 1 cut jt 3.84'., Clean & clear floor, c/o handling eq. p/u test eq. f/4".,Test BOPE, w/ 4" tj, 250 low, 3500 high, test upper & lower rams, annular, 4" safety valves, & rebuilt lower Kelly valve (spare) good.,R/d test jt, install wear ring, clear test tools from floor.,M/U BHA #1, - 6" mill tooth bit, 7" csg scraper, 2-4 3/4" boot baskets, bit sub w/Float, xo, 40 jts 4" dp, xo, double pin sub, 9 5/8" csg scraper, 2 -7" boot baskets, bit sub, 8.5" watermelon mill, flex jt, 6-jts 5" HWDP, jar & bumper sub, 11-jts 5" HWDP=1856.20'.,TIH w/ 5" dp from derrick, t/2804'. Training, cont. tih practice making connections w/new Driller 03751', fill pipe. Up wt 12, do wt 110.,Cont. tih U tag top of cut @ 8594' DP measurement, (clean through TOL @ 7346' ).,CBU @ 14 BPM, 2000 PSI, while reciprocating, up wt 225k, do wt 150k.,POOH t/ 7162'.,Semice rig, Cut & slip Drill Iine.,M-06RD wellhead pressures; 9-5/8 =25 psi, 13-3/8X9-5/8= 0 psi, 28X13-3/8= 0 psi, Fluid loss to well today: 0 bbis Total: 0 bbls 6/2/2017 Service rig, cut & slip drill line, cut 110'.,Cont. POOH standing back 5" dp t/1856'.,Ud 9 518 scraper assy. recover 10 pieces SS banding total length 4 bands-Cont. POOH stand back 6 stands 4" DP, UD remaining 22 jts 4" dp, & 7" scraper assy. recover one SS band.,C/o handling eq. prep & p/u cmt stinger assy, - Mule shoe cmt stinger, 27 jts 3 1/2" tubing, dual xo, 18 jts 4" dp, xo= 1434.79.,Cont. TIH w/5" dp t/ 6172', up wt 160k, do wt 13k.,Cont. tih Utop of tubing cut @ 8594', up wt 205k, do wt 150k, (passed through liner top @ 7346' clean ).,PJSM, r/u Upump cmt, flushed cmt line from unit to rig floor, break circulation with cmt unit, pressure test lines 900psi 13000 psi, good.,Mixed & pumped 20 bbis 15.8 ppg class "G" cmL balanced plug, spotted plug with rig pumps, EST TOC 8082'. POOH slow (/7625'. 6/3/2017 Circulate surface to surface, drop wiper ball, circulate @ 12 bpm 770psi, clean returns.,POOH t/ 1434' standing back 5" dp, (pulled on double for pipe maint.).,Cont. POOH I/d 18 jts 4" DP, & 27jts 3 1/2 tubing with diffuser, I/d handling eq.,R/u PT casing/cmt U2700psi, had leakoff, troubleshoot & repaired surface leak, re-pressure t/2700 hold f/ 30 min good, blow down Iines.,Clean & clear floor of un-needed tools & subs.,R/U a-line, m/u GR/CCL tools, rih Utag TOC @ 7881' wlm, POOH logging collars for, M/U 8.37" GR/ junk basket, rih (/7320', sat down @ 2810', 5804', 6010', 7030' wk through rih (/7320', POOH recovered 17 pieces of SS bands (equal TO 1 3/4 FULL BANDS +-).,Re-run junk basket/GR 07320' POOH recover 9 smaller pieces & 2 large pieces of SS bands (equal to+- 1 112-2 Bands) wk through areas @ 4650', 5804, 7230'.,Re-run junk basket/GR (/7320', recover 2 large, 5 medium & several small pieces SS banding ( equal to +-1.5 bands) wk through 5804'.,Re-run junk basket/GR 1./7320' work through 5804, POOH (rig crew worked on rig punch list projects & housekeeping during W/L operations).,M-06RD wellhead pressures; 9-5/8 =25 psi, 13-3/5X9-5/8= 0 psi, 28X13-3/8= 0 psi, Fluid loss to well today: 0 bbis Total: 0 bbis 6/4/2017 POOH recovered 2 medium pieces & 30 small pieces of SS banding.,Re-head a-line, m/u 8.37"GR/junk basket rih 05804', wk to fall through unable, POOH recover 6 small pieces SS bands.,M/U & run 9 5/8" CIBP, set w/ top of plug @7297' WLM (casing collar @ 7302') POOH ,r/d e-Iine.,P/U BHA.,Drill abandon platform drill, good response, muster and discussion after.,P1U BHA: 9 518 BOTTOM TRIP ANCHOR, 9 5/8 GEN II WHIPSTOCK SLIDE w/479 shear bolt, 8112 WINDOW MILL, 83/8 LOWER WATERMELON MILL, FLEX JOINT, UPPER WATERMELON MILL, 1 JT 5" HWDP, FLOAT SUB, DM COLLAR, TM COLLAR, 3ea FLEX COLLARS, 15 JTS 5" HWDP=647.83', shallow test MWD tools good.,TIH @ 70FPM, f/ 647' t/5574', up wt 175k, do wt 140k.,Cont. tih U 7186up wt 207k, do 157 rot wt 175k.,Orientate whip stock, circ. 10 bpm, 850 psi, wk string U orientate t/61 L, cont. in hole tag CIBP @ 7300' pipe measurement, set @ 61 L, shear anchor pins @ 12k do , p/u 10k over verify anchor set, set do shear bolt w/35k, p/u free 203k, do wt 157k, rot 80 rpm, tq 11 k, rot wt 175k.,Displace hole U OBM, dump upper pits t/pit 6 & rinse while pump 25 bbl spacer ahead of 8.9ppg OBM, taking returns t/ pit 6 & transfer Uproduction, catch spacer & interface in trip tank.,Cont. drain FIW t/ production, suck out interface from tt & clean pits.,M-06RD wellhead pressures; 9- 5/8 =30 psi, 13-3/8X9-5/8= 0 psi, 28X13-3/8= 0 psi, Fluid loss to well today: 0 bbis Total: 0 bbls 6/5/2017 Cont. Drain FIW t/production, clean pits, fill pits w/ OBM.,Mill window 1/7279't/7296' Up wt 197k, do wt, 157k, rot 80 rpm, tq 9k off, 10-12 on, circ. 10 bpm 1360 psi, pump high vis sweep no increase in metal returns.,Cont. drill rat hole 07340', circ 15bpm, 2500 psi, 100 rpm, tq 10-15.,Drift window, pumps on rotating, pumps off no rotation, good, circulate Hi vis sweep w/nut-plug, 150% increase in solids on returns. circulate clean. ( capture total of 206# metal ).,R/U & preform FIT, MW 8.9ppg, TVD 4879', pressure up t/ 960 psi = MW E 12.68 PPG, pumped 5.2 bbls, bleed back 2.9, blow down Iines.,Circulate & spot dry job, POOH (/5385', up wt 170k, do wt 140k.,Cont. POOH U BHA 647'.,Wk BHA, stand back HWDP & flex collars, I/d window mill assembly, upper watermelon mill in gauge. Clean & clear floor.,Pull wear bushing, flush stack.,M-06RD wellhead pressures; 9-5/8 =30 psi, 13-318X9-518= 0 psi, 28X13-3/8= 0 psi, Fluid loss to well today: 0 bbis Total: 0 bbis nHilcorp Energy Company Composite Report Well Name: MRF M-06RD Field: McArthur River County/State: Cook Inlet Offshore Steelhead, Alaska (LAT/LONG): ovation (RKB): API #: Spud Date: 6/7/2017 Job Name: 1711197D M-06RD Drilling Contractor Steelhead 51 AFE #: 1711197D AFE $: AC0ty'aiaie _ Ops Summary;'v,.,ss` , 6/612017 Flush Test Plug Seat & Stack With Wash Tool.;Drain Stack - Pull Wear Bushing - Set Test Plug With 5" Test Joint- Rig Up Surface Lines For Pressure Testing BOP.,Pressure Testing BOP Equipment to Hilcorp & AOGCC Sp - 250psi Low & 3500psi H' h - FP on Lower [BOP Due to Leaking Valve On Test Manifold - F1P On Swaco Super Choke With Trash In Choke.;Witness Of BOP Test Waived By AOGCC Mr. Jim Regg.;Rig Down Test Equipment - Pull Test Plug -Set Wear Bushing, I/d test eq.;P1U BHA#4. Make up 8.5" PDC bit, Geo -Pilot assy wlstab, DM collar, in line stab, DGR, EWR, PWD, HCIM, ALD w/stab & CTN, TM collar, float sub, flex collar.;M/u MWD upload tools and shallow test same, good, PJSM, & load source, cont. p/u 2 -flex collars, 6- HWDP, hyd jars w/ bumper sub, 11- HWDP, BHA total=747.26.;RIH With Sperry GEO - Pilot Assembly BHA#4 t/7190', up wt 203k, do wt 154k.;Establish Circulation at 7210 (59' Above Top Of _9M Window) - Cir to Shear OBM, 200GPM 560PSI, stage rate up as able U 450 gpm, 2047psi get SPR.;Cont in hole, trip through window no issues V 7316', up wt dnwt1R4 6/7/2017 Cont Working Down To 7,340 - Drilling With Rotary Steamble Assembly #4 From 7,340 to 7,419 with Slow Rotary and 10K Bit Weight While Working Logging Tools Through Window.;Had Some Trouble From 7,355 to 7,360 with High Torque - Worked Threw Same - at 7,419 PU 210 SO 160 R 175 485gpm (11.513bl) 2340psi 20kwob 110rpm 13k tor.;Cont RS Drilling F 7419 T 7571 (152' S0'/hr Pipe In Ground) pu 223 SO 160 R 175 504gpm (12Bbl) 2350psi 10 to 20k WOB 150rpm 14 to 15k tor.;Cont RS Drilling f/ 7571' V 7778' (207' 697hr PIG PU 223 SO 160 R 175 504gpm (12Bb1) 2350psi 10 to 20 WOB 150rpm 14 to 15k tor.;Cont. Drilling f/ 7571' 117978' (198' 66'/hr Pipe In Ground) pu 223 SO 160 R 175 504gpm (12Bbl) 2350psi 10 to 20k WOB 150rpm 14 to 15k tq.;Cont. Drilling V 7978' V8203 (225' 757hr Pipe In Ground) pu 223 SO 160 R 175 490gpm, 2150psi 10 to 20k WOB 150rpm 14 to 15k tq.;Cont. Drilling f/8203' 118485' (282' 94' hr Pipe In Ground) pu 223 SO 160 R 175 490gpm, 2150psi 10 to 20k WOB 150rpm 16 to 18k tq.;Cont. Drilling f/8485' V 8703' (218' 72' hr Pipe In Ground) pu 268 SO 175 R 203 490gpm, 2340psi 10 to 20k WOB 150rpm 18 to 20k tq.;M-06RD wellhead pressures; 9-5/8 =35 psi, 13-3/8X9-5/8= 0 psi, 28X13-318= 0 psi, Fluid loss to well today: 0 bilis Total: 0 bbls Distance to plan 6.57' 4AT low 4.81' right 6/8/2017 Drilling With Rotary Steerable 8,70318986 (2837 94' /hr PIG) PU 275 SO 175 R 205 490gpm (11.7) 12 to 20k WOB 150rpm 18k for - Using Coal Tops List To Flag Coals.;Drllling With RS 8986 / 9,180 (194' 64'lhr PIG) PU 285 SO 180 R 210 492gpm (11.7) 2,320psi 20k WOB 150rpm 18k for- Using Coal Top List To Flag Coals.;Drilling WithRS 9180/9461 (281' 93'/hr PIG) PU 300 SO 185 R 215 495gpm (11.7) 2300psi 20k WOB 150rpm 18/21 K for - Using Coal Top List to Flag Coals.;Drilling With RS 9461 / 9672 (211' 707hr PIG) PU 305 SO 185 R 215 495gpm (11.7) 2300psi 20/22 WOB 150rpm 20/21 k tor.;Had Trouble With Over Filling a Cuttings Box & Surge Tank Causing Fluid To Reach The Filter on The Blower- Slow Drilled with 2 to 4k WOB 9658 / 9680 Until Shaker Cuttings Tank was Full - Then Work.;Pipe While Sorting Out Vacuum System.;Drilling f/9672't/ 9842' (170' 85'hr PIG) PU 325 SO 188 R 225 495gpm (11.7) 2400psi 20/22 WOB 150rpm 19/21 k tq Using Coal Top List to Flag Coals.;Drilled Form 9503 to 9,650 Without Coal Top List While G&G Working On Same.;Saver sub broke out while making connection, changed it out.;Drilling (/9842' 119934' (92" hr PIG) PU 305 SO 195 R 225 485gpm (11.7) 2300psi 20/22 WOB 150rpm 17/18k tq (Note: adding NXS lube Vsystem).;Drilling f/9934' U 10092' (158' S2'hr PIG) PU 302 SO 200 R 230 493gpm (11.7) 2290psi 20/22 WOB 150rpm 19120k tq Using Coal Top List to Flag Coals.;Drilling f/10092'ti 10302'(219 79hr PIG) PU 325 SO 188 R 225 495gpm (11.7) 2400psi 20/22 WOB 150rpm 19/21 k tq Using Coal Top List to Flag Coals.;M-06RD wellhead pressures; 9-5/8 =35 psi, 13-318X9-5/8= 0 psi, 28X13-3/8= 0 psi, Fluid loss to well today: 0 bbls Total: 0 bbis Distance to plan 8.29' 2.5 high 7.91' right 6/9/2017 Drilling With Rotatry Steerable 10302 110453 (151' S0'/hr PIG) PU 322 SO 205 R 236 495gpm (11.7) 2350psi 15k WOB 150rpm 19/20k tor.;Drilling With RS 10453 /10,502 (49' 167hr PIG) PU 322 SO 205 R 263 495gpm (11.7) 2350psi 25K WOB 150rpm 19122 tor.;Had a good Deal of trouble at 10,495 Where it Acted Like we Were Hanging Up On The Non - Rotating Sleeve Of the RS Tool - Lost 6k for And Were- Pumped a Monty Sweep Around and Worked Pipe Aggressively;Once We Finally Got It Going It Drilled at 100+'/hr.;Drilling With RS 10502 / 10742 (240' 80'/hr PIG) PU 320 SO 208 R 242 473gpm (11.2) 2200psi 20 to 22k WOB 150rpm 18 to 20k for (One Pumpe Down For Repairs to Liner Gasket) - Some Trbl With Hanging Up.;Cont Drilling With Rotary Steerable 10742 / 10,883 (141' 477hr PIG) PU 325 SO 208 R 242 473gpm (11.2) 2200psi 20/22k WOB 150rpm 18/20k tor.;Cont Drilling With Rotary Steerable 1/10,883 11110191 (136' 457hr PIG) PU 330 SO 210 R 250 483gpm (11.2) 2350psi 15/25k WOB 150rpm 21/23k tor.;Cont Drilling With Rotary Steerable f/11019' 1/11072' (53' 26/hr PIG) PU 340 SO 212 R 250 483gpm (11.2) 2350psi 15/25k WOB 150rpm 21/23k tor, ROP s[owed.;Pump 25 bbl high vis sweep@ 12bpm, 2480 psi, circulate x3 clean.;POOH, up wt 325k, do wt 220k, 1711072', V8233, worked tight spots, 10352', 9687', pulled back through good,;M-06RD wellhead pressures; 9 518 =35 psi, 13-3/8X9-518= 0 psi, 28X13-318= 0 psi, Fluid loss to well today: 0 bbls Total: 0 bbls Distance to plan 9.58' 2.73' low 9.19' right 6/10/2017 Cont POH -823317177- Pulled Well With 10 to 25K Over Pull In spots Matching Coals That We Had Drilled -Did Have a 3Ok Over Pull At the Coal Just Out Of The Window 7,550 & 7,480.;Had Big Tools Across Window At This Time But Overpull Looked Like It Was Caused By Coal - Once Above Coals It Pulled Clean All The Way Through The Window.;Slip And Cut Drilling Line - Service Rig.;Spot dry job, POOH f/7177' 83495'.;Install W WT non rotating protectors, 2 each on every jt 9' below box end, 5' above pin tool joints. Stand back total of 29 stands (2747' w/ protectors).;L/D BHA; stand back HWDP, flex collars, pull source, MWD download tools, clo DM collar, break off bit, BT on shoulder, I/d geo pilot (low oil) (Function tested BOPE from Drillers remote good).;P/U BHA- p/u BHA #5- 8.5" PDC bit, Geo-Pilot assy w/stab, DM collar, in line stab, DGR, EWR, PWD, HCIM, ALD w/stab & CTN, TM collar, float sub, flex collar.;M/u MWD upload tools and shallow test same, good, PJSM, & load source, cont. p/u 2-flex collars, 6- HWDP, p/u hyd jars w/ bumper sub, 11- HWDP, BHA total=747.72'.;RIH p/u 5" DP U 1505', up/dn wt 105k.;M-06RD wellhead pressures; 9-5/8 =35 psi, 13-3/8X9-5/8= 0 psi, 28X13-3/8= 0 psi, Fluid loss to well today: 0 bbis Total: 0 bible Distance to plan 9.58' 2.73' low 9.19' right 6/112017 Cont Picking Up 5" D.P. 150512,547.;Cont Trip In From Derrick 2547 /2644 - Test MWD - Cont RIH From Derrick T 7182.;Cir Btms Up F 7182 to Shear Mud.;RIH Out Of Derrick - Clean Through Window And Down To 8740 Where it took Weight- Started Picking Up Superslider Stands at a Bit Depth Of 8,325.;Kelly Up And Establish Cir- Spot Ream 8740 to 8760.;Cont RIH Clean To 9,375 Where it Took Weight -Attempt to Work Through Unable.;Kelly Up And Establish Circulation -Spot Ream 9,375 to 9,385.;Cont RIH T 10982'- Kelly Up And Wash Last 95' To Btm - Had a Good deal Of Trouble Getting the Last 20' Cleaned Out-Did Not Seem Undergage -Maybe Piled Up Wfth Coal.;Cont Drilling With Rotary Steerable f/11072' t/ 11170' (98' 49'/hr PIG) PU 375 SO 200 R 235 527gpm (11.2) 2810psi 20k WOB 150rpm 16-17k tq.;Cont Drilling With Rotary Steerable 1/1117U U 11305' (135' 45' hr PIG) PU 375 SO 200 R 240 525gpm (11.2) 2800psi 20k WOB 150rpm 16.17k tq.;Cont Drilling With Rotary Steerable f/11170' t/ 11452' (282' 94' hr PIG) PU 375 SO 200 R 235 527gpm (11.2) 281 Opsi 20k WOB 150rpm 16-17k tq. Stick slip in high range.;Cont Drilling With Rotary Steerable 811452' U 11590' (138' 46' hr PIG) PU 375 SO 20O R 235 527gpm (11.2) 2810psi 20k WOB 150rpm 18-19tq. Stick slip in high range. Signed out of spec. sheet for MWD.;W06RD wellhead pressure; 9-5/8=38 psi, 13-3/8X9-5/8= 30 psi, 28X13-3/8= 0 psi, Fluid loss today: 0 bbis Total: 0 bbis Distance to plan 7.35'2.73' low 9.19' right;Daily metal recovered; 20# 6/12/2017 Cont Drilling With Rotary Steemble 11590 / 11700 (110' 36'/hr PIG) PU 370 SO 190 R 245 520gpm 2780psi WOB 15 / 20k 150rpm 16 to 20k tor.;Drilling With RS 11,700 / 11,780 (80' 26'/hr PIG) PU 370 SO 195 R 240 520gpm 2760psi WOB 15 / 25 150rpm 16 to 20k for -Some Trouble With Cylic Tor MWD Tools In Med Range.;Drilling With RS 11,780111,902 (122' 40'/hr PIG) PU 365 SO 195 R 240 531gpm 2800psi WOB 20 / 25k 19 to 20k for - Some Trouble With Cylic Tor MWD Tools In Med Range.;Drilling With RS 11,902 / 12021 (119' 397hr PIG) PU 375 SO 195 R 245 522gpm 2750psi 2010 25k WOB 18 to 20k for - Some Trouble With Cylic Tor MWD Tools In Med Range.;Drilling With RS f/12021' 812172' (151' S0'hr PIG) PU 375 SO 195 R 245 525gpm 2810psi 20 to 25k WOB 19 to 2Ok for -Some Trouble With Cylic Tor MWD Tools In Med Range.;Drilling With RS 812172' 812290' (118' 39'/hr PIG) PU 375 SO 195 R 245 525gpm 2810psi 20 to 25k WOB 19 to 20k for -Some Trouble With Cylic Tor MWD Tools In Med Range.;Drilling With RS 1/12290' 812353' (63' 21' hr PIG) PU 375 $O 195 R 243 544gpm 3000psi 20 to 25k WOB 19 to 2Ok for -Some Trouble With Cylic Tor MWD Tools In Med Range.;Drilling With RS f/12353' U7 2411' (58' 19' hr PIG) PU 375 SO 195 R 243 544gpm 3000psi 20 to 25k WOB 19 to 20k for - Some Trouble With Cylic Tor MWD Tools In Med Range.;M-O6RD wellhead pressure; 9-5/8 =38 psi, 13-318X9-5/8= 0 psi, 28X13-3/8= 0 psi, Fluid loss today: 0 little Total: 0 bbls Distance to plan 11.76' 11.72' high .94rightDaily metal recovered; 41# total 441# 6/13/2017 Cont Drilling 12411 / 12412 PU 375 SO 195 R 243 544gpm 3000psi 18 to 24k WOB 150rpm 17 to 18k for -Could Not Get Any Decent Drill Off.;Cir Working Pipe 12412 to 11990 150rpm for 30min -Rack Back One Stand To Allow a Full 90' Strk While Circulating - Cir Around 30bb1 High Vis Nut Plug Sweep Cir 3XBtms Up Total.;Pulled Out Of Hole On A DBL Break -Worked through Tight Spots 11810 (Close To Top Of Hemlock) -11660 to 11600 (Coal 59) -11400 to 11364 (Coal 39) - Worked Through with A Travel Weight of 340.;And a Max Over Pull Of SOK (390K) - Pulled Through Slowly And Broke Back Down When We had 50K Over Pull - Spots Were Not Bad With None Thaking More Than 2 times Working Prior To Getting By.;Cont POH Would See The Coals With Maybe 10 to 20k Overpull - Would Pass Right Through - Pulled To 7,480 where We had a 20k Overpull - Worked Agianst it Twice - Little Sticky.;Kelly Up And Establish Rotation & Circulation -Rotation at BOrpm Worked Circulation Up to 470gpm At 2,500psi-100rpm Worked Up To 7460- Had Some Light Torque & Packing Off (Coal) - Cont Pulling.;Through Window At 7296 - Window Was Clean - Pull To 7265.;Flow Check - Dry Pipe - Cont POH to 747 (BHA) - Flow Check.;Confinue out of hole racking back HWDP, NMFC, & BHA. Bumper sub below the Jars would not close. Noticed wear on the leading edge of the Inline Stabilizer.;Bft was rung out with a grade of 84-RO-C-X-I-WT-PR. Plan to change out bit & Jars for next run.;Change out Caring encoder on the drawworks. SIMOPS C/O derrick lights, clear area to move test pump to rig floor & drift 7" 26# Iiner.;Change out 8-1/2" bit & jars in BHA #6. Shallow hole test MWD. Load nuke sources & TIH w/ NMFC TO 381' MD.;M-06RD wellhead pressure 9-5/8 =40 psi, 13-3/8X9-5/8=50 psi, 28X13-3/8= 0 psi Fluid loss today: 0 bible Total: 0 bible Distance to plan 11.OT 11.04' high .91 right";Daily metal recovered; 15# total 4621P 6/14/2017 TIH w/ 5" DP f/ 381'-7190' MD, PU 200K, SO 157K, fill pipe every 20 stands.;Circulate bottoms up staging up the pumps to 500 gpm, 2300 psi, PU 200K, SO 157K.;TIH wl 5" DP f/ 7190'-11990' MD, PU 297K, SO 195K, fill pipe every 20 stands.;Wash & ream f/ 11990'-12424' MD, 525 gpm, 2900 psi, 150 rpm, Tq 18- 20K, PU 325K, SO 200K. ROT 240K, pumped Hi-Vis nut plug sweep on bottom.;Drilling ahead w/ 6-12" Rotary Steerable f/ 12424'-12491' MO, 525 gpm, 2950 psi on, 2950 psi off, FO 66%,100-150 rpm, Tq on 17-23K, off 15-17K, PU 395K, SO 195K, ROT 240K, ECD 9.9, MG 30 units.;Drilling ahead w/ 8-12" Rotary Steerable f/ 12491'-12642' MD, 525 gpm, 2950 psi on, 2930 psi off, FO 66%,100-150 rpm, Tq on 20-23K, off 16-18K. PU 400K, SO 195K, ROT 240K, ECD 9.9, MG 30 unb.;Drilling ahead w/ 8-1/2" Rotary Steerable f/ 12642'-12745' MD, 525 gpm, 2940 psi on, 2920 psi off, FO 66-68%, 100 rpm, Tq on 18-22K, off 16- 18K, PU 400K, SO 100K, ROT 240K, ECD 9.8, MG 47 units.;Slip stick was in the high range. Tried different parameters with no success.;Drilling ahead w/ 8-12" Rotary Steerable f/ 12745'-12847 MD, 525 gpm, 2940 psi on, 2920 psi off, FO 66%, 100 rpm, Tq on 20-22K, off 16-18K, PU 395K, 5O 195K, ROT 240K, ECD 9.9, MG 106 units.;Slip stick was in the high range. Tried different parameters with no success. Signed a out of spec. sheet for MWD.;M-06RD wellhead pressure 9-5/8 =40 psi, 13-3/8X9-5/8=45 psi, 28X13-3/8= 0 psi Fluid loss today: 0 bbis Total: 0 bible Distance to plan 1.42' 0.06 Low 1.42' Left;Daily metal recovered; 8# total 470# 6/15/2017 Drill w/8.5" Rotary Steerable f! 12847'-12863' MD, PU395K, SO 190K, ROT 240K, 510 gpm, FO 66%, WOB 3-5K, on 2740 psi, off 2720 psi, Tq on 18-22K, off 16-18K, 140 rpm, ECD 9.8, Max Gas 88.;Slip stick was in the high range. Tried different parameters with no success.;Drill w/8.5" Rotary Steerable f/ 12863'- 12878' MD, PU388K, SO 198K, ROT 243K, 510 gpm, FO 66%, WOB 5-10K, on 2760 psi, off 2720 psi, Tq on 18-22K, off 16-18K, 140 rpm, ECD 9.8, Max Gas 35.;Slip stick was in the high range. Tried different parameters with no success.;Circulate 2 bottoms up at 510 gpm, 2740 psi, 120 rpm, Tq 20K, reciprocating full stand ;TOH f/ 12878'-10886' MD, PU 400K, SO 210K. Wiped the following depths: 12716, 12686'-12591'-2X, 12497'-12402'-2X, 12307'-12212'-2X, 12118'- 12023'-2X, 11928'-11833'-2X, 11738'11643'-2X.;Depths wiped continued -11549'-11454'-2X, Coal 31 11269'-11263'-2X, Coal 3011149'-11138'-2X, Coal 29 10972'- 1 0943'-2X.;TIH f/ 10886-12781' MD, PU 340K, SO 205K @ 10886' ;Wash & ream f/ 12781'-12878' MD, 525 gpm, 2850 psi, 130 rpm, Tq 15-18K.;Drill w/ 8.5" Rotary Steerable f/ 12878'-12970' MD, PU390K, SO 195K, ROT 250K, 525 gpm, FO 67%, WOB 18-20K, on 2950 psi, off 2930 psi, Tq on 19-22K, off 16- 20K, 130 rpm, ECD 9.9, Max Gas 30.;SIip stick was in the high range.;Drill w/ 8.5" Rotary Steerable f/ 12970'-13035' MD, PU400K, SO 195K, ROT 250K, 525 gpm, FO 67%, WOB 20-25K, on 2900 psi, off 2900 psi, Tq on 17-22K, off 15-18K, 120 rpm, ECD 9.9, Max Gas 30.;Slip stick was in the high range.;Drill w/ 8.5" Rotary Steerable f/ 13036-13105' MD, PU380K, SO 195K, ROT 250K, 525 gpm, FO 67%, WOB 20-25K, on 2930 psi, off 2900 psi, Tq on 17-22K, off 15-18K, 120 rpm, ECD 9.9, Max Gas 39.;Slip stick was in the high range.;Drill w/ 8.5' Rotary Steerable f/ 13105'-13199' MD, PU380K, SO 195K, ROT 250K, 525 gpm, FO 67%, WOB 15-20K, on 2930 psi, off 2900 psi, Tq on 17-22K, off 15-18K, 120 rpm, ECD 9.8, Max Gas 20.;Slip stick was in the high range.;M-06RD wellhead pressure 9-5/8 =40 psi, 13-3/8X9-5/8=50 psi, 28X13-3/8= 0 psi Fluid loss today: 0 bbls Total: 0 bbls Distance to plan 21.65' 3.55'Low 21.36' Left;Daily metal recovered; 4# total 474# 6/16/2017 Drill w/ 8.5" Rotary Steerable f/ 13199'-13240'(41'13'/hr PIG) , PU385K, SO 193K, ROT 250K, 523 gpm,, WOB 20-25K, on 2930 psi, off 2900 psi, Tq on 17- 22K, off 15-18K, 120 rpm, ECD 9.9, Max Gas 20.;Slip stick was in the high range.;Short trip f/ 13240'-12781' MD, PU 395K, SO 205K.;Drill w/ 8.5" Rotary Steerable f/ 13240'-13272' (32' 10.6'/hr PIG), PU375K, SO 195K. ROT 245K, 525 gpm„ WOB 19-20K, on 2930 psi, off 2880 psi, Tq on 16-19K, off 17-18K, 120 rpm, ECD 9.8, Max Gas 3.;Circulate & condition reciprocating 13255'-13160'. PU 394K, SO 195K, ROT 245K, 550 gpm, 3100 psi, 150 rpm,Tq 22K.;TOH f/ 13250'-12307' MD, PU 390K, SO 210K.;TOH f/ 12307'-9559' MD, PU 380K, SO 210K, racking back stands on DS w/ Super Sliders;TOH f/ 9559'-8422' MD, PU 356K, 5O 200K;Pump 20 bbls dryjob 1 ippg, 224 gpm, 540 psi, & blow down TD;TOH f/ 8422'-5105' MD, PU 168K, SO 145K, calculated fill 69, actual 79 bbls, 10 bbls accounted to floor drains.;Short trip to TOW f/ 5105'- 7284' MD, remove super sliders from 5" DP because of wear on DP.;Short trip to TOW fl 5105'- 5674' MD, remove super sliders from 5" DP because of wear on DP;TOH f/ 5105'- 5010' MD installing super sliders on pipe & racking back for next TIH.;M-06RD wellhead pressure 9-5/8 =40 psi, 13-3/8X95/8=55 psi, 28X13-3/8= 0 psi Fluid loss today: 0 bbls Total: 0 bbls Distance to plan 20.54' 4.89' Low 19.95' Left;Daily metal recovered; 2# total 476# 6/17/2017 TOH f/ 5010'- 2372' MD, installing non -rotating protectors on pipe & racking back for next TIH. Install 6 NRP per stand.;Service Iron Roughneck, drawworks, inspect elevators / slips / dog collar.;TOH f/ 2372'- 1892' MD, installing non -rotating protectors on pipe & racking back for next TIH. Install 6 NRP per stand.;TOH V 1892'-412' MD, PU 75K, SO 75K.;TOH f/ 412'-134' MD, racking back HWDP, Jars, NMFC, PU 70K, SO 70K.;Remove source from BHA & download tools.;Lay down BHA 6, per HES DD. Bit grade; 1,2,CT, N, X, I, WT, PR. Clear & clean rig floor.;Drain stack of OBM & flush w/ LVT to test BOPE.;BOLDS & pull wear bushing.;lnstall test plug, RILDS, make up test joint, fill stack w/ fresh H2O, 3500 psi test between lower rams & test plug good.;Drain water from stack to below lower rams.;Change lower VBRs to 7" solid body rams.;Test BOPE w/ 5" & 7" test joints to 250 / 3500 psi for 5 minutes each, charted. Gas alarms tested. Completed 6 of 9 tests.;M-06RD wellhead pressure 9-5/8 =40 psi, 13-3/8X9-5/8=50 psi, 28X13-3/8= 0 psi Fluid loss today: 0 bbls Total: 0 bbls Distance to plan 20.54' 4.89' Low 19.95' Left;Daily metal recovered; 0# total 476#. 6/18/2017 Test BOPE w/ 5" & T' test joints to 250 / 3500 psi for 5 minutes each charted. Tested pit level sensors & flow show. Completed final 4 of 10 tests. H2S sensor at shakers failed, replaced same.;Accumulator system full system recovery was outside the range of what had been historical 223 sec vs 187. Cleaned suction screen on #2 pump and adjusted pressure switch; 197 sec on second try.;Remove test plug & install 9" ID wear bushing. Rig down test equipment & blow down all Iines.;Pick up BHA 7, 8.1/2" rotary steerable drilling assembly per HES DO to 113' MD.;Down load to MWD tools. Worked through communication issues between tools & computers.;Shallow hole test MWD tools 475-530 gpm, 1040-1300 psi.;Load sources into MWD tools.;Continue picking up BHA 7 f/ 113'-390' MD, NMFC's, HWDP & Jars PU 78K, SO 77K.;TIH f1390'-3612' MD, PU 130K, SO 117K.;Lost power to the platform. Secure & monitor well, static.;Fill pipe & function test Geo -Pilot at 476525 gpm, 1530-1930 psi, FO 64-68%, 80 rpm, Tq 6K, PU 130K, SO 117K, ROT 125K.;TIH f/ 3612'-7196' MD, PU 180K, SO 130K.;Cut & slip 116' of drill line. Service drawworks, blocks, & top drive. Circulate & condition to shear mud while cut & slip at 210 gpm, 515 psi.;TIH f/ 7196'- 10137 MD, SO 180K, work through 1 fight spot at 8431' MO with 30K max down.;M-06RD wellhead pressure 9-5/8 =40 psi, 13-3/8X9-5/8=60 psi, 28X13-3/8= 0 psi Fluid loss today: 0 bbls Total: 0 bbls Distance to plan 20.54' 4.89 Low 19.95' Left;Daily metal recovered; 09 6/19/2017 TIH V 10137-12979' MD, PU 400K, SO 205K.;Wash & ream f/ 12979'-13272' MD, PU 307K, SO 225K, ROT 240K, 521 gpm, 3180 psi, 120 rpm, Tq 18- 22K.;Drill w/ 8.5" Rotary Steerable f/ 13272'-13312' (40' 26.6'/hr PIG), PU315K, SO 230K, ROT 250K, 521 gpm, WOB 15-20K, on 3170 psi, off 3150 psi, Tq on 20-21K, off 18K, 150 rpm, ECD 10.1, Max Gas 400.;Drill w/ 8.5" Rotary Steerable f/ 13312'-13369 (57' 19'/hr PIG), PU372K, SO 195K, ROT 242K, 526 gpm, WOB 16K, on 3140 psi, off 3120 psi, Tq on 21K, off 18K, 150 rpm, ECD 9.9, Max Gas 12.;Drill w/ 8.5" Rotary Steerable f/ 13369'.13423'(54'18'/hr PIG), PU372K, $O 195K, ROT 242K, 526 gpm, WOB 25K, on 3140 psi, off 3120 psi, Tq on 21 K, off 18K, 120 rpm, ECD 9.9, Max Gas 13.;TOH f/ 13423'-10895' MD, PU 330K, SO 200K. Worked through tight spots (30-40K) at 12970', 12792', 12276', & 12079-12027'; all spots wiped clean.;TOH If 10895'-10516 MD, PU 325K, SO 200K. Removing non rotating protectors, 6 per stand, 4 stands total.;TIH f/ 10516'-11084' MD, PU 330K, SO 201 K.;TIH f/ 11084-13357' MD, PU 330K, SO 205K.;Wash & ream N 13357'-13423' MD, PU 330K, 80 205K, ROT 260K, 455-525 gpm, 2440-3140 psi, 120 rpm, Tq 26K.;Drill w! 8.5" Rotary Steerable f/ 13423'-13469' (46' 15.37hr PIG), PU380K, SO 205K, ROT 260K, 526 gpm, WOB 15-18K, on 3080 psi, off 3000 psi, Tq on 22-23K, off 21-22 K. 100 rpm, ECD 9.8, Max Gas 17.;M-06RD wellhead pressure 9-5/8 =40 psi, 13-3/8X9-5/8=75 psi, 28X13-3/8= 0 psi Fluid loss today: 0 bbls Total: 0 bbls Distance to plan 16.24' 4.96 Low 15.46' Left;Daily metal recovered; 5# total 481# 6/20/2017 Drill w/ 8.5" Rotary Steerable f/ 13469'-13598' (129' 43'/hr PIG), PU375K, SO 197K, ROT 262K, 522 gpm, WOB 12-15K, on 3020 psi, off 3000 psi, Tq on 24- 25K, off 22-23K, 160 rpm, ECD 9.8, Max Gas 1 S.;Drill w/ 8.5" Rotary Steerable f/ 13598'-13675'(77'25.6/hr PIG), PU362K, 5O205K, ROT2621K, 525 gpm, WOB 12-14K, on 3000 psi, off 2990 psi, Tq on 25-26K, off 22K, 160 rpm, ECD 9.9, Max Gas 14.;Drill w/ 8.5" Rotary Steerable f/ 13675'-13732' (57' 19'/hr PIG), PU370K, S0203K, ROT2621K, 525 gpm, WOB 12-14K, on 3020 psi, off 3000 psi, Tq on 25-26K, off 22K, 160 rpm, ECD 9.9, Max Gas 14.;Pump 35 bbl, 9.0 ppg, lube / nut plug sweep. Observed 100% increase in cuttings & a increase in ROP;Drill w/ 8.5" Rotary Steerable f/ 13732'-13828' (96' 327hr PIG), PU362K, S0205K, ROT262K, 525 gpm, WOB 12-14K, on 3040 psi, off 3020 psi, Tq on 25-26K, off 22K,160 rpm, ECD 9.9, Max Gas 14.;Drill w/ 8.5" Rotary Steerable f/ 13728'-13876' (48' 16'/hr PIG), PU362K, S0205K, ROT262K, 545 gpm, WOB 12-14K, on 3200 psi, off 3180 psi, Tq on 25-26K, off 22K, 160 rpm, ECD 9.9, Max Gas 14.;Pump 35 bbl, 9.0 ppg, lube / nut plug sweep. Observed 20% increase in cuttings & no noticeable increase in ROP.;Reaming & washing f/ 13876-13851' MD, PU 380K, SO 220K, ROT 245K, 545 gpm, 3310 psi, Tq on 25K, off 18K, 130 rpm. Working light spot 13850'& 13862' MO.;Drill w/ 8.5" Rotary Steerable f/ 13876-13908' (32' 10.67hr PIG), PU380K, S0220K, ROT2601K, 525 gpm, WOB 30-35K, on 3000 psi, off 2990 psi, Tq on 23-25K, off 21-22K, 120 rpm, ECD 9.7, Max Gas B.;Pump 20 bbl, weighted, lube / nut plug sweep. Observed 100% increase in cuttings & no noticeable increase in ROP.;Drill w/ 8.5" Rotary Steerable f/ 13908'-13921' (32' 10.67hr PIG), PU380K, 5O220K, ROT2601K, 460 gpm, WOB 30-35K, on 2420 psi, off 2410 psi, Tq on 22-24K, off 21-22K, 120 rpm, ECD 9.7, Max Gas B.;W hen trying of wipe the hole on kelly down @ 13921', could not ream or pull past 13912' MD. Attempted many times to ream through w/ 100 rpm, 22- 31 K, staling out.;Pumping at 515 gpm, 2920 psi with no signs of packing off. Attempt straight pull 50K over several times with & without pumps. Alternate trying to ream & straight pull past 13910'.;M-06RD wellhead pressure 9-5/8 =40 psi, 13-3/SX9-5/8=78 psi, 28X13-3/8= 0 psi Fluid loss today: 0 bbis Total: 0 bbis Distance to plan 7.9' 6.42' Low 4.6' RighkDaily metal recovered; 7# total 488# 6/21/2017 Work tight hole f/ 13912'-13904' MD, 464 gpm, 2450 psi, 120 rpm, Tq pulling 28-30K, Tq off 22K, PU 380K, SO 220K, ROT 260K. Alternate back reaming & straight pull to work past.;Circulate for TOH @ 13880'-13831' MD, 470 gpm, 2530 psi, 120 rpm, Tq 21 K, PU 380K, SO 219K, ROT 260K.;TOH f/ 13831'-10990' MD, PU 329K, SO 219K.;Pump 22 bbis / 11 ppg dryjob at 269 gpm, 700 psi, FO 48%. Monitor well, static.;TOH f/ 10990'-7199' MD, PU 210K, SO 160K. Monitor well, static.;TOH f/ 7199'-390' MD, PU 78K, SO 77K.;TOH w/ BHA 7 f/ 390'-110' MD, standing back HWDP, Jars, & NMFC. Calculated fill 126, actual 127 bbls.;Remove sources ff ADL & CTN collars.;TOH & inspect BHA & bit for wear.;Download MWD data from tools.;Lay down BHA 7 as per HES rep.;Clear BHA from rig Floor & clean ;Service drawworks, crown, top drive & rig floor equipment.;Pick up BHA 8 as per HES DD to 110' MD.;Upload MWD tools @ 110' MD.;M- 06RD wellhead pressure 9-5/8 =40 psi, 13-3/8X95/8=80 psi, 28X13-3/8= 0 psi Fluid loss today: 0 bels Total: 0 bbis Distance to plan 8.24' 7.06' Low 4.26' Right.;Daily metal recovered; 13# total 501# 6/222017 TIH f/ 110'-3252' MD, PU 172K, SO 117K, ill pipe every 20 stands. NOV agitator(22.33') installed between stand 12 & 13;1524.74' behind the bit.;TIH f/ 3252'- 7232' MD, PU 185K, SO 149K, fill pipe every 20 stands.;CBU @ 7232' MD, stage up pumps to 500 gpm, 2800 psi, FO 66%.;TIH f/ 7232'-9412' MD, PU 269K, SO 185K.;Fill pipe at 20 stands in & sheer mud pumping 100 bbis, stage up pumps to 500 gpm, 3080 psi, FO 66%.;TIH f/ 9412'-12539' MD, PU 310K, SO 225K.;Fill pipe at 20 stands in & sheer mud pumping 100 bels, stage up pumps to 440-500 gpm, 2630-3430 psi, FO 61-65%.;TIH ff 12539'-13486' MD, PU 375K, SO 210K.;Work tight spot f/ 13486'-13580' MD, observe pack offs, high torque, & over pull to 50K. Attempt back reaming, several times after regaining circulation. Attempt straight pull w/out pumps to 50K over.;Continue to work pipe till able to pull above 13580' MD. Establish circulation & rotation to clean up area.;Ream out f/ 13486'-13580' MD, PU 380K, SO 210K, ROT 250K, 80 rpm, Tq 21 K, 400 gpm, 2340 psi, FO 66%. Observe hole unload w/ cuttings at the shakers, for 2 bottoms up.;Wash & ream f/ 13580'-13921' MD, PU 380K, $O 185K, ROT 270K, 80 rpm, Tq 17-20K, 440 gpm, 2650 psi, FO 60 %.;Drill w/ 8.5" Motor assembly 1113921'-13970'(49'-32.6 fph PIG), PU385K, SO182K, ROT242K, 480 gpm, WOB9-10K, on 3500 psi, off 3350 psi, Tq on 22-24K, off 18-19K, 80 rpm, ECD 9.9, Max Gas 13.;Drill w/ 8.5" Motor assembly f/ 13970'-14175'(206-68.3 fph PIG), PU385K, S01 85K, ROT245K, 480 gpm, WOB 10-12K, on 3550 psi, off 3275 psi, Tq on 21-22K, off 18K, 80 rpm, ECD 10.0, Max Gas 19.;M-06RD wellhead pressure 9-5/8 =40 psi, 13-3/8X9-5/8=85 psi, 28X13-3/8= 2 psi Fluid loss today: 0 bbis Total: 0 bbis Distance to plan 8.09' 4.89' Low 6.45' Right;Daily metal recovered; 9# total 510#. 6/232017 Drill w/ 8.5" Motor assembly f/14175'-14333' (158'-52.6fph PIG), PU385K, 5O180K. ROT245K, 490 gpm, WOB 11-12K, on 3460 psi, off 3250 psi, Tq on 21-22K, off 19K, 100 rpm, ECD 10.0, Max Gas 48.;Pumped 45 bbis, 10.3 ppg, high-vis, lube, nut plug sweep @ 14247' MD. Observed 300-400 % increase in cultings.;Drill w/ 8.5" Motor assembly 1714333'-14490' (157'-52.3fph PIG), PU385K, S01 80K ROT245K, 490 gpm, WOB 9-11 K, on 3480 psi, off 3250 psi, Tq on 22K, off 19K, 100 rpm, ECD 10.0, Max Gas 51.;Pumped tandem - 20 bels ea, 10.3 ppg, low-vis & high-vis, nut plug sweeps @ 14344' MD. Observed 300% increase in cuttings.;Drill w/ 8.5" Motor assembly //14490'-14651' (161'-53.6fph PIG), PU380K, S01 85K, ROT2451K, 490 gpm, WOB 9-10K, on 3510 psi, off 3300 psi, Tq on 22K, off 19K, 100 rpm, ECD 10.0, Max Gas 32.;Pumped tandem - 20 bels ea, 10.3 ppg, low-vis & high-vis, nut plug sweeps @ 14618' MD. Observed 50% increase in cuttings come back 90 bible Iate.;Dri11 w/ 85' Motor assembly f/14651'-1489T (246'-82fph PIG), PU385K, S01 87K, ROT245K, 490 gem, WOB 9-10K, on 3510 psi, off 3300 psi, Tq on 22K, off 19K, 100 rpm, ECD 10.0, Max Gas 22.;Drill wl 8.5" Motor assembly //14897'-14999' (102'-34fph PIG), PU385K, S01 86K, ROT247K, 490 gpm, WOB 9-1 OK, on 3570 psi, off 3390 psi, Tq on 23K, off 19K, 100 rpm, ECD 10.0, Max Gas 19.;Pumped tandem - 20 bbis ea, 10.3 ppg, low-vis & high-vis, nut plug sweeps @ 14908' MD. Observed 300% increase in cuttings. SPR's taken at 14999' MD, 9847' TVD. Attempt to TOH & pull 50K over 2 times coming off bottom. Able to slack off with 21 OK free travel. Attempt to circulate at 1 bpm & pressure up to 900 psi, hole packed off.;Rotate at 50 rpm w/ Tq 20K. Attempt to roll through, tight spot with no success. Attempt to circulate again wt no success. Pull to 50K over, 3 times w/ string free on 4th pull, 149991-14908'MD.;Short trip out of hole 14908'-13890' MD, PU 385K, SO 190K, calculated fill 8.2, actual 11 bbls.;TIH f/ 13890'-14908' MD, PU 380K, SO 190K, calculated displacement 8.2, actual 10 bbls.;Circulate bottoms up f/ 14908'-14999' MD, 490 gpm, 3250 psi, 100 rpm, Tq 21 K, gas 42 units,:Drill w/ 8.5" Motor assembly f/14999'-15092' (93'-31 fph PIG), PU385K, 5O185K, ROT250K, 490 gpm, WOB 12-15K, on 3500 psi, off 3330 psi, Tq on 23K, off 21.5K, 100 rpm, ECD 10.0, Max Gas 19.;Pumped tandem - 20 bels as, 10.3 ppg, low-vis & high-vis, nut plug sweeps @ 14999' MD. Observed 300% increase in cuffings.;Drill w/ 8.5" Motor assembly f/15092'-15282' (190'-63fph PIG), PU385K, S01 90K, ROT250K, 493 gpm, WOB 12-15K, on 3450 psi, off 3350 psi, Tq on 23K, off 20K, 100 rpm, ECD 10.0, Max Gas 9.; Pumped tandem - 20 bbls ea, 10.3 ppg, low-vis & high-vis, nut plug sweeps @ 15192' MD.;M-06RD wellhead pressure 9-5/8 =40 psi, 13-3/8X9-5/8=85 psi, 28X133/8= 0 psi Fluid loss today: 0 bbis Total:0 bbis Distance to plan 13.3 12.61' High 4.22' Right;Daily metal recovered; 18# total 528# 624/2017 Drill w/ 8.5" Motor assembly f/15282'-15472' TD (190'-63fph PIG), PU383K, S01 88K, ROT250K, 493 gem, WOB 10-15K, on 3490 psi, off 3260 psi, Tq on 23- 25K, off 22K, 100 rpm, ECD 10.1, Max Gas 19.;Pumped tandem - 20 bbis as, 10.3 ppg, low -vis & high -vis, nut plug sweeps @ 15210' MD. Observed 75% increase in cuttings.;Circulate hole clean pumping tandem - 30 bbis as, 10.3 ppg, low -vis & high -vis, nut plug sweeps @ 15472' MD, 495 gpm, 3300 psi, 80 rpm, Tq 21K. Observed 150% increase in cuttings.;Pump second tandem - 30 bbis as, 10.3 ppg, low -vis & high -vis, nut plug sweeps @ 15472' MD, 495 gpm, 3300 psi, 80 rpm, Tq 23K, PU 389K, SO 190K, ROT 250K.;Observed 100% increase in cuttings. SPR's taken at 15472' MD, 9911' TVD.;TOH f/ 15472'-13265' MD, PU 375K, SO 200K. Work through tight spots at 13515'& 13017' MD.;Pump 20 bbls, 11.0 ppg dry job at 205 gpm, 755 psi.;TOH V 13265'-7201' MD, PU 205K, SO 160K. Work through tight spots at 12480' & 9254' MD.;Somice rig, adjust drawworks brakes & service. SIMOPS monitor well at top of window, dropped 18" in 30 minutes, less than a 1 bbl to fill.;TOH f/ 7201'-1895' MD, PU 115K, SO 111 K.;Service top drive.;TOH V 1895'-386' MD. Lay down agitator at 1524' MD.;TOH w/ BHA 8, standing back HWDP, Jars, & NMFC. Remove sources from ALD & CTN collars. Download MWD tools.;Lay down BHA 8 as per HES Directional Driller.;M-06RD wellhead pressure 9-5/8 =40 psi, 13-3/8X9-518=90 psi, 28X133/8= 0 psi Fluid loss today: 0 bbls Total: 0 bbis Distance to plan 4.63' .22' High 4.63' Left;Daily metal recovered; 13# total 541 # 6/25/2017 Finish laying down BHA 8, bit graded 2,11,CT, C, X, I, SO, TD. Calculated fill for TOH 139.4, actual 174.3 bbls.;Clear & clean rig floor.;Pick up BHA 9, clean out assembly. PU 8.5 bit, bit sub w/ ported float, 8.375" stab, 3 NMFC, HWDP & Jars to 287' MD.;TIH f/ 28T-7191' MD, SO 181 K.;Cut & slip 123' of drill line. SIMOPS C/O hose & guage on TO, circulate hole to shear mud at 340 gpm, 735 psi, FO 57%.;CBU 7110'-7205' at max rate, PU 190K, SO 155K, ROT 160K, 160 RPM, Tq 9K, 790 gpm, 3240 psi, FO 75%.;TIH f/ 7110'-9479 MD, PU 240K, SO 170K.;Circulate 9479'MD, to shear mud, PU 260K, SO 170K, ROT 205K,100 RPM, Tq 13K, 630 gpm, 2610 psi, FO 72%.;TIH f/ 9479-12133' MD, PU 325K, SO 190K.;CBU @ 12133'-12228' MD, PU 325, SO 190K, ROT 242K, 100 rpm, Tq 19K, 542 gpm, 2360 psi, FO 70%, max gas 110.;TIH f/ 12228'-12692' MD, PU 350K, SO 205K.;Ream out tight spot at 12692'- 12795' MD, PU 360K, SO 205K, ROT 245K, 90 rpm, Tq 19K, 567 gpm, 2660 psi, FO 70%.;TIH f/ 12795'-15258' MD, PU 380K, SO 185K. Calculated displacement 135.7, actual 142.5 bbls.;Wash & ream f/ 15258'-15472' MD, PU 380K, SO 185K, ROT 247K, 100 rpm, Tq 22K, 500 gpm, 2400 psi, FO 70%. At bottoms up observed 200 % increase in cutfings.;Circulate hole clean, pump tandem sweeps 40 bbls low vis 125 bbis high vis, 10.2 ppg, & nut plug. Pump at 500-580 gpm, 2800-3000 psi, 100 rpm, Tq 20-24K. Observed 100% increase in cuttings.;Sweeps came back 100 bbis later than calculated. Increased pumps to 640 gpm, 3450 psi, 150 rpm, Tq 23-24K fill shakers cleaned up. Obtain SPR's at 15472' MD.;TOH V 15472'-13550' MD, PU 375K, SO 205K.;M-06RD wellhead pressure 9-5/8 =40 psi,13- 3/8X9-5/8=85 psi, 28X13-3/8= 0 psi Fluid loss today: 0 bbis Total: 0 bbis Distance to plan 4.63' .22' High 4.63' Left;Daily metal recovered; 5# total 546# 6262017 Ream through tight spot at 13550'-13458' MD, 126 gpm, 320 psi, 100 rpm, Tq 19-23K, PU 350K.;TOH f/ 13458'-12701' MD.;CBU to clean up cuttings bed, 400 gpm, 1400 psi, 120 rpm, Tq 19K, ROT 275K.;TOH f/ 12701'-7205' MD, PU 190K, SO 155K, calculated fill 73,9, actual 74.9 bbis for the trip.;CBU inside the window @ 7205' MD, PU 190K, SO 155K, ROT 162K, 150 rpm, Tq 9K, 670 gpm, 2410 psi, FO 73%.;TIH f/ 7205'-9669' MD, PU 260K, SO 185K.;Fill pipe @ 9669' MD, 199 gpm, 400 psi, FO 41 %, 26.5 bbis to fill.;TIH V 9669'-12417' MD, PU 355K, SO 200K.;Fill pipe @ 12417' MD, 220 gpm, 560 psi, 30 bbis to f1I.;TIH V 12417'-14310' MD, PU 380K, SO 205K.;Fi11 pipe @ 14310' MD, 208 gpm, 590 psi.;TIH f/ 14310'-15258' MD, PU 383K, SO 206K. Calculated displacement for trip 107.5, actual 108.5 bbis for the trip.;Wash & ream f/ 15258'-15472' MD, PU 387K, SO 207K, ROT 255K, 100 rpm, Tq 21 K, 591 gpm, 3000 psi, FO 70 %.;Circulate hole clean at 550 gpm, 2800 psi, FO 68%, 160 rpm, Tq 23K, PU 388K, SO 207K, ROT 255K. Observed 1 st BU w/ 200% increase in cutfings.;Pumped 2 sweeps 25 bbis each, low vis & hig -vis, 10.7 ppg, nut plug. Observed 50% increase in cuttings, 100bb1s lag. Continue pumping 1 more BU to observe the shakers clean up.;Obtain SPR's at 15472' MD. Monitor well 15 minutes, fluid level dropped 6".;TOH f/ 15472'-11830' MD, PU 325K, SO 200K.;M- 06RD wellhead pressure 9-5/8 =40 psi, 133/8X9-518=90 psi, 28X13-3/8= 0 psi Fluid loss today: 21 bbls Total: 53.4 bbis Distance to plan 4.63' .22' High 4.63' Left;Daily metal recovered; 5# total 551# 6/272017 POOH f/ 11830't(7205', through window no issues.;Change out swivel packing on TD, monitor hole static loss @ 2.7 BPH.;CBU, rotate & reciprocate 670GPM, 2400 psi, rot 160 rpm, 8k tq, rot wt. 155, up wt 165, do wt 120, (50% increase at BU).;Pump 20 bbl 11 ppg dry job, drop 2.42" drift, POOH F/7205' t/287'.;Clean & Ud BHA, bit in gauge.;Clean & clear floor.;P/U CMT head, m/u 8' handling pup, r/u & test LJ3500 psi good, check swivel operation, good, I/d same.;P/U & rig up WATCO handling eq. stage cent. on rig floor, m/u safety valve, r/u & test fill up line.;P/U and run 7" liner as per program. Made up and thread locked shoe track assembly, checked float equip. for proper operation, good, cont. in hole 1240' up wt 75k, do wt 75k.;Cont. PIU and run 7" liner as per program. Filling every jt. t/2442', up wt -124, on wt 118k.;M-06RD wellhead pressure 9-518 =40 psi, 133/8X9-5/8=90 psi, 28X13-3/8= 0 psi Fluid loss today: 18 bbis Total: 71 bbls Distance to plan 4.63' .22' High 4.63' Left;Daily metal recovered; 6# total 557# 628/2017 Cont. P/U and run 7" liner as per program. Filling everyjt. topping off every 10, F2442', U7250', up wt 170k, do wt 140.;Circulate & condition mud, @250 gpm, 670 psi, est. parameters, rot 10 rpm, 8k to, rot wt 160k, 20 rpm, 8k tq, 30 rpm, 8k tq.;Cont. rih w 7" liner as per program. Filling every jt. topping off every 10. F/72501, 1/8470', up wt 215k, do wt 155k.;Circulate & condition mud, cbu x-2 @ 250 gpm, 695 psi, est. parameters, rot wt 172k, tq 11 @ 10, 20 & 30 rpm.;PU Baker liner hanger /packer assy. Mix pal and fill tieback sleeve.;Cont. rih w/7" liner on stands 5" dp, circulate first stand down @ 2bpm, 405 psi, up wt 240, do wt 165k, rih making up every 10 stands filling pipe while lowering, rih t/ 12702'.;@ 12702 started taking weight , unable to wk down, broke circulation @ 96 gpm, 530 psi, cont. working & washed down V 12728', cont. circulate & wk stand, lost downward movement, cont wk pipe.;stood back 2 stands, wk t/ 1245U regained free movement both directions.;Cont. rih w/7" liner on stands 5" dp, V13872'. 6/29/2017 Cont. RIH f/13872', 015445' w/ 7" liner on 5" OF, attempt /u, no o.;Circulate & condition mud, circulate casing annulus volume, staging pumps up f/97 gpm, bSO psi, t/254 gpm, 1030 psi.;M/U cmt head, place liner on depth @ 15467', p/u tension V225k.;Circulate & condition mud, stage pumps up t/246 gpm @1040psi.;R/U cmt Iines.;PJSM, r/u blow back Vrig floor U cmt unit, good, pump 5 bbls w/cmt unity fill lines, PT 7501ow, 5150 high, good, Mix & pump 19 bbls 12.5 ppg, spacer, drop lead dart pump 184 bbls 14.9ppg lead;@ 4 bpm 520 psi fcp, mix & pump 54 bbls 15.6pp9tail cmt, drop follow dart, chase w/20 bbls fresh water.;Displace w/rig pumps 421 bbls 9.4 OBM @ 4.2 bpm, 2890 psi (vary pump rates as conditions dictated).;Bumped plug at calculated (421 bbls) pressured up U 3500 psi as per Baker rep. t/set liner hanger @ 7002', bleed off & check floats good. Estimated too of cement 10,000'.;Line up f/cmt unit pressure up 04800 psi Vrelease running tool, slack off & tagged +-16' deep.;PIU free from hanger CBU @10 BPM 810 psi, up wt 200k, do wt 175k, getting coal & fines @ BU UD cmt head, pump 20 bbl 11.4ppg dry job.;POOH, L/d Baker hanger running tools, rotating packer dog sub shear screws had been sheared, packer good.;PN & breakdown cmt head & IN same.;pull wear ring, Install test plug, c/o lower rams VT' U2 7/8" x 5" variables.;R/u Nest ROPE, m/u 4" test jt & install.;M-06RD wellhead pressure 9-518 =40 psi, 13-3/8X9-5/8=88 psi, 28X13-318= 0 psi Fluid loss today: 0 bbls Total: 71 bbls Distance to plan 4.63' .22' High 4.63' Left;Daily metal recovered; total 557# 6/30/2017 Test BOPE as per Hilcorp & AOGCC expectations, test w/4" TJ, 4" ISOP & ball valve, annular, upper & lower rams, 250 low, 3500 high good, test lower rams w/5" TJ , 250 low, 3500 high, good.;R/D test jfs, & test eq, drain test water from stack.;Prep BHA, stock subs & tools V rig floor, strap & tally same, c/o handling eq U4".;M1U 6" bit & 7" scraper assy.;RIH p/u 4" DP & 7" scraper assy. V3305'.;Circulate & condition mud while assisting working boat, 180 gpm, 307 psi.;Cont. p/u 4" DP, f/3305', U 408T up wt 408T, up wt 1 OOk, do wt 95k.;Cont. RIH p/u 4" DP V4152', plu 7" scraper easy. & cont. RIH p/u 4" DP 06838' up wt 130k, do wt 115k.;Circulate & condition mud, stage rate up U 454 gpm, 2600 psi.;M-06RD wellhead pressure 9-5/8 =28 psi, 13-3/8X9-5/8=90 psi, 28X13-3/8= 0 psi Fluid loss today: 0 bbls Total: 71 bbls Distance to plan 4.63' .22' High 4.63' Left;Daily metal recovered; 0 total 557# 7/1/2017 Circulate & condition mud, stage rate up U 454 gpm, 2600 psi, up wt 130, do wt 115.;Cont. rih p/u 4" DIP f/6830', U8400'.;P/U 9 5/8 scraper assy. rih on stands of 5" DP V71732', up wt 185, do wt 165.;Circulate & condition mud, stage pumps up V9.5 BPM, 3200 psi ;Cont. TIH V15238', up wt 320k, do wt 180k.;Kelly up, wash & ream f/15238, V15307'. tag cmt, drill cmt down 075360', Pumps on up wt 305k, do wt 175k, rot wt 200k, 90 rpm, 12-14k tq. circ 9 BPM, 3200 psi.;Circulate & condition , CBU x 3 clean @ 9 BPM, 3200 psi.;POOH 075270', rack back one stand, r/u test casing , fill surface lines & eq. pressure up U2750psi, (10.8 bbls ) held 70 min lost 150psi total, straight line last 12min.;bleed down recover 10.5 bbls, in trip tank, blow down Iines.;Circulate and condition mud, circ 370gpm, 2900 psi, rot 90 rpm, tq.14k rot wt 200, up wt 315k, do wt 180k, clean rig floor prep for displacement, troubleshooting & repair RigWatch system.;Displace wellbore f/OBM U FIW as per procedure, ROT & recip. pipe until tq. increased V17k, Pump 25 bbls 10 PPG High vis spacer, follow with 802 bbls FIW, @ 10 BPM, up wt 325k, do wt 165k;(varying pump rate as dictated by shakers) catching interface in shaker pits, shut down.;Clean f/ rig floor down, clean bushings, & flow box, clean shakees.;POOH 014655' I/d 5" DP cleaning before sending to deck.;M-06RD wellhead pressure 9-5/8 =28 psi, 13-3/8X9- 5/8=90 psi, 28X13-318= 0 psi Fluid loss today: 0 bbls Total: 71 bbls Distance to plan 4.63' .22' High 4.63' Left;Daily metal recovered; 0 72/2017 POOH f/14655' 013910' Ud 5" DP cleaning and removing super sliders before sending to deck.;M/U test plug & landing jt V string, land same hanging off string, M/U 2 7/8" tj while c/o superchoke, r/u lest eq.;Test BOPE as per Hilcorp & AOGCC regs, witness was waived by AOGCC inspector Jim Regg, on 6-30-2017 @15:38 tested w/ 2 7/8" & 5" tj's, 250 low/ 3500 high as per sundry, tested gas system, good.;Blow, down surface eq. r/d test eq. m/u landing jt, Pull test plug & I/d same, prep VPOOH I/d 5" DP.;POOH V13910' t/12576' Ud 5" DP cleaning and removing super sliders before sending to deck.;M-06RD wellhead pressure 9-5/8 =68 psi, 13-3/8X9-5/8=95 psi, 28X13-3/8= 5 psi Fluid loss today: 0 bbls Total: 71 bbls Distance to plan 4.63' .22' High 4.63' Left;Daily metal recovered; 0 total 557 7/3/2017 POOH V12576' 012398' I/d 5" DP cleaning and removing super sliders before sending to deck, up wt 285k, do wt 170k.;POOH f/12398' 08415' 1/d 5" DP cleaning and removing before sending to deck.;P/U single TIH U15360' w/stands 5" DP SLM on way in & document pipe wear, up wt 340k, do wt 180k.;PJSM, du line U production f/ annulus, PT same good, Pump 25 bbl Baraklean pill, w/ FIW till clean returns @ 5 BPM 1250 psi, taking returns V production, Pump 1280 total.;Mix 140 bbls 6% KCL in pit 7, displace well V6% kcl, CIRC staging rate up V 10 bpm, 1900 psi , circ 743 bbls.;POOH f/15360', U 1 1857'stand back 5" DP.;Cut & slip drill Iine.;M-06RD wellhead pressure 9-5/8 =68 psi, 13-3/8X9-5/8=95 psi, 28X13-3/8= 5 psi Fluid loss today: 0 bbls Total: 71 bbls Distance to plan 4.63' .22' High 4.63' Left;Daily metal recovered; 0 total 557 7/4/2017 Cut & Slip Drilling Line 127'- Inspect Top Drive & Derrick - Change Off Drillers Tugger Line -;Cont POH Laying Down 5" D.P. for Inspection - Lay Down 5 Stnd 5" HW For Inspection -Depth 8415;Lay Down 9 5/8" Casing Scraper- Change Elevators To 4";POOH Standing Back 4" D.P., I/d dual 7" scraper assy on way out, install wear bushing, clear tools from floor;R/U E -line P/U e-Ime tools, Gamma, CCL & CBL, surface test tractor Good;M-06RD wellhead pressure 9-5/8 =50 psi, 13-3/8X9-5/8=80 psi, 28X13-3/8= 5 psi Fluid loss today: 0 bbls Total: 71 bbls Distance to plan 4.63' .22' High 4.63' Left;Daily metal recovered; 0 total 557 HHilcorp Energy Company Composite Report Well Name: MRF M-06RD Field: McArthur River County/State: Cook Inlet Offshore Steelhead, Alaska (LAT/LONG): oration (RKB): API #: Spud Date: Job Name: 1711197C M-06RD Completion Contractor AFE #: 1711197C AFE $: Activity Date :... ,. Ops Summary....... 7/4/2017 Run in the hole with eline tools to 13158". Tractor in f/ 13158'-15352" ELM. Log f/15352' currently @ 14867' at report time, Gamma, CCL, & CBL,M-06RD wellhead pressure 9-5/8 =50 psi, 13-3/8X9-5/8=80 psi. 28X13-3/8= 5 psi 7/5/2017 Cont Logging Out Of Hole From 14867 To Liner Top At 7002 With GR/CCUCBL - Log Was Tied In At 15031 to Halliburton LWD Log Dated 06-25-2017 - We Had A Steady Drift Of Correlation as we Logged Up Hole +/- 29' Off When at 7300 MD - Checked Logging Equipment and Could Not Find A Problem - Talked To Engineering Mr. Dan Marlow And Agreed Additional Time Investment To Chase Trouble Was Not Cost Effective,On Site Evaluation Of Cement Top = 8516,Cont POH With Logging Tools And Rig Down Schlumberger,Make Up 4" Safety Joint Crossed Over To Guns - Rig To Pick Up Guns - Picking Up Tripoint 4 1/2" SDP TCP Guns 6 SHPF, 02189', p/u remaining jewelry wl 7" retrievable packer, hydrostatic fill stop valve, & vent subs, in w/5 stands 4" DP, m/u RA sub up/ do wt 92k,Cont. TIH on 4" dip @ 70 fpm, U 7002', run through liner top no sign, up wt 138k, do wt 118k, cont. TIH 09499', up wt 175k, do wt 118k (Note: no bobble with packer entering liner top),M-06RD wellhead pressure 9-5/8=30psi, 13-318X9-5/8=100 psi, 28X13-3/8= 0 psi 7/6/2017 Cont RIH With Tripoint Guns On 4" & 5" to 13,545 - No Indication Fast Fill Valve Had Closed,Rig To Close Fast Fill Valve 13545 MD 9712 TVD - With Packer Not Set And Annulus Open Establish Circulation at 2.8131a1/min with 500psi - Shut Annulus In And Pressure Down D.P. to 800psi - Casing Equlizing With D.P. Pressure - Bleed Down And Repressure To 1,OOOpsi Still Equlizing - Bleed Off and Repressure to 1,500psi - Pressures Still Equlizing - Bleed Off And Repressure to 1,500psi 3 More Times Still Comunicating,Talked Over FWD Plan With Engineering and Agreed To Proceed With Pert Job With Out Underbalance - PU Weight At This Depth 270 SO 170,Cont RIH to a Bull Plug Depth Of 15,215 - Pulled Back to a Bull Plug Depth of 15,180 - RA Marker Depth of 12,463,Rig Up Pollard For Gun Tie In - Run GR/CCL - Pull Strip And Make 4' Adjustment to Tie Into Halliburton LWD Log Dated 06-25-17 - Logged RA Marker at 12,460.5 - Sent Log To Mr. Ramstad Who Quickly Replied Back With A 1' Correction - RA Marker Needed to Move 1T Up Hole,Space Out With RA Tag At 12443.52 for Top Shot At 12972 - Following Procedure Provided By Mr. Dan Marlowe - Established Cir Down Annulus Taking Returns On D.P. with 500psi at 2131al/Min Rate - Set Packer With 30k Down Weight With 9' of Pipe Slackoff - Cir Down D.P. Still Getting Communication To Annulus With 2131bl/Min 450psi - Talked Through Forward Plan With Engineering Mr. Marlowe - Agreed We Would Have to Trip To Ck Tools, Pull Packer Loose With Out Much Visible Overpull - Trip Out With TCP Assembly T/5859' found a washout in DP, up wt 130k, do wt 110k,C/O bad joint, P/T string t/ 500 psi good,TIH 1/5859, 1:112627' filling every 10 stands & testing string t/ 500 psi, (note no bobble at liner top with bull plug or packer through liner top),M-06RD wellhead pressure 9-5/8=30psi, 13-3/8X9-5/8=100 psi, 28X13-3/8= 0 psi 7/7/2017 Cont RIH With Tripoint Guns Filling Each 10Stnds and Pressuretesting D.P. To 500psi Each Fill From 12,627 Bull Plug Depth To 13,479 Leaving 1,682 Lin Ft To Run Dry For A 8,050 Vertical Colume of 8.6PPG Fluid - Cont RIH and Space Out On The Up Stroke at 15180 Bull Plug Depth, 19' Deep - RA Tag at 12,463 DPM - PU 285 SO 165,Rig Up Pollard Wire Line With GR/ CCL - RIH And Pull Strip -Tie In To Halliburton LWD Log For M-06RD Dated 06-25-17 - For ward To Mr. Ramstad For Review - Mr. Ramstad Quickly Responded With A Correlation Corection Or -1' Putting RA Tag At 12,457 LWD Log Depth - We Needed To Move RA Tag Up Hole 13.5' - With Mr. Dalebout's On Site ability - And A Very Quick Turnaround From Mr. Ramstad - Very Timely Op,Space Out In Up Stroke Putting Top shot On Depth At 12,972 as Tied In - Put 8rnds Of RH Rotation While Picking Up - Set Packer With 20k Down Weight With 8' Of Pipe Movement Down - Line Up To Apply Annulus Pressure For Gun Fire & To Monitor D.P. Pressure - Slowly Pressure Up On Annulus to 2,400psi -At 1,200psi We Did See A Pressure Bump & Felt Movement Of D.P. - Tripoing Also Heard Bump On Their Recording Device,Perf w/4 1/2" SDS 60 deg Phasing , 6 SPF TCP GUNS , f/12972'- 013108', 13127'-13455', 13596'-13628', 13650'-13685', 13754'-14023', 14056-14159', 14223'-14269', 14313'-14362', 14369'-144101, 14461'-14649', 14770'-14800', 14812'-15160',Aftempt To Fill Pipe With 47Bb1 Pumped 15Bb1 Over Calculated Fill With Out Catching Pressure (Well Taking Fluid) - Pull Packer Lose With Very Light Drag - Picked Up 15' Past Where We Saw Pipe Movement With 310k Pull,Cir Sims Up With 70 To *0 % Returns - With 570 Bbls Pumped (500Bb1 = Cal) Did See Trace Oil & Shot Gas To Surface - Shut Down - Open Well - Move Pipe An Additional 15' Up 310 to 320K PU - With Well On Trip Tank Establish Loss Rate Or 25 to 30 Bbl/hr,Pull To A Bull Plug Depth Of 14,951 With 310 to 320k PU - Some Flow Back On D.P. (Out Of Balance) - Cir One D.P. Vol 70SPM 900psi,Poh With 5" D.P. - C/O handling eq f/5" t/4", standing back, L/D r/a sub & zo's, bring safety it U Floor, stand back last 5 stands 4"DP, I/d packer & vent valve assy„ L/D 4 1/2" guns, (/2189' t/1 SOT, guns have oil emulsion, cleaning on way out,M-06RD wellhead pressure 93/8=30psi, 13-3/8X9-518=100 psi, 28X13-3/8= 0 psi 7/8/2017 Cont Laying Down Guns - Cleaning Same For Transport - All Guns Had Fired Correctly With Charges Lined Up With Scallops,Pull Wear Bushing - Wash Out Wellhead Area,Service Rig,Set Weatherford Equipment On Rig Floor - Working to Get Summit Equipment To Rig Floor - Worked Boat With Spooler & KCL - ,P/U & service ESP = Anode/Centrilizer, , Gauge, Sib XT150 Type 1, Motor 456 Series, FMSLT, 180 HP, 456 Motor, FMSUTR 180HP, Lower Tandem Seal, Upper Tandem Seal, Gas Separator / Intake, Gas Sep,400 Series, Pump 1, 400 Series, 111 SF2700, Pump 2, 400 Series, 111 SF2700, Pump 3, 400 Series, 111 SF2700, Discharge Head, Bolt on, 2 7/8" 8RD, Ported Pressure Sub, 2 7/8" 8RD ZENITH PORTED PRESSURE SUB Willow control vaNe,1-Jt 2 7/8 6.49 L-80 EUE 8mcI With Summit Equipment = 169.46,Test cable, good, RIH V91T p/u 2 7/8" 6.4# L-80 EUE Sid tubing, drift w/2.33",M-06RD wellhead pressure 9-5/8=30 si 13-3/8X9-5/8=100 psi, 28X13-3/8=0 psi 7/9/2017 Cont Picking Up 2 7/8" Completion From 917 to 2,821 MD - Testing Cable Each 1,000' - Installing Cannon Clamps 1/jnt - Plan Vint to cover 7" Then 1 Every Other Joint In The 9 5/8,Service Rig - Crew Change And IoadPipe Skate,Cont Picking Up 2 7/8" Completion t/6038' MD - Testing Cable Each 1,000'- Installing Cannon Clamps lfnt - Plan 1/jnt to cover 7" Then 1 Every Other Joint In The 9 5/8,Rig Maint. while c/o spools & splice. Static loss @ 20 BPH,Cont Picking Up 2 7/8" Completion 1/9163' MD - Testing Cable Each 1,000' - Installing Cannon Clamps 1 Every Other Joint In The 9 518, (note splice landed on jt 193 will be landed @ 6720'+-) on wt 104k,M-06RD wellhead pressure 9-5/8=30psi, 13-3/8X9-5/8=100 psi, 28X13-3/8= 0 psi 711012017 Cont Picking Up 2 7/8" Completion F 9163 T 11,033 Testing Cable Each 1,000' - Cannon Clamp Every Other Joint,Rig Service While Loading Skate,Change Cable Spools - Splice Cable - Service Rig Equipment While Making Splice - Splice At 1,870 When Landed,Cont Picking Up 2 7/8 ESP Completion Testing Each 1,000'- Cannon Clamp Every Other Joint - Change Flatpack Real at 11,486 (Splice at 1,415 When Landed) From 11,033 to 12,266 - Pick up X Nipple (635' When Landed),Pick Up 2 718 Completion to 12,340 - Pick Up Shallow Set Packer (550 When Landed) M/U cable & cap line penetrations. Wu control line Uvent valve & function test, good„Cont Picking Up 2 7/8 ESP Completion, 1/12340 (changed out bad it, replaced w/extra jt same length) PIU SSSV @ 12422', (valve @ 460' when landed) m/u control line & function tested, good, up wt 180k, do wt 118k,Cont. Picking Up 2 7/8 ESP Completion, U 12824', M/U landing jt & hanger,Mlu penetrator & ss line penetrations f/hanger.,M-06RD wellhead pressure 9-5/8=30psi, 13-3/8X9-5/8=100 psi, 28X13-3/8= 0 psi 7/11/2017 Cont Dressing Hanger 2ea Chem Injection + SSSV + Vent Valve+ ESP Elect Cable - Land Hanger With Elect Penatrator Facing Platte” East - Tighten Lock Down Pins - Weight Ind Reading SO = 120K (Block Wt = 60K) - Held Pressure On SSSV While Landing - Final Test Of ESP Cable & Down Hole Gage After Landing OK,Space Out Landing Joint - Make Up TIW Valve - Rig Up Pollard Slickline With Lubricator And Prong For Pulg Body In X Nipple at 636 - RIH With Same and Land In Plug Body,Fill Pipe & Pressure Up In 500psi Stages to a Final Pressure of 3,800psi to Set Shallow Set Packer - Held Pressure at 3,W0psi for 15Min - Filling Annulus While Holding Pressure - Cont Filling Annulus - Trip Out With Pollard Slick Line & Prong - Re -Dress For Pulling Plug Body And Standby In Lubricator,Cont Pump And Bleed Operation To Get Air Out Of Annulus - Had Two Leaks In Sufice Lines While Pressure Testing - Had To Replace Componets Each Time - Pressure Test Shallow Set Packer at 550' & Hanger Seals to 500psi for 5Min & 1,700Psi For 30Min - Good Test,Pollard RIH to Pull Plug Body From X -Nipple At 636 - Pull Plug Body With Out Trouble - Rig Down Pollard Slick Line,Back Out Landing Joint and Break Down Same,Clear Floor Of ESP Running Tools - Drop Summit Sheaves,Set Back Pressure Valve - Start Rigging to Set Out BOP,Removed all Koomey lines, coiling up in upper well bay. Pulled bell nipple & airboot flanges. Rigged up potato masher & loosened annular cap. Removed choke & kill lines from HCR's. Removed BOP cradle. Layed over skate ramp. Mobilize BOP lifting beam to annular. Begin loosening bolts on annular.,Nipple down annular, double gate, mud cross, single gate & 2 sections of high pressure riser. Demob skate & stage at center deck for rig move. Check nitrogen back up bottles for accumulator.,M-06RD wellhead pressure 9- 5/8=30psi, 13-3/8X9-5/8=100 psi, 28X13.4/8= 0 psi 7/12/2017 Mobilize tree to well bay. Install tree, valves & production piping per NOS Rep & production. SIMOPS C/O mud pump pop off, prep to drain glycol lines, C/O bladder on accumulator back up bottle, & remove valves from 13-5/8" mud cross spool.,Tighten up all connections on tree & piping. SIMOPS drained glycol from lines & remove lines for rig move.,Test tree to 250 psi for 5 minutes and 5000 psi for 15 minutes, charted. Test void to 500 psi for 5 mins & 5000 psi for 15 minutes. Test production lines to valved flow line to 400 psi for visual inspection. Turn M-06RD over to production.,Rig released at 18:00 hes, 7-12-17. Hilcorp Alaska, LLC McArthur River Field Steelhead M-06RD 50733204130100 Sperry Drilling Definitive Survey Report 30 June, 2017 HALLIBURTON Sperry Drilling Company: Hilcorp Alaska, LLC Project: McArthur River Field Site: Steelhead Well: Trading Bay Unit M-06RD Wellbore: M-06RD Design: M-06RD Halliburton Definitive Survey Report Local Coordinate Reference: Well Trading Bay Unit M-06RD TVD Reference: TBU M-6 @ 160.00usft MD Reference: TSU M-6 @ 160.00usft North Reference: True Survey Calculation Method: Minimum Curvature Database: Sperry EDM - NORTH US + CANADA reject McArthur River Field 6/30/2017 lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level leo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 Using geodetic scale factor Well Trading Bay Unit M-06RD Well Position +N/ -S 0.00 usft Northing: 2,499,431.83 usft Latitude: 60" 49'54.291 N +E/ -W 0.00 usft Easting: 214,232.80 usft Longitude: 151° 36'5.544 W Position Uncertainty 0.00 usft Wellhead Elevation: 160.00 usft Water Depth: 187.00usft Wellbore M-06RD Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) 9 (nT) BGGM2017 6/2/2017 _ 16.06 _ 73.71 _ 55,386 Design M-06RD Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,246.02 Vertical Section: Depth From (ND) +NIS +E1 -W Direction (usft) (usft) (usft) (') 0.00 0X0 0.00 13.14 'Survey Program Date 6/30/2017 From To (usft) (usft) Survey (Wellbore) Too] Name Description Survey Date 100.00 3,000.00 M-06 GYD (M-06) NSG WL North seeking gyro on wireline 10/09/2009 3,072.86 7,246.02 MWD (M-06) MWD MWD v3:standard declination 08/31/2009 7,279.00 7,523.64 MWD_Interp Azi+sag(M-06RD) MWD _Interp Azi+sag Fixed:v2:std dec with interpolated azimuth +sag 06/02/2017 7,623.13 15,435.57 MWD+SC+sag(M-06RD) MWD+SC+sag Fixed:v2:standard dec& axial connection +sag 06/07/2017 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/190') (ft) Survey Tool Name 0.00 0.00 0.00 0.00 -160.00 O.DO 0.00 2,499,431.83 214,232.80 0.00 0.00 UNDEFINED 100.00 0.46 161.57 100.00 -60.00 -0.38 0.13 2,499.431.45 214,232.91 0.46 -0.34 NSG_WL(1) 200.00 0.24 141.70 200.00 40.00 -0.93 0.38 2,499,430.90 214,233.16 0.25 -0.81 NSG_WL(1) 300.00 0.40 263.49 300.00 140.00 -1.13 0.17 2,499,430.70 214,232.94 0.56 -1.06 NSG -WL (1) 400.00 0.26 288.30 399.99 239.99 -1.10 -0.40 2,499,430.74 214,232.37 0.20 -1.16 NSG_WL(1) 450.00 0.60 25.90 449.99 289.99 -0.83 -0.39 2,499,431.01 214,232.39 1.37 -0.89 NSG_WL(1) 455.00 0.62 26.49 454.99 294.99 -0.78 -0.37 2,499,431.06 214,232.41 0.42 -0.84 NSG_WL(1) 460.00 0.68 22.53 459.99 299.99 -0.73 -0.34 2,499,431.11 214,232.44 1.50 -0.79 NSG_WL(1) 465.00 0.80 16.24 464.99 304.99 -0.67 -0.32 2,499,431.17 214,232.46 2.89 -0.72 NSG_WL(1) 470.00 0.96 7.53 469.99 309.99 -0.59 -0.31 2,499,431.25 214,232.48 4.16 -0.65 NSG -WI- (1) 475.00 1.12 358.29 474.99 314.99 -0.50 -0.30 2,499,431.34 214,232.48 4.63 -0.56 NSG_WL(1) 6/30201711:26:58AM Page 2 COMPASS 5000.1 Build 81 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well Trading Bay Unit M-06RD Project: McArthur River Field TVD Reference: TBU M-6 @ 160.00usft Site: Steelhead MD Reference: TBU M-6 @ 160.00usft Well: Trading Bay Unit M-06RD North Reference: True Wellbore: M-06RD Survey Calculation Method: Minimum Curvature Design: M-06RD Database: Sperry EDM - NORTH US+CANADA Survey 6730/2017 11:26:58AM Page 3 COMPASS 5000.1 Build 81 Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/.W Northing Easting DLS Section (usft) (°) 0 (usft) (usft) lush) lush) (ft) (ft) (.11001 (ft) Survey Tool Name 480.00 1.37 350.46 479.99 31999 -0.39 -0.31 2,499,431.45 214,232.47 6.04 -0.45 MSG _WL(1) 485.00 1.65 344.73 464.99 324.99 -0.27 -0.34 2,499,431.58 214,232.45 6.36 -0.34 MSG _WL(1) 490.00 2.03 340.70 489.99 329.99 -0.11 -0.39 2,499,431.73 214,232.40 8.02 -0.20 MSG _WL(1) 49500 2.40 339.22 494.98 334.98 007 -0.46 2,499,431.91 214,232.34 7.49 -0.04 NSG_WL(1) 500.00 2.88 337.80 499.98 339.98 0.28 -0.54 2,499,432.13 214,23226 9.69 0.15 MSG _WL(1) 50500 324 336.60 504.97 344.97 0.53 -0.64 2,499,432.38 214,232.17 7.31 0.37 NSG_WL(1) 510.00 3.51 337.21 509.96 349.96 0.80 -0.76 2,499,432.65 214,232.06 5.45 0.61 NSG_WL(1) 515.00 3.72 335.62 514.95 354.95 1.09 -0.89 2,499,432.94 214,231.94 4.65 0.86 NSG-WL(1) 520.00 3.86 336.41 519.94 359.94 1.39 -1.02 2,499,433.25 214,231.81 2.99 1.12 NSG-WL(1) 525.00 3.96 337.76 524.93 364.93 1.70 -1.15 2,499,433.56 214,231.69 2.72 1.40 MSG_WL(1) 530.00 4.09 336.73 529.92 369.92 2.03 -1.29 2,499,433.89 214,231.56 2.97 1.68 NSG_WL(1) 535.00 4.26 336.53 534.90 374.90 2.36 -1.43 2,499,434.23 214,231.42 3.41 1.97 NSG_WL(1) 540.00 4.45 335.28 539.89 379.69 2.71 -1.59 2,499,434.58 214,231.27 4.25 2.28 NSG-WL(1) 545.00 4.60 336.45 544.87 384.87 3.07 -1.75 2,499,434.94 214,231.12 3.52 2.59 MSG_WL(1) 550.00 4.72 337.23 549.86 389.86 3.44 -1.91 2,499,435.32 214,230.97 2.71 2.92 NSG_WL(1) 555.00 4.79 337.89 554.84 394.84 3.83 -2.07 2,499,435.71 214,230.82 1.78 3.26 NSG_WL(1) 560.00 4.89 337.74 559.82 399.82 4.22 -2.23 2,499,436.10 214,230.67 2.02 3.60 NSG_WL(1) 565.00 4.99 338.64 56480 404.80 4.62 -2.39 2,499,436.51 214,230.52 2.53 3.95 MSG_WL(1) 570.00 5.06 339.15 569.78 409.78 5.02 -2.54 2,499,436.92 214,230.38 1.66 4.31 NSG -WL (1) 575.00 5.09 340.19 57476 414.76 5.44 -2.70 2,499,437.34 214,230.23 1.94 4.68 NSG_WL(1) 580.00 5.17 341.54 579.74 419.74 5.86 -2.84 2,499,437.76 214,230.10 2.90 5.06 MSG _WL(1) 585.00 5.22 343.57 584.72 424.72 6.29 -2.98 2,499,438.20 214,229.97 3.81 5.45 NSG_WL(1) 590.00 5.27 345.19 5119.70 429.70 6.73 -3.10 2,499,438.64 214,229.86 3.13 5.85 MSG _WL(1) 595.00 5.33 344.63 594.68 434.68 7.18 -3.22 2,499,439.09 214,229.75 1.58 6.26 MSG _WL(1) 600.00 5.40 346.96 599.66 439.66 TM -3.34 2,499,439.54 214,229.65 4.58 6.67 MSG _WL(1) 610.00 5.46 347.15 609.61 449.61 8.56 -3.55 2,499,440.47 214,229.46 0.63 7.52 MSG _WL(1) 620.00 5.44 350.06 619.57 459.57 9.49 -3.74 2,499,441.41 214,229.29 2.77 8.39 MSG _WL(1) 630.00 5.44 354.58 629.52 469.52 10.42 -3.86 2,499,442.35 214,229.19 4.28 9.27 NSG_WL(1) 640.00 5.45 353.49 639.48 479.48 11.37 -3.96 2,499,443.29 214,229.11 1.04 10.17 MSG _WL(1) 650.00 5.54 35504 649.43 489.43 12.32 4.06 2,499,444.25 214,229.4 1.74 11.08 MSG _WL(1) 66000 5.55 356.60 659.39 499.39 13.28 4.13 2,499,445.21 214,228.99 1.51 12.00 MSG _WL(1) 67000 5.57 0.68 669.34 509.34 14.25 4.15 2,499,446.18 214,228.99 3.96 12.94 MSG _WL(1) 680.00 5.55 357.37 679.29 519.29 15.22 4.17 2,499,447.15 214,229.00 3.21 13.87 MSG _WL(1) 690.00 5.62 357.09 689.24 529.24 16.19 4.22 2,499,448.12 214,228.98 0.75 14.81 MSG _WL(1) 700.00 5.70 358.77 699.20 539.20 17.18 4.25 2,499,449.11 214,228.97 1.84 15.76 MSG _WL(1) 71000 5.77 1.80 709.15 549.15 18.18 4.25 2,499,450.11 214,229.0 3.11 16.74 MSG _WL(1) 720.00 5.84 359.86 719.09 559.09 19.19 4.23 2,499,451.12 214,229.04 2.08 17.72 MSG _WL(1) 730.00 5.86 0.64 729.04 569.04 20.21 4.23 2,499,452.14 214,229.06 0.82 18.72 NSG_WL(1) 740.00 6.05 7.69 738.99 578.99 21.24 4.15 2,499,453.17 214,229.17 7.55 1914 NSG_WL(1) 750.00 6.23 9.24 748.93 588.93 22.30 -3.99 2,499,454.22 214,229.35 2.45 20.81 NSG_WL(1) 6730/2017 11:26:58AM Page 3 COMPASS 5000.1 Build 81 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well Trading Bay Unit M-06RD Project: McArthur River Field TVD Reference: TBU M-6 @. 160.00usft Site: Steelhead MD Reference: TBU M-6 @ 160.00usft Well: Trading Bay Unit M-06RD North Reference: True Wellbore: M-06RD Survey Calculation Method: Minimum Curvature Design: M-06RD Database: Sperry EDM - NORTH US+CANADA Survey 6730201711:26:58AM Page 4 COMPASS 5000.1 Build 81 Map Map Vertical MD Inc Azi TVD TVDSS +M/ -S +FJ -W Northing Easting DLS Section (usft) (1) (') (usft) (usft) (usft) (usft) (ft) (ft) (-/low) (ft) Survey Tool Name 760.00 6.38 10.19 758.87 598.87 23.38 -3.81 2,499,455.30 214,229.56 1.83 21.90 NSG_WL(1) 770.00 6.50 11.38 768.81 608.81 24.48 -3.60 2,499,456.40 214,229.80 1.79 23.02 MSG _WL(1) 780.00 6.80 9.73 778.74 618.74 25.62 -3.39 2,499,457.53 214,230.04 3.56 24.18 MSG _WL(1) 790.00 7.13 8+60 788.67 628.67 2682 -3.19 2,499,458.72 214,230.26 3.57 25.39 MSG _WL(1) 800.00 7.30 8.64 798.59 638.59 28.06 -0.00 2,499,459+96 214,230.48 1.70 26.64 NSG_WL(1) 810.00 7.53 8.40 808.50 648.50 29.34 -2.81 2,499,461.23 214,230.70 2.32 27.93 MSG _WL(1) 820.00 7.91 10.56 818.41 658.41 30.66 -2.59 2,499,462.55 214,230.95 4.78 29.27 MSG _WL(1) 825.00 8.19 10.97 823.36 663.36 31.35 -2.46 2,499,463.23 214,231.10 5.72 29.97 MSG _WL(1) 850.0 8.80 12.37 848.09 668.09 34.96 -1.71 2,499,466.83 214,231.94 2.58 33.66 MSG _WL(1) 875.00 9.42 13.89 872.77 71237 38.82 -0.81 2,499,470.66 214,232.93 2.66 37+62 NSG_WL(1) 900.00 9.85 14.76 897.42 737.42 42.87 0.22 2,499,474.69 214,234.07 1.82 41.80 MSG _WL(1) 925.00 10.56 15.98 922.03 762.03 47.14 1.40 2,499,478.93 214,235.35 2.97 46.23 MSG _WL(1) 950.00 11.43 16.11 946.57 786.57 51.73 2.72 2,499,483.48 214,236.78 3.48 50.99 NSG _WL(1) 975.00 12.26 17.69 971.03 811.03 56.63 4.21 2,499,488.35 214,238.39 3.56 56.11 MSG _WL(1) 1,000.00 13.00 19.03 995.43 835.43 61.82 5.94 2,499,493.49 214,240.24 3.18 61.55 MSG _WL(1) 1,025.00 14.12 19.62 1,019.73 859.73 67.35 7.88 2,499,498.97 214,242.31 4.51 6].38 NSG_WL(1) 1,050.00 14.99 20.23 1,043.93 883.93 73.26 10.02 2,499,504.82 214,244.60 3.53 73.62 MSG _WL(1) 1,075.00 15.93 20.47 1,068.02 908.02 79.51 12.34 2,499,511.01 214,247.07 3.77 80.23 MSG _WL(1) 1,100.00 16.71 20.76 1,092.02 932.02 sees 14.81 2,499,517.53 214,249.70 3.14 87.19 MSG _WL(1) 1,125.00 17.71 20.63 1,115.90 955.90 93.00 17.42 2,499,524.38 214,252.48 4.00 94.53 NSG_WL(1) 1,150.00 18.51 20.67 1,139.66 979.66 100.27 20.16 2,499,531.58 214,255.40 3.20 102.23 NSG-WL(l) 1,175.00 19.32 20.20 1,163.31 1,003.31 107.87 22.99 2,499,539.10 214,258.42 3.30 110.27 MSG _WL(1) 1,200.00 20.36 19.93 1,186.82 1,026.82 115.84 25.90 2,499,547.00 214,261.52 4.18 118.69 MSG _WL(1) 1,225.00 21.19 19.39 1,21020 1,05020 124.19 28.89 2,499,555.28 214,264.70 3.41 127.50 MSG _WL(1) 1,250.00 21.92 19.31 1,233.45 1,073.45 132.85 31.93 2,499,563.87 214,267.96 2.92 136.63 MSG _WL(1) 1,275.00 22.93 19.13 1,256.56 1,096.56 141.86 35.07 2,499,572.79 214,271.32 4.05 146.12 MSG _WL(1) 1,300.00 23.74 19.04 1,279.51 1,119.51 151.22 38.31 2,499,582.07 214,274.78 3.24 155.97 NSG_WL(1) 1,325.00 24.49 18.42 1,302.33 1,142.33 160.89 41.58 2,499,591.66 214,278.30 3.17 166.13 MSG _WL(1) 1,350.00 24.94 18.31 1,325.04 1,165.04 170.81 44.88 2,499,601.50 214,281.83 1.81 176.54 MSG _WL(1) 1,375.00 25.21 18.32 1,347.69 1,187.69 180.87 48.21 2,499,611.47 214,285.40 1.08 187.09 MSG _WL(1) 1,400.00 25.33 18.09 1,370.29 1,210.29 191.01 51.54 2,499,621.52 214,288.98 0.62 197.72 MSG _WL(1) 1,425.00 25.47 18.01 1,39288 1,232.88 201.20 54.86 2,499,631.63 214,29256 0.58 20841 MSG _WL(1) 1,450.00 25.63 17.75 1,415.43 1,255.43 211.46 58.17 2,499,641.81 214,296.12 0.78 219.15 MSG _WL(1) 1,475.00 26.31 17.40 1,43291 1,277.91 221.90 61.48 2,499,652.16 214,299.67 2.79 230.07 MSG _WL(1) 1,500.00 26.86 17.09 1,460.26 1,300.26 232.59 64.80 2,499.662.77 214,303.25 2.27 241.23 MSG _WL(1) 1,525.00 27.43 17.05 1,482.51 1,322.51 243.49 68.14 2,499,673.58 214,306.86 2.28 252.61 MSG _WL(1) 1,550.00 28.27 16.68 1,504.61 1,344.61 254.67 71.52 2,499,684.68 214,310.51 3.47 264.26 MSG _WL(1) 1,575.00 29.25 15.98 1,526.53 1,366.53 266.22 74.89 2,499,696.14 214,314.16 4.09 276.27 MSG _WL(1) 1,600.00 29.85 15.72 1,548.28 1,388.28 278.08 78.26 2,499,707.91 214,317.82 2.45 288.59 NSG-WL(l) 1,625.00 30.48 15.94 1,569.89 1,409.89 290.16 81.69 2,499,719.91 214,321.54 2.56 301.13 NSG_WL(1) 6730201711:26:58AM Page 4 COMPASS 5000.1 Build 81 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well Trading Bay Unit M-06RD Project: McArthur River Field TVD Reference: TBU M-6 @ 160.00usft Site: Steelhead MD Reference: TBU M-6 @ 160.00usft Well: Trading Bay Unit M-06RD North Reference: True Wellbore: M-06RD Survey Calculation Method: Minimum Curvature Design: M-06RD Database: Sperry EDM - NORTH US+CANADA Survey Map Map vertical MD Inc Art TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (I V) (usft) (usft) (usft) (usft) (ft) (ft) (-MOO-) (ft) Survey Tool Name 1,650.00 31.34 16.14 1,591.34 1,43134 302.50 85.24 2,499,732.16 214,325.39 3.46 313.96 MSG _WL(1) 1,675.00 3202 16.43 1,612.62 1,452.62 315.11 88.92 2,499,744.67 214,329.38 2.79 327.07 MSG _WL(1) 1,700.00 32.53 16.51 1,633.75 1,473.75 327.91 92.70 2,499,757.38 214,333.47 2.05 340.40 MSG _WL(1) 1,725.00 33.42 1701 1,65473 1,494]3 340.94 96.63 2,499,7)0.31 214,337.72 372 353.98 MSG _WL(1) 1,750.00 34.25 17.75 1,675.49 1,515.49 354.22 100.79 2,499,783.48 214,342.20 3.71 367.86 NSG_WL(1) 1,775.00 35.04 18.32 1,696.06 1,536.06 367.73 105.19 2,499,796.89 214,346.93 3.42 382.02 NSG_WL(1) 1,800.00 35.84 18.38 1,716.43 1,556.43 381.49 109.75 2,499,810.53 214,351.83 3.20 396.45 MSG _WL(1) 1,825.00 3669 18.51 1,736.58 1,57658 395.52 114.43 2,499,824.44 214,356.85 3.41 411.18 NSG_WL(1) 1,850.00 37.37 18.63 1,756.54 1,596.54 409.79 119.22 2,499,838.59 214,361.99 2.74 426.17 NSG_WL(1) 1,875.00 38.16 18.86 1,776.31 1,616.31 424.29 124.14 2,499,852.96 214,367.26 3.21 441.40 NSG_WL(1) 1,900.00 39.15 19.17 1,795.83 1,635.83 439.05 129.23 2,499,867.60 214,372.71 4.04 456.94 MSG _WL(1) 1,925.00 40.09 19.43 1,815.09 1,655.09 454.10 134.50 2,499,882.51 214,378.34 3.82 472.79 MSG _WL(1) 1,950.00 4076 19.49 1,834.12 1,674.12 469.39 139.90 2,499,897.66 214,384.11 2.68 488.90 MSG _WL(1) 1,975.00 41.63 19.80 1,852.93 1,692.93 484.89 145.44 2,499,913.03 214,390.03 3.57 505.26 MSG _WL(1) 2,000.00 42.41 19.91 1,871.50 1,711.50 500.63 151.12 2,499,928.62 214,396.09 3.13 521.88 MSG _WL(1) 2,025.00 43.11 2014 1,889.86 1,729.86 516.57 156.95 2,499,944.42 214,402.31 2.94 538.73 MSG _WL(1) 2,050.00 43.98 20.51 1,907.98 1,747.98 532.72 162.95 2,499,960.41 214,408.70 3.56 555.81 MSG _WL(1) 2,07500 44.70 20.68 1,925.86 1,765.86 549.08 169.09 2,499,976.61 214,415.24 2.92 573.14 MSG _WL(1) 2,100.00 45.47 20.74 1,943.51 1,783.51 565.63 175.35 2,499,993.01 214,421.90 3.08 590.69 MSG _WL(1) 2,12500 46.43 20.68 1,960.89 1,800.89 58244 18171 2,500,00966 214,42866 3.86 608.50 MSG _WL(1) 2,150.00 47.32 20.54 1,977.98 1,817.98 599.52 188.13 2,500,026.58 214,435.50 3.58 626.59 MSG _WL(1) 2,175.00 48.11 20.57 1,994.80 1,834.80 616.84 194.62 2,500,043.73 214,442.42 3.16 644.93 MSG _WL(1) 2,200.00 48.90 20.39 2,011.36 1,851.36 634.38 201.17 2,500,061.11 214,449.39 3.21 663.50 MSG _WL(1) 2,225.00 49.97 20.56 2,027.62 1,86]62 652.17 207.82 2,500,078.73 214,456.47 4.31 682.34 MSG _WL(1) 2,250.00 50.81 20.50 2,043.56 1,883.56 670.21 214.57 2,500,096.60 214,463.66 3.37 701.44 MSG _WL(1) 2,275.00 51.66 20.55 2,059.21 1,899.21 688.46 221.41 2,500,114.68 214,470.94 3.40 720.77 MSG _WL(1) 2,300.00 52.72 20.58 2,074.54 1,914.54 706.96 228.35 2,500,133.00 214,478.33 4.24 740.36 NSG_WL(1) 2,325.00 53.55 20.59 2,089.54 1,929.54 725.68 23538 2,500,151.55 214,485.81 3.32 760.19 MSG _WL(1) 2,350.00 54.54 20.61 2,104.22 1,944.22 744.62 242.50 2,500,170.31 214,493.39 3.96 780.25 MSG _WL(1) 2,375.00 55.42 20.54 2,118.56 1,958.56 763.79 249.69 2,500,189.30 214,501.06 3.53 800.56 MSG _WL(1) 2,400.00 56.40 20.12 2,132.57 1,972.57 783.20 \256.89 2,500,208.53 214,508.72 4.16 821.10 MSG _WL(1) 2,425.00 57.17 19.80 2,146.27 1,98627 802.86 264.02 2,500,228.01 214,516.34 3.26 841.86 MSG _WL(1) 2,450.00 57.81 19.40 2,159.71 1,999.71 822.72 271.10 2,500,247.69 214,523.89 2.89 862.81 MSG _WL(1) 2,475.00 58.03 19.02 2,172.98 2,012.98 842.73 278.07 2,500,267.52 214,531.35 1.56 883.88 MSG _WL(1) 2,500.00 58.04 18.78 2,186.22 2,026.22 862.79 284.94 2,500,287.41 214,538.70 0.82 904.98 MSG _WL(1) 2,525.00 58.00 18.62 2,199.46 2,039.46 882.88 291.74 2,500,307.32 214,545.99 0.57 926.08 MSG _WL(1) 2,550.00 57.94 18.12 2,212.72 2,052.72 902.99 298.41 2,500,327.27 214,553.16 1.71 947.19 MSG _WL(1) 2,575.00 57.96 17.88 2,225.98 2,065.98 923.15 30496 2,500,347.25 214,560.20 0.82 968.30 MSG _WL(1) 2,600.00 57.67 17.41 2,239.30 2,079.30 943.31 31138 2,500,367.25 214,567.10 1.97 989.40 MSG _WL(1) 2,625.00 i 57.51 17.06 2,252.70 2,092.70 963.47 317.63 2,500,387.25 214,573.85 1.34 1,010.45 MSG _WL(1) 6/30201711:26:58AM Page 5 COMPASS 5000.1 Build 81 Company: Project: Site: Well: Wellbore: Design: Survey Hilcorp Alaska, LLC McArthur River Field Steelhead Trading Bay Unit M-06RD M-06RD M-06RD Halliburton Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Trading Bay Unit M-06RD TBU M-6 @ 160.00usft TBU M-6 @ 160.00usft True Minimum Curvature Sperry EDM - NORTH US+CANADA Vertical Section (ft) Survey Tool Name 1,031.48 NSG_WL(1) 1,052.51 NSG_WL(1) 1,073.56 NSG_WL(1) 1,094.64 NSG_WL(1) 1,115.72 NSG_WL(1) 1,136.77 NSG_WL(1) 1,157.81 NSG _WL(1) 1,178.83 NSG _WL(1) 1,199.86 NSG _WL(1) 1,220.88 NSG_WL(1) 1,241.90 NSG_WL(1) 1,262.95 NSG_WL(1) 1,283.98 NSG_WL(1) 1,304.97 NSG V&(1) 1,325.92 NSG _WL(1) 1,386.95 MWD (2) 1,466.98 MWD (2) 1,543.80 MWD (2) 1,624.04 MWD (2) 1,700.50 MWD (2) 1,781.86 MWD (2) 1,860.57 MWD (2) 1,939.37 MWD (2) 2,017.05 MWD (2) 2,096.88 MWD (2) 2,176.65 MWD (2) 2,255.01 MWD (2) 2,332.95 MWD (2) 2,411.79 MWD (2) 2,491.46 MWD(2) 2,571.31 MWD (2) 2,647.92 MWD (2) 2,727.51 MWD (2) 2,806.10 MWD(2) 2,883.17 MWD (2) 2,962.99 MWD (2) 3,041.50 MWD (2) 3,117.66 MWD (2) 3,194.42 MWD(2) 3,271.60 MWD (2) 61301201711:26:58AM Page 6 COMPASS 5000.1 Build 81 Map Map MD Inc Az) TVD TVDSS +N/ -S +E/ -W Northing Easting DLS (usft) (") (') (usft) (usft) (usft) (usft) (ft) (ft) (°/100') 2,650.00 57.39 16.75 2,266.15 2,106.15 983.63 32376 2,500,407.26 214,580.46 1.15 2.675.00 57.51 16.68 2,279.60 2,119.60 1,003.81 329.82 2,500,427.29 214,587.01 0.53 2,700.00 57.55 16.29 2,293.02 2,133.02 1,024.04 335.80 2,500,447.36 214,593.49 1.33 2,725.00 57.68 16.17 2,306.41 2,146.41 1,044.31 341.70 2,500,467.48 214,599.89 0.66 2,750.00 57.48 16.01 2,319.82 2,159.82 1,064.58 347.55 2,500,487.61 214.606.23 0.97 2,775.00 57.46 15.99 2,333.26 2,173.26 1,08485 363.36 2,500,507.72 214,612.53 0.10 2,800.00 57.38 16.13 2,346.72 2,186.72 1,105.09 359.19 2,500,527.82 214,618.85 0.57 2,825.00 57.36 16.34 2,360.20 2,200.20 1,125.30 365.08 2,500,547.88 214,625.23 0.71 2,850.00 57.43 16.62 2,373.67 2,213.67 1,145.50 371.05 2,500,567.93 214,631.69 0.98 2,875.00 57.42 17.00 2,387.13 2,227.13 1,165.67 377.14 2,500,587.94 214,638.28 1.28 2,900.00 57.47 17.13 2,400.59 2,240.59 1,185.81 383.33 2,500,607.92 214,644.95 0.48 2,925.00 57.61 17.28 2,414.00 2,254.00 1,205.96 389.57 2,500,627.92 214,651.68 0.75 2,950.00 57.48 17.59 2,427.42 2,267.42 1,226.09 395.89 2,500,647.88 214,658.49 1.17 2,975.00 57.22 17.73 2,440.91 2,280.91 1,246.14 402.27 2,500,667.78 214,665.36 1.14 3,000.00 57.28 17.69 2,454.43 2,294.43 1,266.17 408.67 2,500,687.64 214,672.25 0.28 3,072.86 57.06 17.84 2,493.93 2,333.93 1,324.48 427.35 2,500,745.47 214,892.34 0.35 3,168.71 56.93 19.17 2,546.15 2,386.15 1,400.70 452.86 2,500,821.05 214,719.71 1.17 3,260.90 56.93 19.25 2,596.45 2,43645 1,473.65 47828 2,500,893.36 214,746.90 0.07 3,357.21 56.94 19.37 2,649.00 2,489.00 1,549.83 504.97 2,500,968.86 214,775.44 0.10 3,44922 56.50 1950 2.699.48 2,539.48 1.622,36 530.56 2,501,040.75 214,802.80 0.49 3,547.59 56.36 20.67 2,753.88 2,593.88 1,699.34 558.71 2,501,117.02 214,832.81 1.00 3,643.09 56.22 21.20 2,806.88 2,646.88 1,773.54 587.09 2,501,190.50 214,863.00 0.48 3,738.50 56.95 21.71 2,859.42 2,699.42 1,847.66 616.22 2,501,263.88 214,893.93 0.89 3,831.92 57.24 20.45 2,910.18 2,750.18 1,920.84 644.43 2,501,336.36 214,923.91 1.17 3,927.73 56.90 19.67 2,962.26 2,802.26 1,996.38 672.02 2,501,411.20 214,953.33 0.77 4,023.52 56.94 19.24 3,014.54 2,85454 2,072.06 698.75 2,501,486.20 214,981.91 0.38 4,117.41 57.11 18.68 3,065.64 2,905.64 2,146.55 724.34 2,501,560.05 215,009.31 0.53 4,210.85 56.76 18.65 3,116.62 2,956.62 2,220.74 749.40 2,501,633.60 215,036.17 0.38 4,305.63 56.57 18.38 3,168.71 3,008.71 2,295.82 774.55 2,501,708.05 215,063.14 0.31 4,401.60 56.35 18.19 3,221.73 3,061.73 2,371.78 799.64 2,501,783.37 215,090.09 0.28 4,497.82 56.46 17.98 3,274.97 3,114.97 2,447.96 824.52 2,501,858.93 215,116.82 0.21 4,590.07 56.45 17.98 3,325.95 3,165.95 2,521.09 848.26 2,501,931.45 215,142.33 0.01 4,686.07 56.11 17.62 3,379.24 3,219.24 2,597.12 872.67 2.502,006.86 215,168.59 0.47 4,780.89 56.39 17.80 3,431.92 3,271.92 2,672.22 896.65 2,502,081.36 215,194.40 0.33 4,873.99 56.04 18.60 3,483.70 3,323.70 2,745.73 920.82 2,502,154.25 215,220.35 0.81 4,970.50 56.37 18.84 3,537.38 3,377.38 2,821.69 946.56 2,502,229.56 215,247.94 0.40 5,066.34 54.46 18.87 3,591.78 3,431.78 2.896.36 972.06 2,502,303.58 215,275.25 1.99 5,160.45 54.41 19.02 3.646.51 3,486.51 2,968.76 996.91 2,502,375.36 215,301.86 0.14 5,255.33 54.31 18.18 3,701.80 3,541.80 3,041.84 1,021.50 2,502,447.82 215,328.23 0.73 5,350.76 54.32 18.69 3,757.47 3,597.47 3,115.38 1,046.02 2,502,520.73 215,354.53 0.43 Vertical Section (ft) Survey Tool Name 1,031.48 NSG_WL(1) 1,052.51 NSG_WL(1) 1,073.56 NSG_WL(1) 1,094.64 NSG_WL(1) 1,115.72 NSG_WL(1) 1,136.77 NSG_WL(1) 1,157.81 NSG _WL(1) 1,178.83 NSG _WL(1) 1,199.86 NSG _WL(1) 1,220.88 NSG_WL(1) 1,241.90 NSG_WL(1) 1,262.95 NSG_WL(1) 1,283.98 NSG_WL(1) 1,304.97 NSG V&(1) 1,325.92 NSG _WL(1) 1,386.95 MWD (2) 1,466.98 MWD (2) 1,543.80 MWD (2) 1,624.04 MWD (2) 1,700.50 MWD (2) 1,781.86 MWD (2) 1,860.57 MWD (2) 1,939.37 MWD (2) 2,017.05 MWD (2) 2,096.88 MWD (2) 2,176.65 MWD (2) 2,255.01 MWD (2) 2,332.95 MWD (2) 2,411.79 MWD (2) 2,491.46 MWD(2) 2,571.31 MWD (2) 2,647.92 MWD (2) 2,727.51 MWD (2) 2,806.10 MWD(2) 2,883.17 MWD (2) 2,962.99 MWD (2) 3,041.50 MWD (2) 3,117.66 MWD (2) 3,194.42 MWD(2) 3,271.60 MWD (2) 61301201711:26:58AM Page 6 COMPASS 5000.1 Build 81 Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC McArthur River Field Steelhead Trading Bay Unit M-06RD M-06RD M-06RD Local Corordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Trading Bay Unit M-06RD TBU M-6 @ 160.00usft TBU M-6 @ 160.00usft True Minimum Curvature Sperry EDM - NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NlS +E1 -W Northing Easting DIS Section (usft) V) (•) (usft) (usft) (usft) (usft) (ft) (ft) (.1100') (ft) Survey Tool Name 5,444.12 54.33 20.27 3,811.91 3,651.91 3,186.87 1,071.31 2,502,591.59 215,381.56 1.37 3,346.97 MWD (2) 5,539.18 54.17 21.09 3,867.45 3,707.45 3,259.05 1,098.65 2,502,663.07 215,410.56 0.72 3,423.45 MWD (2) 5,633.32 54.42 20.75 3,922.39 3,762.39 3,330.45 1,125.84 2,502,733.79 215,439.59 0.40 3,499.19 MWD (2) 5,728.34 54.59 20.87 3,977.57 3,817.57 3,402.77 1,15333 2,502,805.41 215,468.83 021 3,575.86 MWD (2) 5,823.77 54.52 21.26 4,032.91 3,872.91 3,475.32 1,181.27 2,502,877+26 215,498.53 0.34 3,652.87 MWD (2) 5,919.03 54.42 2051 4,088.27 3,928.27 3,547.75 1,208.91 2,502,948.99 215,527.93 0.65 3,729.68 MWD (2) 6,013.63 54.20 20.29 4,143.46 3,983.46 3,619.76 1,235.69 2,503,020.33 215,556.46 0.30 3,805.90 MWD (2) 6,108.41 54.80 19.40 4,198.50 4,038.50 3,692.34 1,261.88 2,503,092.25 215,584.41 0.99 3,682.53 MWD (2) 6,20260 54.36 19.55 4,253.09 4,093.09 3,764.71 1,287.47 2,503,16397 215,611.76 0.48 3,958.82 MWD (2) 6,296.40 54.52 19.64 4,307.64 4,147.64 3,836.59 1,313.06 2,503,235.21 215,639.10 0.19 4,034.64 MWD (2) 6,390.16 54.49 1997 4,362.08 4,202.08 3,908.41 1,338.93 2,503,306.38 215,666.71 0.29 4,110.46 MWD (2) 6,487.39 54.32 20.99 4,418.67 4,258.67 3,982.48 1,366.59 2,503,379.74 215,696.17 0.87 4,188.88 MWD (2) 6,582.05 54.28 20.16 4,473.91 4,313.91 4,054.45 1,393.60 2,503,451.03 215,724.93 0.71 4,265.10 MWD (2) 6,676.15 54.56 20.11 4,528.66 4,36866 4,126+30 1,419.95 2,503,522.22 215,753.02 0.30 4,341.06 MWD (2) 6,771.75 54.47 20.06 4,584.15 4,424.15 4,199.41 1,446.68 2,503,594.65 215,781.53 0.10 4,418.34 MWD(2) 6,865.97 54.42 19.21 4,638.94 4,478.94 4,271.61 1,472.44 2,503,666.20 215,809.05 0.74 4,494.50 MWD (2) 6,961.34 54.38 19.33 4,694.46 4,534.46 4,344.81 1,498.03 2,503,738.75 215,836.42 DA1 4,571.60 MWD (2) 7,056.06 54.29 18.79 4,749.69 4,589.69 4,417.54 1,523.16 2,503,810.85 215,863.31 0.47 4,648.14 MWD (2) 7,149.76 54.28 18.21 4,804.38 4,644.38 4,489.69 1,547.30 2,503,882.38 215,889.21 0.50 4,723.89 MWD (2) 7,246.02 54,14 16.48 4,860.68 4,700.68 4,564.21 1,570.58 2,503,956.32 215,914.30 1.47 4,801.75 MM (2) 7,279.00 54.19 16.55 4,879.99 4,719.99 4,589.85 1,578.18 2,503,981.76 215,922.52 0.23 4,828.44 MWD_Interp Azi+sag(3) 7,344.15 54.23 16.64 4,918.09 4,758.09 4,640.49 1,593.27 2,504,032.02 215,938.85 0.13 4,881.20 MWD_Intery Azi+sag(3) 7,442.65 49.82 16.80 4,978.68 4,818.68 4,714.84 1,615.60 2,504,105.80 215,962.98 4.48 4,958.67 MWD_Inter, AEi+sag(3) 7,523.64 48.72 16.95 5,031.53 4,871.53 4,773.57 1,633.42 2,504,164.08 215,982.23 1.37 5,019.91 MWD _Interp Azi+sag(3) 7,623.13 45.65 17.14 5,099.14 4,939.14 4,843.34 1,654.80 2,504,233.30 216,005.31 3.09 5,092.72 MWD+SC+sag(4) 7,722.42 40.17 15.20 5,171.83 5,011.83 4,908.22 1,673.68 2,504,297.70 216,025.76 5.68 5,160.19 MWD+SC+sag(4) 7,813.13 38.34 9.69 5,242.09 5,082.09 4,964.21 1,686.09 2,504,353.37 216,039.53 4.34 5,217.53 MWD+SC+sag(4) 7,901.85 36.21 7.09 5,312.69 5,152.69 5,017.35 1,693.96 2,504,406.30 216,048.70 2.99 5,271.07 MWD+SC+sag(4) 7,999.01 30.03 5.08 5,394.03 5,234.03 5,070.09 1,699.66 2,504,458.90 216,055.68 6.46 5.323.73 MWD+SC+sag(4) 8,095.50 26.03 4.33 5,479.18 5,319.18 5,115.27 1,703.40 2,504,50397 216,060.52 4.16 5,368.68 MWD+SC+sag(4) 8,185.72 22.98 2.47 5,561.27 5,401.27 5,152.62 1,705.65 2,504,541.25 216,063.69 3.49 5,405.46 MWD+SC+sag(4) 8,284.83 19.30 359.56 5,653.70 5,493.70 5,188.34 1,706.36 2,504,576.94 216,065.27 3.86 5,440.40 MWD+SC+sag(4) 8,376.13 17.70 357.81 5,740.28 5,580.28 5,217.30 1,705.71 2,504,605.91 216,065.33 1.85 5,468.46 MWD+SC+sag(4) 8,475.62 11.88 346.90 6,836.45 5,676.45 5,242.41 1,702.81 2,504,631.08 216,063.04 6.46 5,492.25 MWD+SC+sag(4) 8,570.97 12.38 345.59 5,929.67 5,76967 5,261.87 1,698.04 2,504,650.65 216,058.75 0.60 5,510.12 MWD+SC+sag(4) 8,666.36 14.67 349.14 6,022.41 5,862.41 5,283.64 1,693.22 2,504,672.53 216,054.46 2.55 5,530.22 MWD+SC+sag(4) 8,766.10 12.26 347.30 6,119.40 5,959.40 5,306.38 1,688.51 2,504,695.38 216,050.31 2.45 5,551.29 MWD+SC+sag (4) 8,856.23 12.95 345.91 6,207.36 6,047.36 5,325.51 1,683.95 2,504,714.61 216,046.21 0.84 5,568.89 MWD+SC+sag(4) 8,952.36 13.67 348.30 6,300.90 6,140.90 5,347.08 1,679.02 2,504,736.30 216,041.82 0.94 5,588.77 MWD+SC+seg(4) 9,047.95 12+60 356.73 6,394.00 6,234.00 5,368.55 1,676.14 2,504,757.84 216,039.45 2.29 5,609.03 MWD+SC+sag(4) 6130 O17 11:26:58AM Page 7 COMPASS 5000.1 Build 81 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Coordinate Reference: Well Trading Bay Unit M-06RD Project: McArthur River Field TVD Reference: TBU M-6 @ 160.00usft Site: Steelhead MD Reference: TBU M-6 @ 160.00usft Well: Trading Bay Unit M-06RD North Reference: True Wellbore: M-06RD Survey Calculation Method: Minimum Curvature Design: M-06RD Database: Sperry EDM - NORTH US+CANADA �- Survey Map Map Vertical MD Inc Ali TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (°) (I (usft) (usft) (usft) (usft) (ft) (ft) (-/100') (ft) Survey Tool Name 9,142.7] 12.83 0.65 6,486.50 6,326.50 5,389.40 1,675.67 2,504,778.69 216,039.49 0.94 5,629.23 MWD+SC+sag(4) 9,237.31 13.23 0.57 6,578.60 6,418.60 5,410.72 1,675.89 2,504,600.00 216,040.24 0.42 5,650.03 MWD+SC+sag(4) 9,332.95 14.21 358.53 6,671.51 6,511.51 5,433.40 1,675.70 2,504,822.67 216,040.60 1.14 5,672.08 MWD+SC+sag(4) 9,426.34 13.49 355.61 6,762.19 6,602.19 5,455.72 1,674.57 2,504,64501 216,040.02 1.07 5,693.56 MWD+SC+sag(4) 9,521.29 12.69 356.31 6,854.67 6,684.67 5,477.17 1,673.05 2,504,866.49 216439.02 0.86 5,714.10 MWD+SC+sag(4) 9,61649 12.22 352.85 6,947.63 6,787.63 5,497.60 1,671.13 2,504,886.97 216,037.60 093 5,733.56 MWD+SC+sag(4) 9,711.14 12.75 2.19 7,040.05 6,880.05 5,517.98 1,670.28 2,504,907.36 216,037.25 2.20 5,753.21 MWD+SC+sag(4) 9,807.53 14.74 2.53 7,133.68 6,973.68 5,540.86 1,671.23 2,504,930.21 216,038.75 2.07 5,775.71 MWD+SC+sag(4) 9,899.15 15.42 358.71 7,222.14 7,062.14 5,564.68 1,671.47 2,504,954.02 216,039.57 1.31 5,798.96 MWD+SC+sag(4) 9,991.69 13.72 356.15 7,311.71 7,151.71 5,587.93 1,670.45 2,504,977.29 216,039.13 1.95 5,821.37 MWD+SC+sag(4) 10,079.27 11.68 354.54 7,397.14 7,237.14 5,607.12 1,668.91 2,504,996.51 216,038.06 2.36 5,839.71 MWD+SC+sag(4) 10,178.77 13.89 355.44 7,494.17 7,334.17 5,629.06 1,667.01 2,505,018.48 216,036.68 2.23 5,860.64 MWD+SC+sag(4) 10,278.10 13.61 354.16 7,590.65 7,430.65 5,652.57 1,664.87 2,505,042.04 216,035.12 0.42 5,883.04 MWD+SC+sag(4) 10,372.77 12.66 352.41 7,682.84 7,522.84 5,673.93 1,662.36 2,505,063.46 216,033.14 1.09 5,903.28 MWD+SC+sag(4) 10,468.02 12.94 356.07 7,775.73 7,615.73 5,694.92 1,660.25 2,505.084.49 216,031.54 0.90 5,923.24 MWD+SC+sag(4) 10,563.92 12.40 350.83 7,86929 7,709.29 5,715.80 1,657.88 2,505,105.42 216,029.68 1.32 5,943.03 MWD+SC+sag(4) 10,659.78 9.05 335.79 7,963.48 7,803.48 5,732.84 1,653.14 2,505,122.58 216,025.36 4.53 5,958.55 MWD+SC+sag(4) 10,752.30 5.87 315.50 8,055.22 7,895.22 5,742.86 1,646.84 2,505,132.74 216,019.30 4.41 5,966.87 MWD+SC+sag(4) 10,847.20 6.25 283.27 8,149.62 7,989.62 5,747.50 1,638.41 2,505,137.59 216,010.99 3.56 5,969.48 MWD+SC+sag(4) 10,943.65 8.24 263.31 8,245.31 8,085.31 5,747.90 1,626.43 2,505,138.29 215,999.02 3.30 5,967.15 MWD+SC+sag(4) 11,037.22 8.56 237.91 8,337.91 8,M,91 5,743.42 1,613.87 2,505,134.11 215,986.35 3.95 5,959.93 MWD+SC+sag(4) 11,134.00 12.46 218.52 8,433.08 8,273.08 5,731.42 1,601.25 2,505,122.42 215,973.45 5.39 5,945.37 MWD+SC+sag (4) 11,225.55 16.44 204.25 8,521.74 8,361.74 5,711.87 1,589.78 2,505,103.15 215,961.50 5.80 5,923.72 MWD+SC+sag(4) 11,323.62 20.35 202.84 8,614.78 8,45436 5,683.49 1,577.45 2,505,075.08 215,948.49 4.01 5,893.28 MWD+SC+sag(4) 11,418.51 21.36 202.99 8,703.45 8,543.45 5,652.37 1,564.30 2,505,044.30 215,934.58 1.07 5,859.99 MWD+SC+sag(4) 11,513.74 24.24 206.01 8,791.24 8,631.24 5,618.83 1,548.95 2,505,011.14 215,918.41 3.26 5,823.84 MWD+SC+sag(4) 11,608.77 2737 205.79 8,876.78 8,716.78 5,581.62 1,530.88 2,504,974.39 215,899.45 3.30 5,783.50 MWD+SC+sag(4) 11,703.69 28.29 203.15 8,960.72 8,800.72 5,541.29 1,512.55 2,504,934.52 215,880.13 1.62 5,740.05 MWD+SC+sag(4) 11,]99.05 32.36 200.24 9,043.02 8,883.02 5,496.55 1,494.83 2,504,890.22 215,861.32 4.54 5,692.45 MWD+SC+sag(4) 11,892.09 38.09 198.08 9,119.00 8.959.00 5,445.86 1,477.29 2,504,839.97 215,842.56 6.30 5,639.11 MWD+SC+sag(4) 11,986.67 44.07 199.31 9,190.26 9,030.26 5,387.03 1,457.34 2,504,781.65 215,821.18 6.38 5,577.28 MWD+SC+sag(4) 12,081.44 50.47 200.19 9,254.53 9,094.53 5,321.56 1,433.81 2,504,716]7 215,79605 6.79 5.508.17 MWD+SC+sag(4) 12,175.61 53.62 199.46 9,312.44 9,152.44 5,251.71 1,408.64 2,504,647.56 215,769.18 3.40 5,434.44 MWD+SC+sag(4) 12,272.50 56.51 197.96 9,367.92 9,207.92 5,176.48 1,383.18 2,504,572.98 215,741.90 3.24 5,355.39 MWD+SC+sag(4) 12,367.27 57.54 197.31 9,419.50 9,259.50 5,100.72 1,359.09 2,504,497.82 215,715.97 1.23 5,276.13 MWD+SC+sag(4) 12,462.23 60.91 199.57 9,468.09 9,308.09 5,023.35 1,333.27 2,504,421.11 215,688.26 4.10 5,194.92 MWD+SC+sag(4) 12,552.72 65.85 197.48 9,508.63 9,348.63 4,946.66 1,307.60 2,504,345.07 215,660.74 5.84 5,114.40 MWD+SC+sag(4) 12,649.66 72.45 193.41 9.543.12 9,383.12 4,859.39 1,283.57 2,50.258.41 215,634.58 7.86 5,023.96 MWD+SC+sag(4) 12,744.77 74.76 192.88 9,569.97 9,409.97 4,770.55 1,262.82 2,504,170.10 215,611.67 2.49 4,932.72 MWD+SC+sag(4) 12,839.74 74.87 191.59 9,594.85 9,434.85 4,680.98 1,243.40 2,504,081.03 215,590.06 1.32 4,841.08 MWD+SC+sag(4) 6/30/2017 11:26:58AM Page 8 COMPASS 5000.1 Build 81 Survey Map Map vertical MD Inc AA TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°flOPJ (R) Survey Tool Name 12,932.66 73.92 192.33 9,619.84 9,459.84 4,593.42 1,224.85 2,503,993.96 215,569.39 1.28 4,751.60 MWD+SC+sag(4) 13,029.17 75.39 193.62 9,645.38 9,485.38 4,502.74 1,203.95 2,503,903.81 215,546.28 2.00 4,658.54 MWD+SC+sag(4) 13,123.84 79.82 195.47 9,665.70 9,505.70 4,413.27 1,180.73 2,503,814.93 215,520.88 5.05 4,566.13 MWD+SC+sag (4) 13,218.65 84.45 198.32 9,678.67 9,518.67 4,323.44 1,15343 2,503,725.80 215,491.40 5.72 4,472.45 MWD+SC+sag(4) 13,267.74 83.24 198.17 9,683.93 9,523.93 4,277.09 1,138.15 2,503,679.84 215,474.99 2.48 4,423.84 MWD+SC+sag(4) 13,322.14 83.39 19819 9,690.27 9,530.27 4,225.84 1,121.02 2,503,629.03 215,456.62 1.17 4,370.04 MWD+SC+sag(4) 13,416.39 82.92 198.11 9,701.50 9,541.50 4,137.08 1,091.41 2,503,541.01 215,424.85 0.87 4,276.87 MWD+SC+sag(4) 13,511.09 83.67 198.13 9,712.56 9,552.56 4,047.69 1,062.16 2,503,452.36 215,393.42 0.79 4,183.17 MWD+SC+sag(4) 13,606.39 83.10 199.58 9,723.54 9,563.54 3,958.11 1,031.57 2,503,363.55 215,360.66 1.63 4,088.98 MWD+SC+sag(4) 13,701.97 84.92 198.41 9,733.51 9,573.51 3,868.23 1,000.63 2,503,274.46 215,327.53 2.26 3,994.42 MWD+SC+sag(4) 13,796.67 85.08 197.70 9,741.76 9,581.76 3,778.54 971.39 2,503,185.51 215,296.12 0.77 3,900.43 MWD+SC+sag(4) 13,892.84 84.88 196.74 9,750.18 9,590.18 3,687.03 943.03 2,503,094.72 215,265.53 1.02 3,804.87 MWD+SC+sag(4) 13,918.14 85.05 196.54 9,752.40 9,592.40 3,662.88 935.81 2,503,070.76 215,257.73 1.04 3,779.72 MWD+SC+sag(4) 14,013.45 85.99 197.04 9,759.84 9,599.84 3,571.92 908.37 2,502,980.49 215,228.07 1.12 3,684.89 MWD+SC+sag(4) 14,108.50 85.25 196.60 9,767.10 9,607.10 3,481.20 880.94 2,502,890.7 215,198.44 0.91 3,590.32 MWD+SC+sag(4) 14,204.01 84.94 196.69 9,775.27 9,61527 3,390.03 853.68 2,502,799.99 215,168.96 0.34 3,495.34 MWD+SC+sag(4) 14,298.50 84.69 195.93 9,783.81 9,62381 3,299.71 827.26 2,502,710.35 215,140.34 0.84 3,401.38 MWD+SC+sag(4) 14,392.93 84.76 196.17 9,792.49 9,632.49 3,209.35 801.26 2,502,620.64 215,112.14 0.26 3,307.47 MWD+SC+sag(4) 14,487.10 84.63 195.75 9,801.20 9,641.20 3,119.19 775.48 2,502,531.15 215,084.17 0.47 3,213.82 MWD+SC+sag(4) 14,581.70 85.56 19656 9,809.29 9,649.29 3,028.66 74925 2,502,441.29 215,055.74 1.30 3,119.69 MWD+SC+sag(4) 14,676.75 85.31 195.87 9,816.85 9,656.85 2,937.69 722.80 2,502,350.98 215,027.07 0.77 3,025.08 MWD+SC+sag(4) 14,771.50 85.01 195.68 9,824.85 9,664.85 2,846.83 697.13 2,502,260.78 214,999.20 0.37 2,930.77 MWD+SC+sag(4) 14,867.10 84.45 194.62 9,833.63 9,673.63 2,754.94 672.25 2,502,169.53 214,972.08 1.25 2,835.64 MWD+SC+sag(4) 14,984.56 83.51 194.61 9,843.85 9,683.85 2,661.16 647.79 2,502,076.37 214,945.34 0.96 2,738.75 MWD+SC+sag(4) 15,056.97 82.70 195.08 9,854.94 9,694.94 2,572.48 624.29 2,501,988.29 214,919.68 1.01 2,647.05 MWD+SC+.g(4) 15,153.04 82.45 194.95 9,867.36 9,707.36 2,480.47 599.61 2,501,896.91 214,892.76 0.29 2,551.83 MWD+SC+sag(4) 15,245.60 81.96 194.89 9,879.91 9,71991 2,391.86 576.00 2,501,808.90 214,867+0 0.53 2,460.17 MWD+SC+sag(4) 15,341.19 81.77 194.85 9,893.44 9,733.44 2,300.40 551.71 2,501,718.06 214,840.49 0.20 2,365.59 MWD+SC+sag(4) 15,435.57 82.28 194.45 9,906.53 9,746.53 2,209.97 528.08 2,501,628.24 214,814.65 0.68 2,272.15 MWD+SC+sag(4) 15,472.00 82.28 194.45 9,911.43 9,751.43 2,175.01 519.07 2,501,593.51 214,804.79 0.00 2,236.06 PROJECTEDto TD Michael Calkins bn.w ea ero a urto a.a +rw -m Checked By: -^ Approved By: n.cum W Date: 6/30/17 6/302017 11:26:58AM Page 9 COMPASS 5000.1 Build 81 i Halliburton 1 Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well Trading Bay Unit M-06RD Project: McArthur River Field TVD Reference: TBU M-6 @ 160.00usft Site: Steelhead MD Reference: TBU M-6 @ 160.00usft Well: Trading Bay Unit M-06RD North Reference: True Wellbore: M-06RD Survey Calculation Method: Minimum Curvature Design: M-06RD Database: Sperry EDM - NORTH US + CANADA Survey Map Map vertical MD Inc AA TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°flOPJ (R) Survey Tool Name 12,932.66 73.92 192.33 9,619.84 9,459.84 4,593.42 1,224.85 2,503,993.96 215,569.39 1.28 4,751.60 MWD+SC+sag(4) 13,029.17 75.39 193.62 9,645.38 9,485.38 4,502.74 1,203.95 2,503,903.81 215,546.28 2.00 4,658.54 MWD+SC+sag(4) 13,123.84 79.82 195.47 9,665.70 9,505.70 4,413.27 1,180.73 2,503,814.93 215,520.88 5.05 4,566.13 MWD+SC+sag (4) 13,218.65 84.45 198.32 9,678.67 9,518.67 4,323.44 1,15343 2,503,725.80 215,491.40 5.72 4,472.45 MWD+SC+sag(4) 13,267.74 83.24 198.17 9,683.93 9,523.93 4,277.09 1,138.15 2,503,679.84 215,474.99 2.48 4,423.84 MWD+SC+sag(4) 13,322.14 83.39 19819 9,690.27 9,530.27 4,225.84 1,121.02 2,503,629.03 215,456.62 1.17 4,370.04 MWD+SC+sag(4) 13,416.39 82.92 198.11 9,701.50 9,541.50 4,137.08 1,091.41 2,503,541.01 215,424.85 0.87 4,276.87 MWD+SC+sag(4) 13,511.09 83.67 198.13 9,712.56 9,552.56 4,047.69 1,062.16 2,503,452.36 215,393.42 0.79 4,183.17 MWD+SC+sag(4) 13,606.39 83.10 199.58 9,723.54 9,563.54 3,958.11 1,031.57 2,503,363.55 215,360.66 1.63 4,088.98 MWD+SC+sag(4) 13,701.97 84.92 198.41 9,733.51 9,573.51 3,868.23 1,000.63 2,503,274.46 215,327.53 2.26 3,994.42 MWD+SC+sag(4) 13,796.67 85.08 197.70 9,741.76 9,581.76 3,778.54 971.39 2,503,185.51 215,296.12 0.77 3,900.43 MWD+SC+sag(4) 13,892.84 84.88 196.74 9,750.18 9,590.18 3,687.03 943.03 2,503,094.72 215,265.53 1.02 3,804.87 MWD+SC+sag(4) 13,918.14 85.05 196.54 9,752.40 9,592.40 3,662.88 935.81 2,503,070.76 215,257.73 1.04 3,779.72 MWD+SC+sag(4) 14,013.45 85.99 197.04 9,759.84 9,599.84 3,571.92 908.37 2,502,980.49 215,228.07 1.12 3,684.89 MWD+SC+sag(4) 14,108.50 85.25 196.60 9,767.10 9,607.10 3,481.20 880.94 2,502,890.7 215,198.44 0.91 3,590.32 MWD+SC+sag(4) 14,204.01 84.94 196.69 9,775.27 9,61527 3,390.03 853.68 2,502,799.99 215,168.96 0.34 3,495.34 MWD+SC+sag(4) 14,298.50 84.69 195.93 9,783.81 9,62381 3,299.71 827.26 2,502,710.35 215,140.34 0.84 3,401.38 MWD+SC+sag(4) 14,392.93 84.76 196.17 9,792.49 9,632.49 3,209.35 801.26 2,502,620.64 215,112.14 0.26 3,307.47 MWD+SC+sag(4) 14,487.10 84.63 195.75 9,801.20 9,641.20 3,119.19 775.48 2,502,531.15 215,084.17 0.47 3,213.82 MWD+SC+sag(4) 14,581.70 85.56 19656 9,809.29 9,649.29 3,028.66 74925 2,502,441.29 215,055.74 1.30 3,119.69 MWD+SC+sag(4) 14,676.75 85.31 195.87 9,816.85 9,656.85 2,937.69 722.80 2,502,350.98 215,027.07 0.77 3,025.08 MWD+SC+sag(4) 14,771.50 85.01 195.68 9,824.85 9,664.85 2,846.83 697.13 2,502,260.78 214,999.20 0.37 2,930.77 MWD+SC+sag(4) 14,867.10 84.45 194.62 9,833.63 9,673.63 2,754.94 672.25 2,502,169.53 214,972.08 1.25 2,835.64 MWD+SC+sag(4) 14,984.56 83.51 194.61 9,843.85 9,683.85 2,661.16 647.79 2,502,076.37 214,945.34 0.96 2,738.75 MWD+SC+sag(4) 15,056.97 82.70 195.08 9,854.94 9,694.94 2,572.48 624.29 2,501,988.29 214,919.68 1.01 2,647.05 MWD+SC+.g(4) 15,153.04 82.45 194.95 9,867.36 9,707.36 2,480.47 599.61 2,501,896.91 214,892.76 0.29 2,551.83 MWD+SC+sag(4) 15,245.60 81.96 194.89 9,879.91 9,71991 2,391.86 576.00 2,501,808.90 214,867+0 0.53 2,460.17 MWD+SC+sag(4) 15,341.19 81.77 194.85 9,893.44 9,733.44 2,300.40 551.71 2,501,718.06 214,840.49 0.20 2,365.59 MWD+SC+sag(4) 15,435.57 82.28 194.45 9,906.53 9,746.53 2,209.97 528.08 2,501,628.24 214,814.65 0.68 2,272.15 MWD+SC+sag(4) 15,472.00 82.28 194.45 9,911.43 9,751.43 2,175.01 519.07 2,501,593.51 214,804.79 0.00 2,236.06 PROJECTEDto TD Michael Calkins bn.w ea ero a urto a.a +rw -m Checked By: -^ Approved By: n.cum W Date: 6/30/17 6/302017 11:26:58AM Page 9 COMPASS 5000.1 Build 81 Lease & Well No. County Hilcorp Energy Company CASING & CEMENTING REPORT MRF M-06RD Cook Inlet Offshore Steelhead State Alaska Supv. CASING RECORD Lirrer TD 15,472.00 Shoe Depth: 15,467.00 No. Jts. Delivered 224 No. Jts. Run Date Run 29Jun-17 Hauck / Soule _ PBTD: 15,346.63 208 No .Its. Rehimed 17 Csg Wt. On Hook: Type Float Collar. Csg Wt. On Slips: Type of Shoe: _ Rotate Csg Yes X No Recip Csg _ Yes X Fluid Description: OEM Liner hanger Info (Make/Model): Baker HRD-E, SCD Liner hanger test pressure: 2750 Centralizer Placement: Every jt F/10836'T11 5309. One on shoe track. CEMENTING REPORT _ No. Him to Run: Casing Crew: No 70 Ft. Min. 2ft 5 WUI UU 9.4 PPG Liner top Packer?: X Yes No Floats Held X Yes No Shoe @ 15467 FC @ 15,389.00 Top of Liner 7002 lush (Spacer) .. Tuned Spacer Density (ppg) 12.5 Volume pumped (BBLs) 20 I Slurry .. Easy Blok Sacks: 785 Yield: 1.32 city (ppg) 14.9 Volume pumped (BBLs) 186 Mixing / Pumping Rate (bpm): 4 Slurry Easy Block Sacks: 255 Yield: 1.19 ;ily (ppg) 15.6 Volume pumped (BBLs) 59.6 Mixing / Pumping Rate (bpm): 4 : Flush (Spacer) Density (ppg) Rate (bpm): Volume: _ acement: CBM Density (ppg) 9.4 Rate (bpm): 4 Volume (actual / calculated): 421 (psi): 2973 Pump used for disp: Rig Bump Plug? X Yes No Bump press ig Rotated? _Yes X No Reciprocated? _Yes X No % Returns during job 100 ant returns to surface? _Yes X No Spacer retums?_Yes X No Vol to Surf: ant In Place At: 15:00 Date: 6/29/2017 Estimated TOC: 8,520 od Used To Determine TOC: CBL --46 7, 5� WA G� Post Job Calculations: �If j� i.r1•i7 Calculated Cmt Vol @ 0% excess: 126.4 Total Volume curt Pumped: 245.6 Cmt returned to surface: 0 Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: www.wellez.net WellEz Information Management LLC ver 102716bf Casing (Or Liner) Detail Setting Depths As. Component Size Wt. Grade THD Make Length Bottom Top SHOE 73/4 29.0 L-80 DWC/C Davis Lynch 2.04 15,467.00 15,464.96 2 7 Liner 7 29.0 L-80 DWC/C Vam 75.86 15,464.96 15,389.10 Float Collar 29.0 L-80 DWC/C Davis Lynch 1.29 15,389.10 15,387.81 3 7 Liner 7 29.0 L-80 DWG/C Vam 37.84 15,387.81 15,349.97 Landing Collar 29.0 L-80 DWC/C Baker 3.34 15,349.97 15,346.63 4 7 Liner 7 29.0 L-80 DWC/C Vam 36.97 15,346.63 15,309.66 161 7 Liner 29# 7 29.0 L-80 DWC/C Vam 6,525.29 15,309.66 8,784.37 43 7 Liner 7 26.0 L-80 DWC/C Vam 1,752.67 8,784.37 7,031.70 LTP 7,031.70 7,002.60 Csg Wt. On Hook: Type Float Collar. Csg Wt. On Slips: Type of Shoe: _ Rotate Csg Yes X No Recip Csg _ Yes X Fluid Description: OEM Liner hanger Info (Make/Model): Baker HRD-E, SCD Liner hanger test pressure: 2750 Centralizer Placement: Every jt F/10836'T11 5309. One on shoe track. CEMENTING REPORT _ No. Him to Run: Casing Crew: No 70 Ft. Min. 2ft 5 WUI UU 9.4 PPG Liner top Packer?: X Yes No Floats Held X Yes No Shoe @ 15467 FC @ 15,389.00 Top of Liner 7002 lush (Spacer) .. Tuned Spacer Density (ppg) 12.5 Volume pumped (BBLs) 20 I Slurry .. Easy Blok Sacks: 785 Yield: 1.32 city (ppg) 14.9 Volume pumped (BBLs) 186 Mixing / Pumping Rate (bpm): 4 Slurry Easy Block Sacks: 255 Yield: 1.19 ;ily (ppg) 15.6 Volume pumped (BBLs) 59.6 Mixing / Pumping Rate (bpm): 4 : Flush (Spacer) Density (ppg) Rate (bpm): Volume: _ acement: CBM Density (ppg) 9.4 Rate (bpm): 4 Volume (actual / calculated): 421 (psi): 2973 Pump used for disp: Rig Bump Plug? X Yes No Bump press ig Rotated? _Yes X No Reciprocated? _Yes X No % Returns during job 100 ant returns to surface? _Yes X No Spacer retums?_Yes X No Vol to Surf: ant In Place At: 15:00 Date: 6/29/2017 Estimated TOC: 8,520 od Used To Determine TOC: CBL --46 7, 5� WA G� Post Job Calculations: �If j� i.r1•i7 Calculated Cmt Vol @ 0% excess: 126.4 Total Volume curt Pumped: 245.6 Cmt returned to surface: 0 Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: www.wellez.net WellEz Information Management LLC ver 102716bf 0 1000 2000 3000 4000 5000 6000 7000 r Y a d v 8000 v m m 9000 10000 11000 12000 13000 14000 15000 16000 M-06RD Days vs Depth FINAL I I —M-06RD Plan —M-06RD Actual TOH for BHA and Super Sliders TOH for N/— ve Super Sliders, BOP Test to insect BHA/Bit 0 5 10 15 20 25 30 35 40 45 50 Days 8/2/2017 11:21 AM 21 7064 Debra OudTech 3800 p Alaska, LLC AK GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 tslen.P AL.A.. t.f.c Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATA `0GGED $ / Y/20t'T DATE: 8/01/2017 M. K. BENDER To: AOGCC Makana Bender 333 W. 71h Ave. Ste#100 RECEIVED Anchorage, AK 99501 AUG 0 1 2011 AOGCC CANRIG FINAL MUDLOG DATA CD i Log PDFs 7/22/2017 12:48 PM File folder 1 Log TIFFS 8/1/201711:46 AM File folder Show Reports 8/1/2017 11:49 AM File folder I Daily Reports 8/1/201711:51 AM File folder I DML Data 8/1/201711:51 AM File folder i Final Well Report 8/1/201711:52 AM File folder i LAS Data 7/22/201712:48 PM File folder HALLIBURTON FINAL WELL DATA CD Definitive Survey 6/30/2017 10:38 A... File folder EMF 8/1/201711:30 AM File folder LAS 6/30/201710:38 A... File folder PDF 6/30/201710:38 A... File folder TIFF 8/1/2017 11:30 AM File folder _Log Viewers 8/1/201711:31 AM File folder CGM 8/1/201711:31 AM Filefolder Prints: ROP DGR EWR-Phase4 CTN ALD MD DGR EWR-Phase 4 CTN ALDTVD SCHLUMBERGER CBL DATA CD DLIS Data 7/13/2017 3:56 PM File folder LAS Data 8/1/2017 12:06 PM File folder I Log 7/13/2017 3:56 PM File folder Prints: CEMENT BOND LOG Please include current contact information if different from above. 28457 28459 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 DATE 7/24/2017 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 V J Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Meredith Guhl, Petroleum Geology Assistant 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTA M-06 RD Transmitted herewith are cuttings from M-06RD WELL BOX SAMPLE INTERVAL M-06RD BOX 1 OF 5 7279' - 9060' BOX 2 OF 5 9060' - 10320' BOX 3 OF 5 10320' - 12330' BOX 4 OF 5 12330'- 13680' BOX 5 OF 5 13680 - 15472' Please include current contact information if different from above. RECEIVED JUL 2 8 2017 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 THE STATE °fALASKA. GOVERNOR BILL WALKER Stan W. Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: McArthur River Field, West Foreland Oil Pool, TBU M-06RD Permit to Drill Number: 217-064 Sundry Number: 317-219 Dear Mr. Golis: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.claska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 22day of June, 2017. RBDMS L v JUL - 6 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED MAY 3 0 2017 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool 121 Re-enter Susp Well ❑ Alter Casing ❑ Other. ESP Completion ❑+ 2. Operator Name: 4. Current Well Class: 5. Permit to DO Number: Hilcorp Alaska, LLC Exploratory ❑ Development Stratigraphic ❑ Service ❑ 217-064 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number. Anchorage, AK 99503 50-733-20585-01-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 228A' Will planned perforations require a spacing exception? Yes ❑ No Trading Bay Unit M-06RD ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO18730 McArthur River Field / West Foreland Oil Pool (proposed) . 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): +15,595 (proposed) 19,917 (proposed) it 5,500 (proposed) ±9,907 (proposed) 3,136 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 470' 28" 470' 470' Surface 1,401' 13-3/8" 1,401' 1,371' 5,020 psi 2,260 psi Intermediate Production ±7,300 (proposed) 9-5/8'. ±7,300 (proposed) ±4,898 (proposed) 6,870 psi 4,760 psi Liner :8,495 (proposed) 7" ±15,595 (proposed) ±9,917 (proposed) 8,160 psi 7.020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A WA N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 121 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/23/2017 OIL Q, WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe a hllcOr .Com Contact Phone: 907) 283-1329 r"7 � 6 Authorized Signature: ✓'�" Date: � 30zo (-11 COMMISSION SE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number Plug Integrity ❑ BOP Test LtG Mechanical Integrity Test ❑ Location Clearance ❑ I (o (21 Other: RBDMS (L- JUL 6 017 Post Initial Injection MIT Yes ❑ No r-1 Spacing Exception Required? Yes No Subsequent Farm Required: 1 y Q � C /��_�•-�'y. WL�C ❑ 0' �" 1 APPROVED BY Approved 6—Z. by: COMMISSIONER THE COMMISSION Date: ?AA / L, 27- i 7 RIGI Form 10-403 Revised 4/2017 oApproJed�pl3licatlon is Laid for 12 months from the date of approval. Submit Form and Attachments in Duplicate n Becnrp Aina,e, cu Well Work Prognosis Well: M-06rd Date: 05/23/2017 Well Name: M-06rd API Number: 50-733-20585-01 Current Status: Sidetracked Producer Leg: B-2 NE Corner Estimated Start Date: June 23, 2017 Rig: Steelhead Rig #51 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 217-064 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) Current Bottom Hole Pressure: 4,100 psi @ 9,827' TVD 0.417 lbs/ft (8.18 ppg) based on offset producers Maximum Expected BHP: 4,100 psi @ 9,827' TVD 0.417lbs/ft (8.18 ppg) based on offset producers Maximum Potential Surface Pressure: 3,136 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary M-06rd is a West Foreland only producer that will be completed with an ESP. This new well was side tracked from the current M-06 which is a depleted gas w This workover will perforate and run the completion string in the new well. Last Casine Test: Casing and liner tested to 2,500 psi under PTD 217-064 R..' cap- ws Procedure: 1. 2. 3. ***Take over operations from the Drilling Sidetrack Program *** aA— ass) 'b4 - 4W' = Y3. 3e Test BOP s every 14 days continued from last test date from PTD 217-064. Test to 250psi low/3,500psi high/ 2,500 psi annular. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). Workover fluids will be 6% KCL. BOP'S will be closed as needed to circulate the well. 4. Rig up E -Line and run gamma/ccl/cbl. POOH. 6 <w. e y C_ ti C. 5. PU TCP guns, RIH and perforate per program. 6. After detonation, circulate out any perfgas, confirm well is static, POOH. 7. PU and run ESP completion. 16 46gcc- t;t- o_„�-. A • A high set pac packervent valve, and SSSV will be ran if well indicates ability to flow to surface. 8. If applicable - Set and test packer to 1,500 psig charting for 30 minutes. 9. Set BPV. NU tree, test same. 10. Turn well over to production 11. Schedule SVS testing with AOGCC as per regulations. 12. If applicable (no packer and SSSV installed in step 7) - Schedule no -flow with AOGCC as per regulations. 1�1_ Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Proposed 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form K Hil.rp Alm►., t,t.c RKB to TBG Head — 78' 13 3/8" 9-50 Stage Collar @ 5,806' PROPOSED Steelhead Platform Well: M-06RD2 Last Completed: FUTURE PTD: XXX -XXX API: 50 -733 -20585 -XX EXISTING CASING DETAIL Size wt Grade Conn ID Top atm 28" Conductor 27" Surf 470' 13-3/8" 68 L-80 BTC 12.415" Surf 1,401' 9-5/8" 47 L-80 BTC -M 8.681" Surf ±7,300' (KOP) TOC @ 10,0w PBTD: 15,500' TD: 15,595' CEMENT DETAIL No ,-,TOC@6,100' TOC Depth Volume Item (MD) (TVD) 4 ±10,000' ±7,290' 193 bbls 15.3 ppg Class G cement w/ Y2 bbl Fibrous LCM k 4 No Depth (MD) Depth (TVD) ID Item SDDliner 1 ±7,100' ±4,781' 6.059" SDD Baker Liner Hanger hanger 2 ±7,300' ±4,892' - KOP ±7,100 3 ±7,100'- 15,595' ±4,922' 6.059" 7" 29k L-80 DWC/C 45/g' ,�1? 2 Window ±7,300 TOC @ 10,0w PBTD: 15,500' TD: 15,595' Updated By: MMM 04/19/17 CEMENT DETAIL No TOC Depth TOC Depth Volume Item (MD) (TVD) 4 ±10,000' ±7,290' 193 bbls 15.3 ppg Class G cement w/ Y2 bbl Fibrous LCM Updated By: MMM 04/19/17 0 cors Alaska. LL( ROtOTBG Head -78' PBTD: ±15,300' TD: 15,472' Max Hole Arrgle 85.99° @±14,013' Steelhead Platform Well: M-06rd PTD: 217-064 PROPOSED API: 50-733-20555-01 Last Completed: Future CASING DETAIL Size Wt Grade Conn ID Top Btm 28" OD Conductor Btm (MD) 27" Surf 470' 13-3/8" 68 L-80 BTC 12.415" Surf 1,401' 9-5/S" 47 L-80 BTC -M 8.681" Surf 7,279'(TOW) 7" 29 L-80 DWC/C 6.059" ±7,100' ±15,470' TUBING DETAIL 2-7/8" 6.4 L-80 8 round EUE 1 2.441" Surf ±12,930' Updated By: DEM 06/26/17 JEWELRY DETAIL No Depth MD Depth TVD ID OD Item Btm (MD) 78' 78' Feet SPF Tubing Hanger Status ±450' ±450' 2.313" 4.91" SSSV- Haliburton T5524TRSV NE ±136' ±480' ±480' Proposed 8.500" ESP Dual Packer D&L Oil Tools w/ WFT vent valve ±13,455' ±510' ±510' 2.313" 6 %-nipple Proposed WF -2 ±13,596' N/A 4.000" Discharge, Bolt -On ±32' 6 Future N/A 4.000" Pump- 333 stage Summit SF2700AR 4 ±9,728' ±9,732' N/A 4.000" Intake Proposed WF -2 ±13,754' N/A 4.000" Seals- Tandem Summit 400 series BPBSL ±269' 6 Future N/A 4.560" Motors -Summit 240HP/2975V/58A ±14,159' ±12,9;0' ±9,619' N/A 4.560" Gauge (Zenith)/Centralizer /Anode Proposed WF -2 ±14,223' ±14,259' ±9,777' ±9,781' ••Note -Straight Hole Pump Tangent Section 12,712' to 12,932' Updated By: DEM 06/26/17 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Feet SPF Date Status WF -1 ±12,972' ±13,108' ±9,630' ±9,662' ±136' 6 Future Proposed WF -1 ±13,127' ±13,455' ±9,666' ±9,706' ±328' 6 Future Proposed WF -2 ±13,596' ±13,628' ±9,722' ±9,726' ±32' 6 Future Proposed WF -2 ±13,650' ±13,685' ±9,728' ±9,732' ±35' 6 Future Proposed WF -2 ±13,754' ±14,023' ±9,738' ±9,761' ±269' 6 Future Proposed WF -2 ±14,056' ±14,159' ±9,763' ±9,771' ±103' 6 Future Proposed WF -2 ±14,223' ±14,259' ±9,777' ±9,781' ±46' 6 Future Proposed WF -2 ±14,313' ±14 ±9385' ±9,790' ±49' 6 Future Proposed WF -2 ±14,369' ±14- +9,790' ±9,794' ±41' 6 Future Proposed WF -2 ±14,461' ±14: t 9,815' ±188' 6 Future Proposed WF -2 ±14,770' ±14.b.. -9,827' ±30' 6E!22 Proposed WF -2 ±14,812' ±15,160' x9,829' ±9,868' ±348' 6 Future Proposed Updated By: DEM 06/26/17 H Hilcurp Alaekn, LLC RKB to TBG Head -78' 28' 1}3/8' rat TOC @974 Stage Collar @5,819 .,TCC@6,100' dJ wre"r ±7,100 )-,M±7,3W 35/8" a vs -i ".j M2 M3 r' PBTD: ±15,504 TD: ±15,595' PROPOSED Steelhead Platform Well: M-06rd PTD: 217-064 API: 50-733-20585-01 Last Completed: Future CASING DETAIL Size Wt Grade Conn ID Top Btm 28" O Item Conductor 78' 27" Surf 470' 13-3/8" 68 L-80 BTC 12.415" Surf 1,401' 9-5/8" 47 L-80 BTC -M 8.681" Surf (TOW) 7" 29 L-80 DWC/C 6.059" ±7,100' ±15,595' Updated By: JUL 05/23/17 PERFORATION DATA JEWEL DETAIL No Depth MD Depth D TVD O Item Btm (TVD) Feet SPF 78' 78' WF -1 Tubing Hanger 1 ±450' ±450' 2.313N Contingent -SSSV 2 ±480' ±484 Contingent -ESP Dual Packer w/WFT vent valve 3 ±510' ±510' Contingent - X-nile ±9.882• Future Pro sed Discharge, Bolt -On Pum Intake 4 Seals otor3 ±13,0 ±9,61 N/A ntralizer Anode Updated By: JUL 05/23/17 PERFORATION DATA ne Top (MD) Btm Top (MD) (TVD) Btm (TVD) Feet SPF Date Status WF -1 ±13,084' ±9,638'F2 re oposed WF -2 ±13,959' ±9,744' Future P used WF -3 ±15,269' ±9.882• Future Pro sed Updated By: JUL 05/23/17 H flilrorp Akwdi IAA: M�28a 133/5/er2 7/8 Va1, Swab, 41/165M, HN Valor, Master' 411165M, HW( Multibowl syvem, Vetto M62Q, 13 5/85M Flanged top x 30 %3M W-3 bottom, Spirting hind, Vetoo MB -246, 20 %3M NT -3 top a E8" BW Nttom, w/ 1-3" LGO and 6" AN516W outlets Steelhead Platform M-06RD Proposed 05/26/2017 Tubing xarger, Vetco 1011 -N2 - EV EN -CCL 135/8x 6%IBT susp x 6.969 MCA lift w/ C" ryce H An' 4-11.1 line ps6, DD material Tree op, Bower 41/165M FE x 7" -SSA Bowen union top 31/8 E 4im Steelhe 5/8 5 Platform 13 13 5/8 SM BOP (Oil Leg) 01/30/2017 Ilil.� p AI.+A.. [AA: LO ry r' O LL F- n Q W 2 J LLJ W F- C/) H uilro I, AL„ka. 111 Attachment #1 Hilcorp Alaska LLC BOP Test Procedure: Steel head Rig # 51 BOP Test Procedure Attachment #1 Steelhead Rig # 51 WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Production Vessel that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Circulate down tubing taking returns to production off of the annulus and sweep gas and oil to production until returns are clean. 4) Confirm that well is static Monitoring for any pressure Build Up Or if Well Is Still On A Strong Vacuum ( I do not think that We Often Shoot Fluid Levels) Initial Test (i.e. Tubing Hander is in the Wellhead) If BPV profile is good 1) Set BPV, ND Tree 2) Clean / Inspect /And Confirm By Screwing Into Lift Threads (Counting Turns) Remove Sub —Check all Lock Down Pins to Ensure they Will Back Out Far Enough To Clear Hanger— Plug Penetrations Through Hanger — Put a Sealing Cap On Penetrator — Leave BPV Installed & If Needed Install Adaptor to Test Joint, Might Be Using a Left Hand Blank Ported Sub or a Combo Tool Of Various Types NU BOP. 3) MU landing joint With On/Off Tool Adaptor. 4) Set slips, mark same. Test per standard Steelhead Rig # 51 Test Procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, establish static fluid level. 2) Once the fluid level is established to be static, notify Hilcorp Anchorage Operations Engineer. 3) Proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a BPV, or prepare lift -threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) MU Left Hand Blanking Plug d) Plug penetrations in hanger. For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 4) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC - guy.schwartz@alaska.gov ) and Mr. n xahr.p Ab.ks, u.c Steelhead Rig # 51 BOP Test Procedure Attachment #1 Jim Regg (AOGCC-jim.regg@alaska.gov ) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 5) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 6) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Note: BOPE high test pressures will be determined upon Approved Sundry. Test joint sizes will be determined upon well work. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Pull Wear Bushing, Makeup Test Plug and Test Joint — Land Same Measuring in the hole getting a Good Mark when Landed . a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after Isolation Plug is Set) 1) Make up Test Joint as per diagram. Insure all connections above test plug are torque. 2) Pull Wear Bushing and install Test Plug 3) Make up Side -Entry Sub, (2) TIW valves and IBOP to top of Test Jt. 4) Make up Test Hose #1 to Side -Entry Sub and Test Hose #2 to Top Drive Test Sub. 5) Verify Annulus valve is open and monitored. 6) Fill BOP and Choke Manifold with water. Purge air from system through Choke manifold top valve and IBOP. 0 Hihrnq Alaska, LIX Steelhead Rig # 51 BOP Test Procedure Attachment #1 7) Close Annular and set closing pressure to 800 psi. (pressure can be increased as necessary to seal element) Perform full body BOP test to check integrity of system. Note: When testing, pressure up with pump to desired pressure, close MPI and/or MP2 to trap pressure and read same with chart recorder. 8) Referencing the attached schematics test BOP as per Permit and Regulations as follows. a) Close W1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Open W1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves, to 250 psi low and 3,000 psi high, for 5 minutes each, as follows: (Valve numbers are in reference to Flow Diagram) d) Test #1- Annular, IBOP, Upper TD Valve, Kill Line Demco, C1, C2, C3, C12, C13, C14. e) Test #2 —Test VBRs, Top TIW, Lower TD valve, HCR2, C4, C5, C6. f) Test #3 —Test VBRs, W2, C7, C8, C9 g) Test #4. —Test Lower Pipe Rams, Bottom TIW. h) STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (I.E. Report might read "10 bottles at 2,150 psi") 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre -charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto', not "Manual" so the pumps will kick-off automatically. j) Back out Test joint and pull to rig floor. Connect test hose to C13. Pressure up on Manual and Hydraulic Chokes to 1,000 psi. Function Chokes to bleed pressure and verify operation. k) Test #5. —Test Blinds and C10, C11. 1) Make up 2nd Test Joint if running two string sizes m) RIH with 2nd Test Joint and test plug. Make up Side -Entry Sub, (1) TIW valve and IBOP to Test Joint. Connect #1 Test Hose to Side -Entry Sub and #2 Test Hose to suspended TIW w/test sub. U am,,q 11L,ka. rrC Steelhead Rig # 51 BOP Test Procedure Attachment #1 Purge air from system. (always verify lengths needed when compared to RKB and add pups if necessary) n) Test #6 - Test Annular, IBOP, suspended TIW and HCR1. o) Test #7- Test VBRs,UpperTIWand Manual Choke. p) Rig down test equipment. Blow down lines. Close Annulus valve. Pull test plug. Install Wear Bushing. Rig down, or stand back Test Stand. q) Back out testjoint & pull, close blinds, close valves C7, C8, C9, open HCR1, and W1 r) Open all rams and annular and close HCR2 to place BOPE back into operating position for well work. s) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well M-06RD (PTD 217-064) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date THE STATE 01ALASKA GOVERNOR BILL WALKER Monty Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Re: McArthur River Field, West Foreland and Hemlock Oil Pools, TBU M-06RD Hilcorp Alaska, LLC Permit to Drill Number: 217-064 Surface Location: 1035' FNL, 592' FWL, SEC. 33, T9N, R13W, SM, AK Bottomhole Location: 1062' FSL, 1121' FWL, SEC. 28, T9N, R13W, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. DATED this e4ay of May, 2017. Sincerely, Cathy P. Foerster Chair STATE OF ALASKA AL1 .A OIL AND GAS CONSERVATION COMM PERMIT TO DRILL 20 AAC 25.005 DN APR 2 0 2017 1a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas LJ Service- WAG Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Oil El, Service - Winj ❑ Single Zone Coalbed Gas ❑ Gas Hydrates ❑ Redrill Q - Reentry ❑ Exploratory - Oil ❑ Development - Gas �y'1� ❑ Service - Supply ❑ Multiple Zone WIr" Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244. TBU M-06RD 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 15,595' . TVD: 9,917' 1 McArthur River Field West Foreland Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 1035' FNL, 592' FWL, Sec 33, T9N, R13W, SM, AK ` ADLO18730 • - A Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 787' FNL, 2143' FWL, Sec 28, T9N, R1 3W, SM, AK N/A 6/1/2017 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1062' FSL, 1121' FWL, Sec 28, T9N, R13W, SM, AK 3840 11,056' to nearest unit boundary 4b. Location of Well (Slate Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 160' • 15. Distance to Nearest Well Open Surface: x-214232 y- 2499431 Zone -4 GL Elevation above MSL (ft): N/A to Same Pool: 250'G-32 16. Deviated wells: Kickoff depth: 7,300 feet t 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 84 degrees Downhole: 4744 . Surface: 2501 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 8-1/2" 7" 29# L-80 DWC/C 8,495' 7,100' 4,781' 15,595' 9,916' 809 sx 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 12,502' 8,770' 9,412, 11,666', 12,317' 9,099' 5,950' 9,099' Casing Length Size Cement Volume MD TVD Conductor/Structural 470' 28" Driven 470' 470' Surface 1,401' 13-3/8" 525 bbls 1,401' 1,371' Intermediate Production 7,610' 9-5/8" 573 bbls 7,610' 5,080' Liner 5,148' 7" 1 240 bbls 12,494' 8,762' Perforation Depth MD (ft): 8,932'- 9,351' Perforation Depth TVD (ft): 5,857' - 6,087' 20. Attachments: Property Plat Q BOP Sketch Q Drilling Program ❑✓ Time v. Depth Plot ❑✓ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements ❑✓ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Monty Myers Email mirrivers(a)[hilcorto.com Printed Name Monty Myers Title Drilling Engineer Signature _ Phone 777-8431 Date Y. ZD • 70/7 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: I - oip 50- - —"p -pb Date: requirements. Conditions of approval : If box is chec/kk�eed, well may not used to explore for, test, or produce coalbed urethan , gas hydrates, or gas contained in shales: Other: 7� 3Soo Y0Sr_ /JO/Q�.� �- Samples req'd: Yes No lei Mud log req'd: Yes❑ NOV 2 HzS measures: Yes No ❑- Directional svy req'd: Yes V No ❑l r �Jc ✓A •! Spacing exception req'd: Yes❑ NoInclination-only svY req'd: Yes❑ NoRI /r r 2-0 A Z s , a �A�G�� y��r'� Post initial injection MIT req'd: Yes ❑ No ❑ iF Suvr�Ny�t y`L<tc-f.i�t.Jr4r,�.e.r'� L / �L �c �c+... l:n nr�Ct-T•r+.... APPROVED BY Approved b r �^ COMMISSIONER THE COMMISSION Date: J ;�a yizyl�7 t y� (4Art p � i 1Q12L "^ Z � - (� If Submit Form and Form 10-401 (Revised 1112015) UT% t months from t date of approval (20 AAC 25.005(8)) Attachments in Duplicate U Hilcorp fte c—P-Y 4/20/2017 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: M-06RD Dear Commissioner, Monty Myers Drilling Engineer Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyem@hilcorp.com RECEIVED APR 2 0 2011 ACGCC Attached is the application for permit to drill M-06RD. M-06RD is an oil production well planned to be re -drilled in a North-easterly direction from M-06 utilizing the existing casing program down to 7300' MD / 4892' TVD. At 7300' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets and ultimately penetrating the West Foreland 1 and 2. A 8495' x 8-1/2" open hole section is planned. A 7" 29# L-80 DWC/C prod liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 2-7/8" ESP completion. Drilling operations are expected to commence approximately June 1St, 2017. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, V Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 Hilcorp Alaska, LLC M-06RD Drilling Program McArthur River ApRrad by: M t M--" Revision 0 April 18, 2017 K nilrarp Alaska, UA: M-06RD Drilling Procedure Rev 0 Contents 1.0 Well Summary.................................................................................................................................2 2.0 Management of Change Information............................................................................................3 3.0 Tubular Program............................................................................................................................4 4.0 Drill Pipe Information.....................................................................................................................4 5.0 Internal Reporting Requirements..................................................................................................5 6.0 Planned Wellbore Schematic..........................................................................................................6 7.0 Drilling Summary............................................................................................................................7 8.0 Mandatory Regulatory Compliance / Notifications.....................................................................8 9.0 R/U and Preparatory Work..........................................................................................................10 FIT Procedure................................................................................................................................36 10.0 BOP N/U and Test.........................................................................................................................11 Choke Manifold Schematic...........................................................................................................37 11.0 Mud Program and Density Selection Criteria............................................................................12 Offset MW vs. Depth TVD...........................................................................................................38 12.0 Whipstock Running Procedure....................................................................................................13 Casing Design Information...........................................................................................................39 13.0 Whipstock Setting Procedure.......................................................................................................16 14.0 Drill 8-1/2" Hole Section...............................................................................................................19 15.0 Run 7" Production Liner..............................................................................................................22 16.0 Cement 7" Production Liner........................................................................................................25 17.0 Wellbore Clean Up & Displacement............................................................................................29 18.0 Run Completion Assembly...........................................................................................................30 19.0 RD...................................................................................................................................................30 20.0 BOP Schematic..............................................................................................................................31 21.0 Wellhead Schematic......................................................................................................................32 22.0 Days vs Depth.................................................................................................................................33 23.0 Geo-Prog.........................................................................................................................................34 24.0 Anticipated Drilling Hazards.......................................................................................................35 25.0 FIT Procedure................................................................................................................................36 26.0 Choke Manifold Schematic...........................................................................................................37 27.0 Offset MW vs. Depth TVD...........................................................................................................38 28.0 Casing Design Information...........................................................................................................39 29.0 8-1/2" Hole Section MASP............................................................................................................40 30.0 Plot (NAD 27) (Governmental Sections)......................................................................................41 31.0 Slot Diagram (As Built) (NAD 27)...............................................................................................42 32.0 Directional Program(wp04).........................................................................................................44 B nihMmp ANA., LIA: 1.0 M-06RD Drilling Procedure Rev 0 Well Summary Well M-06RD Pad & Old Well Designation Sidetrack of existing well M-06 (PTD#209-004 Planned Completion Type 7" 29# L-80 Liner, 2-7/8" Tubing w/ ESP Target Reservoir(s) West Foreland Planned Well TD, MD / TVD 15595' MD / 9917' TVD PBTD, MD / TVD 15500' MD / 9907' TVD Surface Location Governmental 1035' FNL, 592' FWL, Sec 33, T9N, R13W, SM, AK Surface Location AD 27 X=214232.8, Y=2499431.83 Surface Location (NAD 83) Top of Productive Horizon (Governmental) 787' FNL, 2143' FWL, Sec 28, T9N, R13 W, SM, AK TPH Location (NAD 27) X=215885.18, Y=2504953.43 TPH Location (NAD 83) BHL (Governmental) 1062' FSL, 1121' FWL, Sec 28, T9N, ROW, SM, AK BHL (NAD 27) X=214785.68, Y=2501548.2 BHL AD 83 AFE Number 1711197D AFE Drilling Days AFE Drilling Amount $5.7 MM Work String 5" 19.5# S-135 NC -50 Rental string from Weatherford) RKB 160' Water Depth 187' BOP Equipment 13-5/8" 5M Hydril "GK" Annular BOP 13-5/8" 5M Cameron Type U Double Ram 13-5/8" 5M Cameron Type U Single Ram Page 2 Revision 0 April, 2017 H I Iilvo,p :kla.ka. LLC 2.0 Management of Change Information M-06RD Drilling Procedure Rev 0 11 Hileorp Alaska, LLC xilcorp Changes to Approved Permit to Drill Date: April 18, 2017 Subject: Changes to Approved Permit to Drill for M-06RD File #: M-06RD Drilling Program Any modifications to M-06RD Drilling Program will be documented and approved below. Changes to an approved APD will be communicated and approved by the AOGCC prior to continuing forward with work. Approval: Drilling Manager Date Prepared: Monty M Myers 04.18.2017 Drilling Engineer Date Page 3 Revision 0 April, 2017 H I likoq, ANA., 1.1.1: 3.0 Tubular Program M-06RD Drilling Procedure Rev 0 Section OD in Wt #/f# Co" ., ra I no Top Bottom 8-1/2" 7" 29 7.656 6.184 6.059 L-80 DWC/C 7100 15595 4.0 Drill Pipe Information le OD Chou (in) ID (in) TJ ID (in) TJ Wt Grade OD (#/ft) (in Conn]'UVWWOse (psi) (psi) Tension (k -lbs) 8-1/2" 5" 4.276 3-1/4 6-5/8 19.5 S-135 NC -50 17,105 15,638 560 All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 April, 2017 5.0 Internal Reporting Requirements M-06RD Drilling Procedure Rev 0 5.1 Fill out daily drilling report and cost report on Wellez. i. Report covers operations from 6am to 6am ii. Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area — this will not save the data entered, and will navigate to another data entry tab. iii. Ensure time entry adds up to 24 hours total. iv. Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates v. Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers .hilcorp com and cdinger@hilcorp.com 5.3 5am Weekend Update vi. Submit a short operations update each weekend and holiday to whoever is assigned weekend or vacation duty. Details will be sent before each weekend or holiday. vii. Copy pmazzolini@hilcorp.com, and mmyers@hilcoM.com hilcoM.com 5.4 EHS Incident Reporting viii. Notify EHS field coordinator. 1. This could be one of (3) individuals as they rotate around. Know who your EHS Feld coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. Mark Tornai: O: (907) 283-1372 C: (907) 748-3299 b. Leonard Dickerson: O: (907) 777-8317 C: (907) 252-7855 2. Spills: Keegan F: 0:907-777-8477 C:907-350-9439 ix. Notify Drlg Manager 1. Paul Mazzolini: 0:907-777-8369 C: 907-317-1275 x. Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally xi. Send final "As -Run" Casing tally to mmyers@hilcorp.com and cdinger@hilcorp.com 5.6 Casing and Cut report xii. Send casing and cement report for each string of casing to mmyers@hileorp.com and cdinger@hilcorp.com Page 5 Revision 0 April, 2017 H Ililcorp Alu.ku, LLA: M-06RD Drilling Procedure Rev 0 6.0 Planned Wellbore Schematic Wt Grade Conn ID StePlatform Btm M 0 Welt: ll; M�6RD2D2 PROPOSED Last ete d. FUTURE Surf PTD: XXX -XXX IBI,a,n ]I.•An, Li API: 50 -733 -20585 -XX RKBt0TBGhBad-78 surf 01 2-3/Er us rn.Ta ew 93/8 sage Cotr@ SXT J,300 localojac 3 Ll PWD:15,500' TD: 15,595' Page 6 EXISTING CASING DETAIL Size Wt Grade Conn ID Top Btm 28" Conductor 27" Surf 470' 13-3/8" 68 680 BTC 1].415' surf 1,401' 9-5/8. 47 L-90 BTC -M 8.681" Sud 17,300' KOP 0 No Depth (MD) Depth (ND) IO Item 1 ±7,100' ±4,781' 6.659" SDD Baker Liner Hanger 2 ±7,300' ±4,892' - KOP 3 17,100' —15,595' ±4,922' 6.059" 7" 29# L-80 DWC/C Revision 0 April, 2017 CEMENT DETAIL No TO(CNDDepth TOICTDO;th Volume Item 4 ±10,000' ±7,290' 193 bbls 15.3 ppg Class G cement w/ !x bbl Fibrous LCM Revision 0 April, 2017 U nikoq M.A.. LIA: M-06RD Drilling Procedure Rev 0 7.0 Drilling Summary( f A �3 r7- 017`( \ . _DL i M-06RD is an oil production well planned to be re -drilled in a North-easterly-di—rection from M-06 utilizing the existing casing program down to 7300' MD / 4892' TVD. At 7300' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets and ultimately penetrating the West Foreland 1 and 2. A 8495' x 8-1/2" open hole section is planned. A 7" 29# L-80 DWC/C prod liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 2-7/8" ESP completion. Drilling operations are expected to commence approximately June 1" 2017. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal / beneficial reuse depending on test results. / A separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack and for running the completion assembly 317-'37Y General sequence of operations pertaining to this approved drilling procedure: SO, d pp' 1. Steelhead Rig 511 will be over slot 6 Leg B-2 (M-06) to de -complete and P&A well under separate sundry. _3 I?- 01y 2. DP should be stood back in derrick 3. PU whipstock, and mills and TIH to CIBP r 4. Orient whipstock and set at 65 deg left of highside. 5. Mill 8-1/2" window and 35' of new formation at 7300'. 6. POOH and LD mills. PU directional BHA and TIH to window. 7. Swap well to 8.9 ppg oil based drilling mud 8. Perform FIT to 12.5 ppg EMW P 9. Drill 8-1/2" production hole from 7335' to 15595' MD, performing short trips as needed 10. Perform short trip and condition mud. POOH 11. LD Directional Tools. RIH w 7" liner. Set liner and cement. Circ wellbore clean. 12. POOH, laying down DP and liner running tools, 13. PU 7" casing scraper assembly and TIH to landing collar. 14. Circ casing clean. POOH laying down DP. 15. Run 2-7/8" completion. (Covered under separate sundry) 16. Land hanger and test. 17. ND BOPE, NU tree and test void Page 7 Revision 0 April, 2017 K llikuq M.A., IAX M-06RD Drilling Procedure Rev 0 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2) week intervals during Ke drilling of M-06RD. Ensure to provide AOGCC 48 firs notice prior to testing BOPS. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must testALL BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system" • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. Variance Requests: o The calculated MASP for this wellbore when completely evacuated to gas is 3272 psi. However, for Cook Inlet Operations, we assume that the well can never flow 100% gas, due to the water in the reservoir. We reduce this MASP calculation to 2501 psi which assumes that only 2/3 of the wellbore is evacuated to gas and 1/3 to 9.2 ppg reservoir fluid. Alf, /&+5 r cv- (- YP; 0V - C Page 8 Revision 0 April, 2017 K I liko,p AI.A., 1.1.1: M-06RD Drilling Procedure Rev 0 Hole Section Equipment Test Pressure(psi) • 13-5/8" Hydril GK 5M annular • 13-5/8" 5M Cameron U Double gate Initial Test: 250/3500 0 2-7/8" X 5" VBR in upr cavity (Annular 2500 psi) o Blind ram in btm cavity 8-1/2" Mud cross • 13-5/8" 5M Cameron U single gate Subsequent Tests: • 3-1/16" 5M Choke Manifold 250/3500 • Standpipe, floor valves, etc (Annular 2500 psi) Note: 7' casing ram in lower ram for 8-1/2" hole section. • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Secondary back- up is an air pump, and tertiary emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event (BOPs utilized to shut in the well to control influx of formation fluids). • 48 hours notice prior to spud. • 48 hours notice prior to testing BOPS. • 48 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Additional requirements may be stipulated on APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: iim.regg@alaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov alaska.gov Test/Inspection notification standardization format: hup:Hdoa.alaska.pov/ogc/forms/TestWitnessNotifhtml Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 Revision 0 April, 2017 H I lilcuq� Aleake, LLC 9.0 R/U and Preparatory Work M-06RD Drilling Procedure Rev 0 9.1 Separate sundries will be submitted that will include the following: • Pull tubing • P&A lower perfs with a cement plug • Set CIBP 9.2 Mix oil based mud for 8-1/2" hole section. Page 10 Revision 0 April, 2017 10.0 BOP N/U and Test M-06RD Drilling Procedure Rev 0 10.1 * BOPE was NU and tested on prior decompletion sundry. We will test BOPE on 7 day cycle until the window is milled, at that point we will switch to the 14 day test cycle. Continue on to step 11. 10.2 N/U 13-5/8" x 5M BOP as follows (top down): • 13-5/8" x 5M Shaffer annular BOP. • 13-5/8" Shaffer Type "SL" Double ram. (2-7/8" X 5" VBR in top cavity, blind ram in bum cavity) • 13-5/8" mud cross • 13-5/8" Shaffer Type "SL" single ram. (2-7/8" X 5" VBR) • N/U pitcher nipple, install flowline. • Install (2) manual valves on kill side of mud cross. Manual valve used as inside or "master valve". • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 10.3 Run BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3500 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Ensure to leave "A" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. Confirm the correct valves are opened!!! • Test VBRs on 5" test joint. • Ensure gas monitors are calibrated and tested in conjunction w/ BOPE. 10.4 R/D BOP test assy. 10.5 Continue mixing mud for 8-1/2" hole section. 10.6 Set wearbushing in wellhead. Ensure ID of wearbushing > 7". Page 11 Revision 0 April, 2017 H I lihnq. AI.A., LIX 11.0 Mud Program and Density Selection Criteria 11.1 8-1/2" Production hole mud program summary: M-06RD Drilling Procedure Rev 0 Primary weighting material to be used for the hole section will be barite to minimize solids. We will have enough barite on location to weight up the active system 1ppg above highest anticipated MW in the event of a well control situation. Canrig PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 80/20 Enviromul MOBM Properties: IDID d ei ght Viscosity PV YP HTHP WPS ES EZ MILL NT (ppWb GELTONE V 6-10 ppb Lime 7 ppb DURATONE HT 2 ppb 7,300-15,595' 1 1118.9- 9. 50-801 25-35 I 15-22 <5 I 250-270K >580 System Formulation: 80/20 Enviromul MOBM Product Concentration LVT _ 0.662 bbl Water .172 bbl INVERMUL NT 4 ppb EZ MILL NT 4 ppb GELTONE V 6-10 ppb Lime 7 ppb DURATONE HT 2 ppb Calcium Chloride 21 ppb BAROID 41 9.2 ppg (as needed) BARACARB 5 3-5 ppb BARABLOK 2 ppb BAROTROLPLUS 4 ppb 11.2 Program mud weights are generated by reviewing data from producing & shut in offset wells, estimated BHP's from formations capable of producing fluids or gas and formations which could require mud weights for hole stabilization. 11.3 A guiding philosophy will be that it is less risky to weight up a lower weight mud than be overbalanced and have the challenge to mitigate lost circulation while drilling ahead. Page 12 Revision 0 April, 2017 H uak�...p AI.A., u.c 12.0 Whipstock Running Procedure M-06RD Drilling Procedure Rev 0 Section 12.1 through 12.5 is covered under decompletion sundry, drilling proceed to 12.6 12.1 M/U window milling assembly and TIH w/ 4-1/2" DP out of derrick. • Use an 8-1/2" taper mill and an 8-1/2" string mill above to ensure whipstock assy will pass freely. • Ensure BHA components have been inspected previously. • Caliper and drift all BHA components before running them in the hole. • Drift DP prior to RIH. • Lightly wash and ream any tight spots noted. 12.2 TIH to CIBP (7300' MD). Note that this was a wireline measurement so actual depth tagged may vary slightly. Keep up with the # of joints picked up so we know where we are. 12.3 Pressure test casing to 2500 psi / 30 min. Chart record casing test & keep track of the amount of fluid pumped. Stage up to 2500 psi in 500 psi increments. 12.4 CBU & circ at least (1) hi -vis sweep to remove any debris created by the clean out run. Anything left in the wellbore could affect the setting of the Whipstock. 12.5 TOH. 12.6 Make up mills on a joint of HWDP. 12.7 RIH & set in slips. 12.8 Make up float sub, install float. 12.9 Leave assembly hanging in the elevators, and stand back on floor. 12.10 Bring Whipstock to rig floor on the pipe skate. Do not slam into bottom of Whipstock with pipe skate. 12.11 Pickup Whipstock per Baker rep using the Baker Whipstock handling system using air hoist. Allow assy to hang while Baker Rep inspects and removes shear screws as needed and any safety screws. Note: Anchor should be pinned with 6 shear screws initially. Shear screws are rated for 6,630 lbs each. REMOVE 3 screws for a set down shear of 6,630 x 3 =19,890 lbs. Note: Attach mills to Whipstock with (1) 35k mill shear bolt. 12.12 If needed, open BOP Blinds. Page 13 Revision 0 April, 2017 H nik-.,q M.A.. LIA: M-06RD Drilling Procedure Rev 0 12.13 Run the Whipstock in the hole, install safety clamp as per Baker Rep, and install hole cover wrap. 12.14 Release pick up system at this point, Make up mills. 12.15 With the top drive, pick the assembly and position the starting mill to align with the hole in the slide. The Baker Rep will instruct the driller when the slot is lined up, the shear bolt then can be made up by the Baker Rep. 12.16 The assembly can now be picked up to ensure that the shear bolt is tight. 12.17 Remove the handling system. 12.18 Slowly run in the hole as per Baker Rep. Run extremely slow through the BOP & wear bushing. 12.19 Run in bole at 1 '/2 to 2 minutes per stand. 12.20 Fill every 30 stands or as needed, do not rotate or work the string unnecessarily. 12.21 Call for Baker Rep. 15 — 10 stands before getting to bottom. 12.22 Orient at least 30'-45' above the CIBP. Page 14 Revision 0 April, 2017 n llilanp ANA, LLA: Window Master G2 Whipstock With Torque Master Bottom Trip Anchor 9.625 53.5# Non Special Drift Casing 6.375 —i 4o.s 8.250 —� f- 8.500 3.41 p f 1.9 M-06RD Drilling Procedure Rev 0 CAk2 BAKER HUGHES 1.13 Whipstock OD: 8.000 Length: 18.54 Face Angle: 1.9 Face Length: 17.08 Retrieval BTA OD: 8.357 Length: 3.41 Overall length Length: I44' WELL INFORMATION CUSTOMER FIELD 8.600 LEASE WELL NO. SHEAR BOLT 25,000 35,000 45,000 55,000 65,000 75,000 Page 15 Revision 0 April, 2017 Baker Oil Tools Upper Watermelon Mill OD: 8.500 F6 2-5 Length: 6.25 Flex Joint OD: 6.375 ' Length: 9.00 9.00 Lower Watermelon Mill OD: 8.375 Length: 5.66 Window Mill OD: 18.500 5.66 Length: 1 1.13 1.13 Whipstock OD: 8.000 Length: 18.54 Face Angle: 1.9 Face Length: 17.08 Retrieval BTA OD: 8.357 Length: 3.41 Overall length Length: I44' WELL INFORMATION CUSTOMER FIELD 8.600 LEASE WELL NO. SHEAR BOLT 25,000 35,000 45,000 55,000 65,000 75,000 Page 15 Revision 0 April, 2017 K 181 uq, M.A., LI.I: 13.0 Whipstock Setting Procedure M-06RD Drilling Procedure Rev 0 13.1 With the bottom of the Whipstock 30 — 45' above the CIBP, measure and record P/U and S/O weights. We will orient Whipstock face using highside MWD. 13.2 Orient Whipstock to desired direction by turning DP in'/4 round increments. P/U and S/O on DP to work all torque out (Being careful not to set BTA). Whipstock Orientation Diagram: 65 L HS 45 LHS Desired orientation of the Whipstock face is 65 degrees left of high side. Hole Angle at window interval (7300' MD) is 54 deg. The wellbore trajectory is planned to kick off at low and at 14 degrees azimuth. 13.3 Once Whipstock is in desired orientation, slack off and tag CIBP to set Bottom Trip Anchor. 13.4 Set down 12-15K on anchor to trip, P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by slacking off weight on the Whipstock shear bolt. (25k shear value). �G 13.5 P/U 5-10' above top of Whipstock. 13.6 Displace to 8.9 ppg 80/20 Enviromul MOBM. 13.7 Record P/U, S/O weights, and free rotation. Slack off to top of whipstock and with light weight and low torque. Mill window. Utilize 4 ditch magnets on the surface to catch metal cuttings. 13.8 Install catch trays in shaker underflow chute to help catch iron. _ 13.9 Keep iron in separate bbls. Record weight of iron recovered on ditch magnets. Page 16 Revision 0 April, 2017 n Ilihmq. AI.A., LIA: 13.10 Estimated metal cuttings volume from cutting window: M-06RD Drilling Procedure Rev 0 Wieght of Cuttings For Milled Casing Exit O.D. Of Casing (in) 9.625 I.D. Of Casing (in) 8.535 Whipstock Face Length (Ft) 16.00 Percent of Casing Removed (%)' 38 Milled Area (in Al2) 5.908 Volume of Cuttings (in A3) 1134.272 Density of Casing (lb./inA3) " 0.283 Weight of Cutting Generated (lbs) 321.0 Calculated Average of Casing Removed Based on Drift Mills (38%) Density of Steel = .283 13.11 Drill approx. 35' rat hole to accommodate the rotary steerable drilling assembly. Ream window as needed to assure there is little or no drag. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 13.12 Circulate Bottoms Up until MW in = MW out. k� 13.13 Conduct FIT to 12.5 ppg EMW.LVI • (12.5 — 8.9) * 0.052 * 4892' tvd = 916 psi 13.14 Kick Tolerance 7t, • (12.5 - 8.9) * (4892/9916) t7 3,b ,, c,yq) Note: Offset field test data pre icts frac gradients at the window to be between 12 ppg and 15 ppg. A 12.5 ppg FIT results in a ppg kick tolerance while drilling the interval with a 8.9 ppgfluid density. 13.15 Slug pipe and POOH. Gauge Mills for wear. 13.16 Should a second run be required pick up the following BHA. Page 17 Revision 0 April, 2017 K Ilikoq, M.A. I.1.0 Back Up Mills Connection M-06RD Drilling Procedure Rev 0 Length O.D. WINDOW MILL 4 % REG -P X MILL 2.25 8.5 NEW LOWER WATERMELON MILL 4'/z REG -P X 4'/s REG -B 5.5 8.5 FLEX JOINT 4 % REG -P X 4 Yz REG -B 9.0 6.375 STRING MILL 4 Yz REG -P X 4 Y: REG -B 5.5 8.5 FLOAT SUB 4'/i' REG -P X 5 Yi' NC50-B 3.0 6.375 30'ts-HWDP 5'/z' NC50-B X 5/2" NC50-P 900' 6.5 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY! Page 18 Revision 0 April, 2017 U Ililr�np Alueko, L1.1: 14.0 Drill 8-1/2" Hole Section 14.1 P/U 8-1/2" rotary steerable drilling assy. 14.2 Ensure BHA Components have been inspected previously. M-06RD Drilling Procedure Rev 0 14.3 Drift & caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 14.4 Ensure TF offset is measured accurately and entered correctly into the MWD software. 14.5 Confirm that the bit is dressed with a TFA of 0.51 - 0.61 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 450-550 gpm. 14.6 Primary bit will be the Halliburton 8-1/2" MM75DC PDC bit. Ensure to have a back up bit available on location. COMPONENT Item It I DATA Description Serial Number MMB PDC .. (in) 6.360 10 (in) 2.750 Gauge (in) 8.500 Weight (Ibpf) 88.03 Top Connection P 4-112' REG Length (it) 0.95 Cumulative Length (it) 0.95 2 Dirigo 7600 Rotary Steerable System 7.625 2.000 144.91 B 4-12• IF 23.16 24.11 Stabilizer 8.250 3 6-3r4' DGR (Gamma) 6.760 1.920 97.80 B 4-12' IF 8.22 32.33 4 Inline Stabilizer (ILS) 6.750 1.920 8.250 112.09 8 4-12' IF 2.20 34.53 5 6.314' PWD (Pressure) 6.750 1.920 96.30 B 4-12' IF 4.43 38.96 6 6-3(4' ADR Collar (Resistivity) 6.690 1.920 109.40 B4.12'IF 24.32 63.28 7 6-3/4' DM Collar (Directional) 6.760 3.125 103.40 84.12' IF 9.16 72.44 8 6.3/4' TM Collar (Mud Pulse Telemetry) 6.770 3.250 103.60 B 4-12' IF 10.38 82.82 9 6 314' Float Sub 6.810 2.875 102.01 B 4.12' IF 2.99 85.81 10 6 3/4' Non Mag Flex Collar 6.850 2.875 103.47 B 4-12' IF 31.09 116.90 11 6 314' Non Mag Flex Collar 6.670 2.938 95.98 B 4-12' IF 30.68 147.58 12 6 3/4' Non Map Flex Collar 6.590 2.813 95.07 B 4.12' IF 30.78 178.36 13 4 1/21F P x XT -39 B 6.500 2.500 96.36 B 4' XT39 1.51 179.87 14 6 its 4- XT -39 FIWDP 1 4.000 2.652 24.00 181.40 361.27 15 XT -39 P x 4 12' IF B 6.500 1 2.875 90.96 B 4.il; IF 1.30 362.57 16 6.1/4'Jar 6.500 2.500 88.24 B4.12'IF 30.00 392.57 17 4 121F P x XT -39 B 6.500 2.500 1 1 96.36 1 P 4- XT39 1.62 394.19 18 91ts 4' XT -39 11W DP 4.000 2.562 1 1 25.26 1 274.50 668.69 Total: V� Page 19 Revision 0 April, 2017 PRODUCT SPECIFICATIONS Cutter Type Select Cutter IADC Code M422 Body Type MATRIX Total Cutter Count 72 Cutter Distribution 13mm 16mm Face 0 46 Gauge 7 12 Up Drill 7 0 Number of Large Nozzles 0 Number of Medium Nozzles 0 Number of Small Nozzles 7 Number of Micro Nozzles 0 Number of Ports (Size) 0 Number of Replaceable Ports (Size) 0 Junk Slot Area (sq in) 13.06 Normalized Face Volume 37.82% API Connection 4-1/2 REG. PIN Recommended Make -Up Torque* 12,461 — 17.766 FNlbs. Nominal Dimensions" Make -Up Face to Nose 10.96 in - 278 mm Gauge Length 3 in - 76 mm Sleeve Length 0 in - 0 mm Shank Diameter 6 in - 152 mm Break Out Plate (Mat.#/Legacy#) 181954/44040 Approximate Shipping Weight 180Lbs. - 82Kg. SPECIAL FEATURES Up -Drill Cutters on Gage Pads, 1/16" Stepped Gage, Carbide Impact Arrestor, Optimized Dual Row - "D" Feature M-06RD Drilling Procedure Rev 0 HALLIBURTON Material #846097 *Bit specific recommended make-up torque is a function of the bit I.D. and actual bit sub O.D. utilized as specified in API RP7G Section A.8.2. **Design dimensions arc nominal and may vary slightly on manufactured product. Hallibunon Drill Bits and Services models are continuously reviewed and refined. Product specifications may change without notice. O 2016 Halliburton. All rights reserved. Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. Page 20 Revision 0 April, 2017 H Ililwrp ANA., U.1: 14.7 TIH to window. Shallow test MWD on trip in. M-06RD Drilling Procedure Rev 0 14.8 TIH through window, ensure Halliburton MWD service rep on rig floor during this operation. • Do not rotate string while bit is across face of Whipstock. 14.9 Drill 8-1/2" hole to 15595' MD using rotary steerable assembly. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • See mud program for hole cleaning and LCM strategies. • Ensure solids control equipment is functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain API fluid loss < 6. • Take MWD surveys every stand drilled. • Minimize backreaming when working tight hole 14.10 Hilcorp Geologists will follow mud log closely to determine exact TD. 14.11 At TD pump a sweep and a marker to be used as a fluid caliper to determine annulus volume for cement calculations. CBU, and pull a wiper trip back to the window. 14.12 TOH with drilling assembly, handle BHA as appropriate. Page 21 Revision 0 April, 2017 H Ilikoq, ALA., I.IX M-06RD Drilling Procedure Rev 0 15.0 Run 7" Production Liner M 7 ` £ fe 5t- 15.1 R/U Weatherford 7" casing running equipment. • Ensure 7" DWC/C x 5" NC -50 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted and tally verified prior to running. • Be sure to count the total # of joints before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 15.2 P/U shoe joint, visually verify no debris inside joint. 15.3 Continue M/U & thread locking shoe track assy consisting of: • (1) Shoe joint w/ shoe bucked on & threadlocked (coupling also thread locked). • (1) Baker locked joint. • (1) Joint with float collar bucked on pin end & threadlocked (coupling also thread locked). • (1) Joint with landing collar bucked up. • No centralizers to be installed on shoe joint, FC joint, and LC joint. • Install volant or equivalent solid body centralizers, one per joint to +/- 10,000' TMD, and leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe & FC. 15.4 Continue running 7" production liner • Fill casing while running using fill up line on rig floor. • Use "API Modified" thread compound. Dope pin end only w/ paint brush. • Install solid body centralizers on every joint to 10,000' MD. Leave the centralizers free floating. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 7" DWC/C M/IJ torques Casing OD Minimum Maximum Yield Torque 7" 19,200 ft -lbs 22,100 ft -lbs 25,000 ft -lbs Page 22 Revision 0 April, 2017 0 lhhor pAlnnku. I.I.I: Technical Specifications Connection Type: Size(O.D.): DWC/C Casing 7 in 2012 API Spec 5CT Coupling O.D. Material L-80 Grade 80,000 Minimum Yield Strength (psi) 95,000 Minimum Ultimate Strength (psi) M-06RD Drilling Procedure Rev 0 Weight (Wall): Grade: 29.00 Ib/ft (0.408 in) L-80 -USA Pipe Dimensions 7.000 Nominal Pipe Body O.D. (in) 6.184 Nominal Pipe Body I.D.(in) 0.408 Nominal Wall Thickness (in) 29.00 Nominal Weight (Ibslft) 28.75 Plain End Weight (lbs/ft) 8.449 Nominal Pipe Body Area (sq in) M-06RD Drilling Procedure Rev 0 Weight (Wall): Grade: 29.00 Ib/ft (0.408 in) L-80 -USA Pipe Body Performance Properties 676,000 Minimum Pipe Body Yield Strength (lbs) 7,030 Minimum Collapse Pressure (psi) 8,160 Minimum Internal Yield Pressure (psi) 7,500 Hydrostatic Test Pressure (psi) M-06RD Drilling Procedure Rev 0 Weight (Wall): Grade: 29.00 Ib/ft (0.408 in) L-80 -USA Connection Dimensions 7.875 Connection O.D. (in) 6.184 Connection I.D. (in) 6.125 Connection Drift Diameter (in) 4.50 Make-up Loss (in) 8.449 Critical Area (sq in) 100.0 Joint Efficiency (%) M-06RD Drilling Procedure Rev 0 Weight (Wall): Grade: 29.00 Ib/ft (0.408 in) L-80 -USA Appoximated Field End Torque Values 19,200 Minimum Final Torque (ft -lbs) 22,100 Maximum Final Torque (ft -lbs) 25,000 Connection Yield Torque (ft -lbs) VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston, TX 77041 Phone: 713-0793200 Fax: 713-4793234 Email: VAMUSAsales(o2yanwsa.com Page 23 Revision 0 April, 2017 Connection Performance Properties 676,000 Joint Strength (lbs) 16,650 Reference String Length (ft) 1.4 Design Factor 718,000 API Joint Strength (lbs) 338,000 Compression Rating (lbs) 7,030 API Collapse Pressure Rating (psi) 8,160 API Internal Pressure Resistance (psi) 26.2 Maximum Uniaxial Bend Rating [degrees/100 ft] Appoximated Field End Torque Values 19,200 Minimum Final Torque (ft -lbs) 22,100 Maximum Final Torque (ft -lbs) 25,000 Connection Yield Torque (ft -lbs) VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston, TX 77041 Phone: 713-0793200 Fax: 713-4793234 Email: VAMUSAsales(o2yanwsa.com Page 23 Revision 0 April, 2017 H Ilibnq, AI.A., LLC M-06RD Drilling Procedure Rev 0 15.7 Ensure to run enough liner to provide for approx 200' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8" connection. 15.8 Before picking up Baker SDD liner hanger / packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 15.9 M/U Baker SDD liner top packer. Fill liner tieback sleeve with "Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 15.10 RIH one stand and circulate a minimum of one liner volume. Note weight of liner 15.11 RIH w/ liner on DP no faster than 1 min/ stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 15.12 M/U top drive and fill pipe while lowering string every 10 stands. 15.13 Set slowly in and pull slowly out of slips. 15.14 Circulate 1-1/2 drill pipe and liner volume at 9-5/8" window prior to going into open hole. Stage pumps up slowly and monitor for losses. Do not exceed 60% of the nominal liner hanger setting pressure. 15.15 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 15.16 Continue to fill the string every 10 joints while running liner in open hole. Do not stop to fill casing. 15.17 P/U the cmt stand and tag bottom with the liner shoe. P/U 2' off bottom. Note slack -off and pick-up weights. Record rotating torque values at 10, 20, & 30 rpm. 15.18 Stage pump rates up slowly to circulating rate without exceeding 60% of the liner hanger setting pressure. Circ and condition mud with the liner on bottom. Reduce the low end rheology of the drilling fluid by adding water and thinners. 15.19 Reciprocate & rotate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 24 Revision 0 April, 2017 K niko,p ANA, LIT 16.0 Cement 7" Production Liner M-06RD Drilling Procedure Rev 0 • Cement will be mixed using batch mixer to ensure consistent density 16.1 Hold a pre job safety meeting over the upcoming cmt operations. 16.2 Attempt to reciprocate the casing during cmt operations until hole gets sticky. 16.3 Pump 15 bbls 12.5 ppg spacer. 16.4 Test surface cmt lines to 4500 psi. 16.5 Mix and pump 190 bbls of 15.3 ppg class "G" cmt per below recipe with 0.5 lb/bbl of loss circulation fiber. Ensure cmt is pumped at designed weight. Job is designed to pump 50% OH excess but if fluid caliper dictates otherwise we may increase excess volumes. Cement volume is designed to bring cement up to a minimum of 500' above hemlock in annulus of 7" casing and 8- 1/2" open hole. Est TOC 10000' TMD. 16.6 Displacement fluid will be drilling mud. —126 bbls of displacement fluid in drill pipe and —311 bbls of displacement fluid inside liner. Total of --437 bbls Cement Calculations 8-1/2" OH x 7" Liner: (15595' —10000') x 0.02259 x 1.5 = 190 bbls Shoe Track: 80' x 0.03715 = 3 bbls Total Volume (bbls): 190 + 3 = 193 bbls Total Volume (ft3): 193 bbls x 5.615 ft3/bbl = 1084 ft3 Total Volume (sx): 1084 ft3 / 1.34 ft3/sk = 809 sx Page 25 Revision 0 April, 2017 U nilemp M.A., LIX Slurry Information: M-06RD Drilling Procedure Rev 0 System Easy BLOK Density 15.3 lb/gal Yield 1.34 ft3/sk Mixed Water 5.879 gal/sk Mixed Fluid 5.879 gal/sk Expected Thickening 70 Bc at 05:00 hr:mn API Fluid Loss <25 mL in 30.0 min at 155degF / 1000 psi Additives Code Description Concentration G D046 D202 D400 D154 Cement Anti Foam Dispersant Gas Control Agent Extender 94 lb/sk 0.2% BWOC 1.5% BWOC 0.8% BWOC 8.0% BWOC 16.7 Drop DP dart and displace with drilling mud. 16.8 Pump cement at max rate of 8 bbl/min. Reduce pump rate to I hpm prig to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re -zeroed at this point 16.9 If elevated displacement pressures are encountered, position liner at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. Reduce pump rate as required to avoid packoff. 16.10 Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger (15% above nominal setting pressure. Hold pressure for 3-5 minutes. 16.11 Slack off total liner weight plus 30k to confirm hanger is set. 16.12 Do not overdisplace by more than % shoe track (—1 bbls). Shoe track volume is 1.8 bbls. 16.13 Pressure up to 4200 psi to release the running tool (HRD-E) from the liner Page 26 Revision 0 April, 2017 H Ililanry, Alaska, LLC 16.14 Bleed pressure to zero to check float equipment. M-06RD Drilling Procedure Rev 0 16.15 P/U, verify setting tool is released, and expose setting dogs on top of tieback sleeve 16.16 Rotate slowly and slack off 50k downhole to set ZXP. 16.17 Pressure up drill pipe to 500 psi and pickup to remove the RS packoff bushing from the RS profile. Bump up pressure as req'd to maintain 500 psi DP pressure while moving pipe until the pressure drops rapidly, indicating pack -off is above the sealing area (ensure that 500 psi will be enough to overcome hydrostatic differential at liner top). 16.18 Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 16.19 Pick up to the high -rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re -tag the liner top, and circulate the well clean. 16.20 Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 16.21 POOH, LDDP. Verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 16.22 If the HRD-E tool still does not release hydraulically, left-hand (counterclockwise) torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure ✓ and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 16.23 NOTE: Some hole conditions may require movement of the drillpipe to "work" the torque down to the setting tool. 16.24 After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set -down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point, the bottom sub no longer supports the collet fingers. Pick straight up with workstring to release collet from the profile. Page 27 Revision 0 April, 2017 M-06RD Drilling Procedure Rev 0 Ensure to report the following on Wellez: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface & volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the successor problems during the cement job Note: Send Csg & cmt report + "As -Run" liner tally to mmvers(&.hilcora.com Page 28 Revision 0 April, 2017 17.0 Wellbore Clean Up & Displacement M-06RD Drilling Procedure Rev 0 17.1 M/U casing clean out assy complete with casing scraper assys for each size casing in the hole. • 6" bit or mill • Casing scraper & brush for 7" 29# casing • +/- 8375' of 4" workstring. • Casing scraper & brush for 9-5/8" 47# casing • (2000') 5" DP • Casing scraper & brush for 9-5/8" 47# casing • 5" DP to surface. 17.2 TIH & clean out well to landing collar (+/- 15,475' MD). • Circulate as needed on trip in if string begins to take weight. • Circulate hi -vis sweeps as necessary to carry debris out of wellbore. Ensure 6" bit is worked down to the landing collar. Space out the cleanout BHA so that the 6" bit reaches the 7" landing collar when crossover is +/- 30' above the 7" liner top. 17.3 After wellbore has been cleaned out satisfactorily using mud, test casing to 2500 psi / 30 min. Ensure to chart record casing test. 17.4 Displace drilling fluid in wellbore with a hi -vis pill followed by filtered inlet water. • Circulate 3 to 4 B/U until clean-up is satisfactory. Do not recirculate fluid, pump and dump • After a couple circulations using FIW, short trip the assy to bring the upper 9-5/8" multi -back assy to surface. • RIH again & tag landing collar w/ 6" bit. Continue circulation as necessary until fluid cleans up. Make another short trip if necessary. • Pump a chemical train followed by FIW. Target NTU's are 80-100 17.5 TOH w/ clean out assy. Page 29 Revision 0 April, 2017 H f ih-.rp Alaxka, LLC 18.0 Run Completion Assembly M-06RD Drilling Procedure Rev 0 18.1 Run 2-7/8" tubing completion assembly as per separate Approved Completion Sundry 19.0 RD 19.1 Install BPV in wellhead. RILDs. 19.2 ND BOPE, NU tree, test void 19.3 Prep to skid rig Page 30 Revision 0 April, 2017 H Iliknq AI.A., LLC 20.0 BOP Schematic M-06RD Drilling Procedure Rev 0 m, n.o' Page 31 Revision 0 April, 2017 H Ilikoq, AlMeko. 1.1.1: 21.0 Wellhead Schematic EUMbeae pillf m M 30 36X16%f03/BX 1O Up Ipi Val-,= 165M1 4U Vahe,ury v WYXM.M. SSV. L/. /lg"OmN Vele, M -til 41/a6 sM FE F Ttihead MCEwY Alp, f35/B SM FE It, if I6%SM EE FctNn, .1 i- U165M S5O ruble feet m3cmw,waFn unlheaE, 16 X 5M fE lop X f6%SM .=,w/131/16 SMSSO IMlbat IMC irye 1 f6%SM FE top %31 X 2M FMC sift bortom,w/4211165MMO Meter apwl, FMOn�ss 3tl' MSS eftlE IpttomX 01 M 3M FMC 1peedlakbp,w/34'60 Slaltlng Flat Iff '. FE X M' ll fill 1112 135/9 4A HO li Eo,E5P. 135/BXiN IBi 1111 anE NM, w/<' iYM N 0 W poble, l-3/Bwnlimnln eoMrd tires BHiq FMC, &11 -AO, 41/16 SM FE A FE xwn,pp M-06RD Drilling Procedure Rev 0 Page 32 Revision 0 April, 2017 1/ 22.0 Days vs Depth Days Vs Depth M-06RD Drilling Procedure Rev 0 0 M-0 RD 2000 4000 6000 8000 L d d a u m � 10000 12000 14000 16000 18000 0 5 10 15 20 25 30 35 40 45 Days Page 33 Revision 0 April, 2017 H llllanp Alaska, LI.1: 23.0 Geo-Prog GEOLOGICAL PROGNOSIS Based on subsudaoe evaluation M-06RD Drilling Procedure Rev 0 :ARTHUR RIVER M-06RD ka _ KB 160 Based on new rig contig. 0.0 187.0 I thru WF2 benches. MD .. 1 FLUID KOP COAL39 coal i FW Sand/Conglomerate Oil Sand COAL59 Coal 0.43 _ HTKE-FW Sand/ Conglomerate Oil Sand HK2T Sand /Conglomerate Oil Sand WF7 Sand/Conglomerate Oil Sand WF2 _ Sand /Conglomerate Oil Sand WF3 Sand/Conglomerate Oil Sand TD 9,082 r M-06RD Drilling Procedure Rev 0 :ARTHUR RIVER M-06RD ka _ KB 160 Based on new rig contig. 0.0 187.0 I thru WF2 benches. MD NDIFiI Est Pressure EMW X` 7300 4,892 2120 8.33 0.43 11383 8,644 3426 7.62 0.40 11828 9,035 3566 7.59 0.39 11876 9,073 3575 7.58 0.39 11888 9,082 3582 7.58 0.39 11932 9,116 3597 7.59 0.39 13084 9,638 4230 8.44 0.44 13959 9,744 4258 8.40 0.44 15269 9.882 4326 8.42 0.44 _ r roan uew oeiow our e e.. Rotary Steereble, Gamma Res with Triple combo Mad Pass at TO r e. Gyro run upon cam pletion of the well to validate wellbore tortuosity and position. COMPLETION TYPE ESP ANTICIPATED RATES —500-3000 BPD ARTIFICKIL LIFT EQUIPMENTOD TUBING SIZE Page 34 Revision 0 April, 2017 H Ililcurp A1.4., LI.1: 24.0 Anticipated Drilling Hazards M-06RD Drilling Procedure Rev 0 Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material, 500 lbs SteelSeal (Angular, dual -composition carbon -based material), & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ viscofier as necessary. Sweep hole w/ 20 bbls flowzan as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain programmed mud specs. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt -type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. • Minimize swab and surge pressures • Minimize back reaming through coals when possible H2S: 112S is not present in this hole section. No abnormal temperatures or pressures are present in this hole section. II Page 35 Revision 0 April, 2017 K llilcorp Alaska. 1.1.1: 25.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: M-06RD Drilling Procedure Rev 0 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1 -minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre -determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre -determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 36 Revision 0 April, 2017 0 INlrorp .Uu+kn, LL1: 26.0 Choke Manifold Schematic TO GAS BUSTER TO DERRICK VENT TO SHALE SHAKERS M-06RD Drilling Procedure Rev 0 * ALL VALVES IN FLOW PATH ARE 0-1116' 5000 PSI CAMERON GATE TYPE Page 37 Revision 0 April, 2017 SECTION AA M-0 Drilling Procedure Rev 0 Illl, oqp A1.4a, LLA: 27.0 Offset MW vs. Depth TVD MW vs TVD Offsets 0 1,000 2,000 3,000 4,000 5,000 x O 6,000 7,000 8,000 9,000 10,000 11,000 —A-15RD2 (2002) G-28RD(2000) —G-15RD(1998) —K-13RD2 (2001) —D-48 (1999) �M29A (2012, 1700 ft @ 75 deg) —M318 (2013, 1500 ft @ 70 deg) 8.0 9.0 10.0 11.0 12.0 13.0 14.0 15.0 Mud Weight (PPG) Page 38 Revision 0 April, 2017 M-06RD Drilling Procedure Rev 0 28.0 Casing Design Information Calculation & Casing Design Factors Cook Inlet Offshore DATE: 4/1912017 WELL: M-06RD FIELD: McArthur River DESIGN BY: Monty M Myers Desiqn Criteria: Hole Size Mud Density: Hole Size 8-1/2" Mud Density: 9.0 ppg Hole Size Mud Density: Drilling Mode l'_,V, MASP: 2501 psi (See attached MASP determination & calculation) Production Mode MASP: 4744 psi (See attached MASP determination & calculation) Collapse Calculation: Section Calculation 1, 2 Normal gradient external stress (0.43 psi/ft) and the casing evacuated for the internal stress Cas ng Section — Calculation/Specification 1 2 3 4 Casing OD 7 Top (MD) 7,100 Top (TVD) �- _ 4,781 Bottom (MD) 15,595 __ l Bottom (TVD) 9,916 Length 8,495 Weight (ppf) 29 Grade L-80 __ Connection DWC/C Weight w/o Bouyancy Factor (Ibs) 246,355 Tension at Top of Section (lbs) 246,355 Min strength Tension (1000 lbs) 676 _ Worst Case Safety Factor (Tension) 2.74 Collapse Pressure at bottom (Psi) 3,905 Collapse Resistance w/o tension (Psi) 7,030 Worst Case Safety Factor (Collapse) 1.80 ./ MASP (psi) 2,501 Minimum Yield (psi) 8,160_ Worst case safety factor (Burst) 3.26E91 Page 39 Revision 0 April, 2017 M-06RD Drilling Procedure Rev 0 29.0 8-1/2" Hole Section MASP 14 Maximum Anticipated Surface Pressure Calculation H�ICO�rp 8-1/2" Hole Section M 06RD Cook Inlet, Alaska MD TVD Planned Top: 7300 4862 Planned TD: 15595 9916 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad COAL39 8644 3426 Water 7.6 0.39 H1X-FW 9035 3566 Oil Sand 7.6 0.39 COAL59 9073 3575 Water 7.6 0.39 HTKE-FW 9082 3582 Oil Sand 7.6 0.39 HK2T 9116 3597 Oil Sand 7.6 0.39 WF1 9638 4230 Oil Sand &3 0.43 WF2 9744 4258 Oil Sand &3 0.43 WF3 9882 4326 Oil Sand &3 0.43 TD 9916 4350 Oil Sand &3 0.43 Offset Well Mud Densities Well MW ranee Ton (TVDI Bottom ITVnl nate W31B 9.6-9.7 7,755 9,718 2013 G-28RD &6-9.5 8,100 9,600 2000 G -MD &6-9.4 8,500 9,550 1998 W29A 9.2-9.5 8,050 9,800 2012 Assumptions: 1. Anticipated fracture gradientat7300'TMD(4862'TVD)=0.7=14.9ppg EMW 2. Maximum planned mud densityforthe 8-1/2" hole section is 9.5 ppg. 3. Calculations assumes 9.2 ppg reservoir contains 2/3 gas, 1/3 water. Fracture Pressure at window considering a full column of gas from window to surface: 4862 (ft) x 0.7(psi/ft)= 3403 3403(psi)-[0.1(psi/ft)'4862(ft))= 2916 psi MASP from pore pressure; normal gradient atTD, (0.43 psi/ft) 9916(ft)x0.43(psi/ft)= 4264psi 4264(psi)-(0.1(psi/ft)'9916(ft))= 3272 psi MASP from pore pressure; unknown gas sand at TD, at 9.2 ppg (0.4781 psi/ft) 9916 (ft) x 0.47 4744(psi) - [(2/3)"0.1(psi/ft)'9916(ft))+[(1/3)'0.4784(psi/ft)' unhole ` Iing MASP ✓ Summary: 2 01�tO CA,,. 1. MASP while drilling 8-1/2" hole is governed by pore pressure minus 2/3 of wellbore evacuated togas (remaining 1/3 remains 9.2 ppg drilling fluid) Page 40 Revision 0 April, 2017 H IHlrerP Al.xka, LLC 30.0 Plot (NAD 27) (Governmental Sections) M-06RD Drilling Procedure Rev 0 Legend YY\ 1-I4RD2 BH • M.06RD_SHL • Other Surface Hole Location X M-06RD_TPH a Other Bottom Hole Locafim - Well Palls -} M-06RD_BHL ADL017594`� \ 1 1 • 1 I \` \ `\ ` -18 ML I 1 r \ 0 \ \ • w� \ L HL K-TDBW25PBBHL II It iK-0�i\0141. \-30 SHL \ I TRACING BAY K40BML I K f% \ \1 I 488 L KMPB \\ t1\ ,//, \ y� -- K058tl I U TRADING BAY UNI`IGJ, BHL ,�/// M318HLI\\`� ---- \ r f / ) 1r1y4(-21RD SHL ` \ , M-06RD TPH // /yrTKNOMG BAY UNIT AFRI I*L \ F218D�8 -• -- Q31L FU/ / -• \ GmRD \ i• / I , e r BNL \ \ / '- r \ e 1))Wv 14 4I BHL G-0S\BHL ADL017594/ ,'/ 1---�_�%HL \ bI �� ,\/ , I ING BAY UNIT G 2BHL `\WNrRD y\, /'/ \`\, .�>>a I M'IYB /Gn88H)M.25BHL G41 IML `\\, TRADING13AY,UOT ;_��—_�;��r�; e y /„ 11•�y1{ � 11• 1 %� / _�T!/BNt--"--- l`i'b LMI� -'-'-- ,/jam yw��a%t,�- * D/ Ma SHL -_____ -/ CMOHL -''idle e II - IrY'•3208HL / ��`� ' _ \ r1 -- •\eI a/r�� `,' Yn a \\ \\` ��� I• A /�_��iFDf11111L �'<� yG31 BM /�5gtD BHL M.06RD_BIIL � 002 /I IM-t"BHL ld3{``� \ 1 I 1 ♦-• Y43BHL 11 °PetO"` ADLO18730 QiR4i yq M•06RD_SHL Ste`elhead • 11• 1 t IN It I L`% 1 P 1 614ARD BHL y✓v1 YNIADWG BAY UNIT M-258HL W ISHI I I } 4G82RDBHL '\` / ` 28141. / ( , \ VI ,/ /I 1 `. `G48RDaNL I /O 1 \, / / It \ Page 41 Trading Bay Unit M-06RD Revision 0 1.01x1 2.00 Feet Maeea State Plane Zone 4. NAD27 Map Date: b/,82017 April, 2017 n Ilih! 1. Al.nko, LIA: 31.0 Slot Diagram (As Built) (NAD 27) SECTION LINE NOT TO SCALE (PROTRACTED) N:2500506.697 E: 213054.958' M-06RD Drilling Procedure Rev 0 LAT LAT 80'W LEG81 . 49'S4.839N 5M'FWL INTS) •N LON: 151.36'6.89514 N: 249WMM7 'n E: 2M67458' ASP ZONE 4 NAD V 1068'FNLINTS) LEG 0.1 1062FNLINTS) 1136FNLINTSI u 1'7LEG A 1 STEELHEAD PLATFORM "'' �• ..n° ASBUILT WELL LOCATIONS !�! SECTION 33 T9N RI 3W CENTER LEG&2 CENTER LEG A�1 UT: 60"49'54.27011 LAT: 60'49'54213-N LON. 151' 36'B25T4 I LON, t5t• 38' Stl51N N: 2499127.167 N: 499429.511' E: 214098.05' E:2H239.OT ASP ZONE 4 NAD 27 ASP 20NE4 NAp 21 CENTER LEO A-2 LAT. 60" 49' S1.544'N LON:151.36'627TV2 N: 2499357.467 544' FNL (NTSI E'. 214169.615' AV ZONE 4 NAD 27 O LEG AQ -OCH 2010) AND VERTICAL CONTROL (NAVD88) IS AN OPUS NATION FROM NGS STATIONS KENS. AC51 AND ANC2 TO ITABLISH CP -I. THE ALASKA STATE PLANE COORDINATES NAD ZONE 41N FEET ARE: N = 2486371.366 E = 1354193.305 ELEV.= 1SOA361NAVDSB) SECTION LINES SHOWN ARE EXTENSIONS OF PROTRACTED ,LUES. ATU DM TRANSFORMATIONS (NADS3 ASPZ4 TO NAD27 ASPZ4) -ERE DONE USING CORPSCON SOFTWARE VERSION 6.0.1. SCALE o m m EE! w:urlr " RILLV V Rf" I1V\JRr.• LLV STEELHEAD PLATFORM WELLS " ""° M '• ®t COOK INLET ALASKA AS BUILT SURFACE LOCATION (nf.N[°N°..WP,giWKVX°tirflNp NAD 27'`"°°• °hkW 4A L a.<Lw<Aca1 1lilrurp .Ua•Im, LLf. "°" PROTRACTED SEC. 33 T09N R13W or.. SEWARD MERIDIAN, ALASKA �•r' 1-3 Page 42 Revision 0 April, 2017 H Ililroq..AI.A., LLA: M-06RD Drilling Procedure Rev 0 rw.uE�in< ervo"�m�"."wriw.sw.Evno: rezmn YO 0"%.b080t"tl.M9°E03 �%• Center Leg B-2 NAD 27 214239.137 60' 49' 54.270" e"oxwi°a Slot # I Well # Northing Easting Latitude Longitude 214246.421 Center Leg B-1 2499499.259 214167.458 60'49'54.939" -151' 36'6.895" 2 M-18 1 M-26 2499505.978 214167.640 60' 49' 55.006" -151' 36' 6.894" 2499422.705 2 M-32RD 2499504.406 214171.960 60°49'54.991" -151'36'6.806" 4 M-21 3 M-28 2499500.316 214174.375 60'49'54.951" -151' 36'5.474" -151'36'6.756" 4 M-27 2499495.577 214173.610 60'49'54.905" -151'36'6.769" -151'36'5.540" Leg B-1 5 Empty 2499492.381 214170.029 60'49'54.872" 60'49'54.291" -151'36'6.839" -151'36'5.544" 6 Empty 2499492.362 214165.235 60'49'54.871" -151'36'6.936" 7 M -29A 2499495.452 214161.556 60' 49' 54.900" -151' 36'7.012" 8 g Empty 2499500.052 214160.609 60' 49' 54.946" -151° 36'7.033" 9 9 M-30 2499504.087 214162.790 60'49'54.986" -151°36'5.298" -151'36'6.991" 10 10 N/A 2499500.729 214170.099 60' 49'5C954" -151° 36'6.842" -151' 36'5.382" 11 M-25 2499495.774 214167.855 60'49'5490 60' 49' -151'36'6.885" -151'36'5.473" 12 M -31B 2499500.204 214164.607 60' 49' ;4!;82-151'36'6.952"4 rw.uE�in< ervo"�m�"."wriw.sw.Evno: rezmn YO 0"%.b080t"tl.M9°E03 �%• Center Leg B-2 2499429.534 214239.137 60' 49' 54.270" e"oxwi°a -1514 36'5.415" SIIEEI q 3 3 1 M-9 2499429.705 214246.421 60' 49' 54.274" -151' 36'5.268" 2 M-18 2499425.538 214245.127 60'49'54.232" -151'36'5.292" 3 M-2 2499422.705 214240.766 60°49'54.203" -151'36'5.378" 4 M-21 2499423.448 214236.029 60' 49'54.210" -151' 36'5.474" 5 Empty 2499427.060 214232.883 60'49'S4.244" -151'36'5.540" Leg B-2 6 M-6 2499431.832 214232.798 60'49'54.291" -151'36'5.544" 7 M-7 2499435.552 214235.847 60'49'54.329" -151"36'5.484" 8 M-1 2499436.452 214240.494 60'49'54.339" -151"36'5.391" 9 M-4 2499433.752 214245.008 60'49'54.313" -151°36'5.298" 10 M-3 2499426.614 214240.677 60' 49'54.242" -151' 36'5.382" 11 M-5 2499429.508 214236.227 60' 49' 54.269" -151'36'5.473" 12 Empty 2499432.482 214240.507 60'49'54.300" -151°36'5.388" rw.uE�in< ervo"�m�"."wriw.sw.Evno: rezmn YO 0"%.b080t"tl.M9°E03 �%• (Iilwrp Alaska. I,Lf. STEELHEAD PLATFORM WELLS COOK INLET ALASKA AS BUILT SURFACE LOCATION NAD 27 Sf11fi '�" ""..0 0 e"oxwi°a aCf iW PROTRACTED SEC. 33 T09N R13W SEWARD MERIDIAN. ALASKA SIIEEI q 3 3 Page 43 Revision 0 April, 2017 H IlH 1, AI.A., IAA: 32.0 Directional Program (wp04) M-06RD Drilling Procedure Rev 0 Page 44 Revision 0 April, 2017 Hilcorp Alaska, LLC McArthur River Steelhead TBU M-06 - Slot 132-06 Plan: M-06RD Plan: M-06RD WP04 Standard Proposal Report 17 February, 2017 HALLIBURTON Sperry Drilling Services HALLIBURTON Hiloorp Alaska, LLC REFERENCE INFORMATION Calculation Method: MinimuCurvature Co m ordinate(WE) RaM kmance: Well TBU -06- Slot 132-06, True North Sperry Orllling Error System: ISCWSA Vertical (TVD) Reference: TBU M6 @ 16000us8 Scan Methad: Closest Approach 30 Measured Depth Reference: TBU M6 @ 150.00us8 Error Surface: Elliptical Conic Warning Method: Error Ratio Czlculalion Method: Minimum Curvature I Project., McArthur River SECTION DETAILS Site: Steelhead Sec MD Inc .59 TVD +N/ -S +E/ -W Dog0.00 TFace VSect46.32 Target Well: TBU M-06 1 7300,00 54.23 18.59 4892.27 4606.18 1583.04 0.00 0.00 4846.32 Wellbore: Plan: M-06RD 2 7317.00 55.29 14.39 4902.08 4619.56 1586.74 12.30 -60.00 4860.19 n: Desi M-06RD WP04 3 7437.00 55.29 14.39 4970.41 4715.11 1611.25 0.00 0.00 4958.82 Design: 4 8516.56 13.07 354.22 5845.36 5294.06 1714.13 4.00 -173.46 5545.94 5 10604.70 13.07 354.22 7879.39 5763.94 1666.61 0.00 0.00 5992.45 6 12784.03 75.00 196.06 9560.35 4805.17 1271.30 4.00 -158.92 4968.62 7 13084.03 75.00 196.06 9638.00 452610 1191.14 0.00 0.00 4679.19 M-06RD WP04 WFi Tgt 1 8 13263.06 83.95 196.06 9570.67 4357.72 1142.50 5.00 0.00 4503.56 DDI = 6.608 9 15268.75 83.95 196.06 9882.00 2441.02 590.80 0.00 0.00 2511.45 M-06RD WP04 WF3 Tgt2 10 15595.00 83.95 196.06 9916.38 2129.24 501.06 0.00 0.00 2187.40 FORMATION TOP DETAILS 6175 TVDPath TVDssPath MDPath Formation 8644.00 8484.00 11382.68 COAL39 9035.00 887500 11827.96 H1X FW 9073.00 891300 11876.12 COAL59 9082.00 892200 11887.72 HTKE-FW - 9118.00 895600 11932.25 HK2T 6650- 9638.00 947800 13084.03 WF1 9744,00 9584.00 13959.04 WF2 - 9882.00 9722.00 15268.75 WF3 _ c � 7125 3 m t 7600 a m E 8075 m 8550 9025 WELL DETAILS: TEL M-06 Ground Level: 160.00 -EJ-VV Northing Easting Latidude Longitude 0.00 2499431.83 214232.80 60° 49 54.2912945 N 151.36' 55436581 W Start Dir 12.30/100' : 7300' MD, 4892.27'ND : 60° LT TF °O° End Dir :7317' MD, 4902.08' ND 1 Start Dir40/100': 7437' MD, 4970.41TVD � 0 End Dir : 8516.56' MD, 5845.36' ND 8500 °° �y 9000 NZ 105p0 J 1-10000 Start Dir 40/100' : 10604.7' MD, 7879.39'ND 11500 �BdOi� Sf 72> 11000 12000 drOf�So 8403 -%a /78p 4fo 9'180 S COAL39 Di� .7 7`706. • 8 35• HlX_FW M -OG _ 12502 888'88• %0"' 9680 ?, �O NTKE FWCOAL59. 7j588 4jO 98> 38' V� HK2T - - OB> 7d Total Depth: 15595'MD, 9916.38'ND WF1 Ben 9500 WF2 �m WF3 O 00 W O 0 9975 - Co Co Co 15595o 0 7"x81/2"• co M-06RD WP04 WF1 Tgt 1 _ M-06RD WP04 10450 M-06RD WP04 WF3 Tgt 2 10925 1900 2375 2850 3325 3800 4275 4750 5225 5700 6175 6650 7125 7600 8075 8550 Vertical Section at 13.24' (950 usfUin) SURVEY PROGRAM Date: 2017-02-10T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 100.00 3000.00 M-06 GYD NSG_WL 3072.86 7300.00 MWD MWD 7300.00 15595.00 M-06RD WPO4 MWD+SC+sag " CASING DETAILS 1750 TVD TVDSS MD Size 9916.38 9756.38 15595.00 7"X 8 1/2" FORMATION TOP DETAILS 6175 TVDPath TVDssPath MDPath Formation 8644.00 8484.00 11382.68 COAL39 9035.00 887500 11827.96 H1X FW 9073.00 891300 11876.12 COAL59 9082.00 892200 11887.72 HTKE-FW - 9118.00 895600 11932.25 HK2T 6650- 9638.00 947800 13084.03 WF1 9744,00 9584.00 13959.04 WF2 - 9882.00 9722.00 15268.75 WF3 _ c � 7125 3 m t 7600 a m E 8075 m 8550 9025 WELL DETAILS: TEL M-06 Ground Level: 160.00 -EJ-VV Northing Easting Latidude Longitude 0.00 2499431.83 214232.80 60° 49 54.2912945 N 151.36' 55436581 W Start Dir 12.30/100' : 7300' MD, 4892.27'ND : 60° LT TF °O° End Dir :7317' MD, 4902.08' ND 1 Start Dir40/100': 7437' MD, 4970.41TVD � 0 End Dir : 8516.56' MD, 5845.36' ND 8500 °° �y 9000 NZ 105p0 J 1-10000 Start Dir 40/100' : 10604.7' MD, 7879.39'ND 11500 �BdOi� Sf 72> 11000 12000 drOf�So 8403 -%a /78p 4fo 9'180 S COAL39 Di� .7 7`706. • 8 35• HlX_FW M -OG _ 12502 888'88• %0"' 9680 ?, �O NTKE FWCOAL59. 7j588 4jO 98> 38' V� HK2T - - OB> 7d Total Depth: 15595'MD, 9916.38'ND WF1 Ben 9500 WF2 �m WF3 O 00 W O 0 9975 - Co Co Co 15595o 0 7"x81/2"• co M-06RD WP04 WF1 Tgt 1 _ M-06RD WP04 10450 M-06RD WP04 WF3 Tgt 2 10925 1900 2375 2850 3325 3800 4275 4750 5225 5700 6175 6650 7125 7600 8075 8550 Vertical Section at 13.24' (950 usfUin) WEIL DETAILS: TBU M-06 Ground Level: 160.00 +N/ -S +F/ -W Noshing Eesti, Isnnude Lo giW e 0.00 0.00 24"43 1.83 214232.80 60° 49' 54.2912945 N 151° 36 5,5436581 W REFERENCE INFORMATION Co aNI to (N� Reference: Well TBU M-05- SIM W-05. Tme NoM VeNeal l Reference: TBU W90162.00vsfi -600 -300 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 West( -)/East(+) (600 ucR/in) HALLIBURTON Project: McArthur River Site: Steelhead sae�nr or1111no Well: TBU M-06 Wellbore: Plan: Plan: M-06RD WPO WP04 WEIL DETAILS: TBU M-06 Ground Level: 160.00 +N/ -S +F/ -W Noshing Eesti, Isnnude Lo giW e 0.00 0.00 24"43 1.83 214232.80 60° 49' 54.2912945 N 151° 36 5,5436581 W REFERENCE INFORMATION Co aNI to (N� Reference: Well TBU M-05- SIM W-05. Tme NoM VeNeal l Reference: TBU W90162.00vsfi -600 -300 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 West( -)/East(+) (600 ucR/in) HALLIBURTON Database: Sperry EDM - NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: McArthur River Site: Steelhead Well: TBU M-06 Wellbore: Plan: M-06RD Design: W06RD WP04 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well TBU M-06 - Slot B2-06 TBU M-6 @ 160.00usft TBU M-6 @ 160.00usft True Minimum Curvature Project McArthur River Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Steelhead Site Position: From: Map Position Uncertainty: Northing: Easting: 0.00 usft Slot Radius: 2,499,453.95 usft Latitude: 214,083.78 usft Longitude: 13-3/16" Grid Convergence: 60° 49'54,4732457 N 151" 36'8.5597019 W -1.40 ° Well TBU M-06 - Slot B2-06 Well Position +N/S 0.00 usft Northing: 2,499,431.83 usft Latitude: 60° 49'54.2912945 N Plan: M-06RD +E/ -W 0.00 usft Easting: 214,232.80 usft Longitude: 151' 36'5.5436581 W Position Uncertainty 0.00 usft Wellhead Elevation: 163.00 usft Ground Level: 160.00 usft 2/17/201710:10:18AM Page 2 COMPASS 5000.1 Build 81 Withers Plan: M-06RD Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2016 2/712D17 16.15 73.73 55,435 Design M-06RD WP04 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,300.00 Vertical Section: Depth From (TVD) +N/ -S +FJ -W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 13.24 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/ -S +Ef-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (us8) (9100usft) (°/100usft) (°/100usft) (1) 7,300.00 54.23 16.59 4,892.27 4.73227 4,606.18 1,583.04 0.00 0.00 0,00 0.00 7,317.00 55.29 14.39 4,902.08 4.74208 4,619.56 1,586.74 12.30 6.27 -12.96 -60.00 7,437.00 55.29 14.39 4,970.41 4.810.41 4,715.11 1,511.25 0.00 0.00 0.00 0.00 8,516.56 13.07 354.22 5,845.36 5,685.36 5,294.06 1,714.13 4.00 -3.91 -1.87 -173.46 10,604.70 13.07 354.22 7,879.39 7.719.39 5,763.94 1,666.61 0.00 0.00 0.00 0.00 12,784.03 75.00 196.06 9,560.35 9,400.35 4,805.17 1,271.30 4.00 2.84 -7.26 -158.92 13,084.03 75.00 196.06 9,638.00 9.478.00 4,526.70 1,191.14 0.00 0.00 0.00 0.00 13,263.06 83.95 196.06 9,670.67 9,510.67 4,357.72 1,142.50 5.00 5.00 0.00 0.00 15,268.75 83.95 196.06 9,882.00 9,722.00 2,441.02 590.80 0.00 0.00 0.00 0.00 15,595.00 83.95 196.06 9,916.38 9,756.38 2,129.24 501.06 0.00 0.00 0.00 0.00 2/17/201710:10:18AM Page 2 COMPASS 5000.1 Build 81 Planned Survey Halliburton H A L L I B U RTO N Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Coordinate Reference: Well TBU M-06 - Slot B2-06 Company: Hilcorp Alaska, LLC TVD Reference: TBU M-6 @ 160.00usft Project: McArthur River MD Reference: TBU M-6 @ 160.00usft Site: Steelhead North Reference: True Well: TBU M-06 Survey Calculation Method: Minimum Curvature Wellbore: Plan: M-06RD Depth Inclination Design: M-06RD WP04 Depth TVDss Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss -NIS +E/.W Northing Easting DLS Vert Section (usft) (°) V) (usft) usft (usft) (usft) (usft) (usft) .160.00 0.00 0,00 0.00 0.00 -160.00 0.00 0.00 2,499,431.83 214,232.80 0.00 0.00 100.00 0 46 161.57 100.00 -60.00 -0.38 0.13 2,499,431 AS 214,232.91 0.46 -0.34 200.00 0.24 141.70 200.00 40.00 -0.93 0.38 2,499,430.90 214,233.16 0.25 -0.81 300.00 0.40 263.49 300.00 140.00 -1.13 0.17 2,499,430.70 214,232.94 0.56 -1.06 400.00 0.26 288.30 399.99 239.99 -1.10 -0.40 2,499,430.74 214,232.37 0.20 -1.16 450.00 0.60 25.90 449.99 289.99 -0.83 -0.39 2,499,431.01 214,232.39 1.37 -0.89 455.00 0.62 26.49 454.99 294.99 -0.78 -0.37 2,499,431.06 214,232.41 0.42 -0.84 460.00 0.68 22.53 459.99 299.99 -0.73 -0.34 2,499,431.11 214,232.44 1.50 -0.79 465.00 0.80 16.24 464.99 304.99 -0.67 -0.32 2,499,431.17 214,232.46 2.89 -0.72 470.00 0.96 7.53 469.99 309.99 -0.59 -0.31 2,499,431.25 214,232.48 4.16 -0.65 475.00 1.12 358.29 474.99 314.99 -0.50 -0.30 2,499,431.34 214,232.48 4.63 -0.56 480.00 1.37 350.46 479.99 319.99 -0.39 -0.31 2,499,431.45 214,232.47 6.04 -0.45 485.00 1.65 344.73 484.99 324.99 -0.27 -0.34 2,499,431.58 214,232.45 6.36 -D.34 490.00 2.03 340.70 489.99 329.99 -0.11 -0.39 2,499,431.73 214,232.40 8.02 -0.20 495.00 2.40 339.22 494.98 334.98 0.07 -0.46 2,499,431.91 214,232.34 7.49 -0.04 500.00 2.88 337.80 499.98 339.98 0.28 -0.54 2,499,432.13 214,232.26 9.69 0.15 505.00 3.24 336.60 504.97 344.97 0.53 -0.64 2,499,432.38 214,232.17 7.31 0.37 510.00 3.51 337.21 509.96 349.96 0.80 -0.76 2,499,432.65 214,232.06 5.45 0.60 515.00 3.72 335.62 514.95 354.95 1.09 -0.89 2,499,432.94 214,231.94 4.65 0.86 520.00 3.86 336.41 519.94 359.94 1.39 -1.02 2,499,433.25 214,231.81 2.99 1.12 525.00 3.96 337.76 524.93 364.93 1.70 -1.15 2,499,433.56 214,231.69 2.72 1.40 530.00 4.09 336.73 529.92 369.92 2.03 -1.29 2,499,433.89 214,231.56 2.97 1.68 535.00 4.26 336.53 534.90 374.90 2.36 -1.43 2,499,434.23 214,231.42 3.41 1.97 540.00 4.45 335.28 539.89 379.89 2.71 -1.59 2,499,434.58 214,231.27 4.25 2.27 545.00 4.60 336.45 544.87 384.87 3.07 -1.75 2,499,434.94 214,231.12 3.52 2.59 550.00 4.72 337.23 549.86 389.86 3.44 -1.91 2,499,435.32 214,230.97 2.71 2.91 555.00 4.79 337.89 554.84 394.84 3.83 -2.07 2,499,435.71 214,230.82 1.78 3.25 560.00 4.89 337.74 559.82 399.82 4.22 -2.23 2,499,436.10 214,230.67 2.02 3.59 565.00 4.99 338.64 564.80 404.80 4.62 -2.39 2,499,436.51 214,230.52 2.53 3.95 570.00 5.06 339.15 569.78 409.78 5.02 -2.54 2,499,436.92 214,230.38 1.66 4.31 575.00 5.09 340.19 574.76 414.76 5.44 -2.70 2,499,437.34 214,230.23 1.94 4.68 580.00 5.17 341.54 579.74 419.74 5.86 -2.84 2,499,437.76 214,230.10 2.90 5.05 585.00 5.22 343.57 584.72 424.72 6.29 -2.98 2,499,438.20 214,229.97 3.81 5.44 590.00 5.27 345.19 589.70 429.70 6.73 -3.10 2,499,438.64 214,229.86 3.13 5.84 595.00 5.33 344.63 594.68 434.68 7.18 -3.22 2,499,439.09 214,229.75 1.58 6.25 600.00 5.40 346.96 599.66 439.66 7.53 -3.34 2,499,439.54 214,229.65 4.58 6.67 610.00 5.46 347.15 609.61 449.61 8.56 -3.55 2,499,440.47 214,229.46 0.63 7.51 620.00 5.44 350.06 619.57 459.57 9.49 -3.74 2,499,441.41 214,229.29 2.77 8.38 630.00 5.44 354.58 629.52 469.52 10.42 -3.86 2,499,442.35 214,229.19 4.28 9.26 640.00 5.45 353.49 639.48 479.48 11.37 -3.96 2,499,443.29 214,229.11 1.04 10.16 650.00 5.54 355.04 649.43 489.43 12.32 -4.06 2,499,444.25 214,229.04 1.74 11.06 660.00 5.55 356.60 659.39 499.39 13.28 -4.13 2,499,445.21 214,228.99 1.51 11.99 670.00 5.57 0.68 669.34 509.34 14.25 .4.15 2,499,446.18 214,228.99 3.96 12.92 680.00 5.55 357.37 679.29 519.29 15.22 -4.17 2,499,447.15 214,229.00 3.21 13.86 690.00 5.62 357.09 689.24 529.24 16.19 -4.22 2,499,448.12 214,228.98 0.75 14.80 2/17/2017 10:10:184M Page 3 COMPASS 5000.1 Build 81 HALLIBURTON Database: Sperry EDM - NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: McArthur River Site: Steelhead Weil: TBU M-06 Wellbore: Plan: M-06RD Design: M-06RD WP04 Planned Survey Measured Depth (usft) 700.00 710.00 720.00 730.00 740.00 750.00 760.00 770.00 780.00 790.00 800.00 810.00 820.00 825.00 850.00 875.00 900.00 925.00 950.00 975.00 1,000.00 1,025.00 1,050.00 1,075.00 1,100.00 1,125.00 1,150.00 1,175.00 1,200.00 1,225.00 1,250.00 1,275.00 1,300.00 1,325.00 1,350.00 1,375.00 1,400.00 1,401.00 13 3/8" 1,425.00 1,450.00 1,475.00 1,500.00 1,525.00 1,550.00 Local Comrdinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well TBU M-06 -Slot B2-06 TBU M-6 @ 160.00usft TBU M-6 @ 160.00usft True Minimum Curvature 25.47 18.01 Vertical 1,232.88 201.20 54.86 Map Map 214,292.56 0.58 Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (°) (°) (usft) usft (usft) (usft) (usft) (usft) 539.20 2,499,652.16 5.70 358.77 699.20 539.20 17.18 -0.25 2,499,449.11 214,228.97 1.84 15.75 5.77 1.80 709.15 549.15 18.18 4.25 2,499,450.11 214,229.00 3.11 16.72 5.84 359.86 719.09 559.09 19.19 -4.23 2,499,451.12 214,229.04 2.08 17.71 5.86 0.64 729.04 569.04 20.21 -4.23 2,499,452.14 214,229.06 0.82 18.70 6.05 7.69 738.99 578.99 21.24 -4.15 2,499,453.17 214,229.17 7.55 19.73 6.23 9.24 748.93 588.93 22.30 -3.99 2,499,454.22 214,229.35 2.45 20.79 6.38 10.19 758.87 598.87 23.38 -3.81 2,499,455.30 214,229.56 1.83 21.89 6.50 11.38 768.81 608.81 24.48 -3.60 2,499,456.40 214,229.80 1.79 23.01 6.80 9.73 778.74 618.74 25.62 -3.39 2,499,457.53 214,230.04 3.56 24.16 7.13 8.60 788.67 628.67 26.82 -3.19 2,499,458.72 214,230.26 3.57 25.37 7.30 8.64 798.59 638.59 28.06 -3.00 2,499,459.96 214,230.48 1.70 26.63 7.53 8.40 808.50 648.50 29.34 -2.81 2,499,461.23 214,230.70 2.32 27.91 7.91 10.56 818.41 658.41 30.66 -2.59 2,499,462.55 214,230.95 4.78 29.25 8.19 10.97 823.36 663.36 31.35 -2.46 2,499,463.23 214,231.10 5.72 29.95 8.80 12.37 848.09 688.09 34.96 -1.71 2,499,466.83 214,231.94 2.58 33.64 9.42 13.89 872.77 712.77 38.82 -0.81 2,499,470.66 214,232.93 2.66 37.60 9.85 14.76 897.42 737.42 42.87 0.22 2,499,474.69 214,234.07 1.82 41.78 10.56 15.98 922.03 762.03 47.14 1.40 2,499,478.93 214,235.35 2.97 46.21 11.43 16.11 946.57 786.57 51.73 2.72 2,499,483.48 214,236.78 3.48 50.97 12.26 17.69 971.03 811.03 56.63 4.21 2,499,488.35 214,238.39 3.56 56.09 13.00 19.03 995.43 835.43 61.82 5.94 2,499,493.49 214,240.24 3.18 61.54 14.12 19.62 1,019.73 859.73 67.35 7.88 2,499,498.97 214,242.31 4.51 67.37 14.99 20.23 1,043.93 883.93 73.26 10.02 2,499,504.82 214,244.60 3.53 73.60 15.93 20.47 1,068.02 908.02 79.51 12.34 2,499,511.01 214,247.07 3.77 80.22 16.71 20.76 1,092.02 932.02 86.08 14.81 2,499,517.53 214,249.70 3.14 87.18 17.71 20.63 1,115.90 955.90 93.00 17.42 2,499,524.38 214,252.48 4.00 94.52 18.51 20.67 1,139.66 979.66 100.27 20.16 2,499,531.58 214,255.40 3.20 102.23 19.32 20.20 1,163.31 1,003.31 107.87 22.99 2,499,539.10 214,258.42 3.30 110.27 20.36 19.93 1,186.82 1,026.82 115.84 25.90 2,499,547.00 214,261.52 4.18 118.69 21.19 19.39 1,210.20 1,050.20 124.19 28.89 2,499,555.28 214,264.70 3.41 127.50 21.92 19.31 1,233.45 1,073.45 132.85 31.93 2,499,563.87 214,267.96 2.92 136.63 22.93 19.13 1,256.56 1,096.56 141.86 35.07 2,499,572.79 214,271.32 4.05 146.12 23.74 19.04 1,279.51 1,119.51 151.22 38.31 2,499,582.07 214,274.78 3.24 155.97 24.49 18.42 1,302.33 1,142.33 160.89 41.58 2,499,591.66 214,278.30 3.17 166.14 24.94 18.31 1,325.04 1,165.04 170.81 44.88 2,499,601.50 214,281.83 1.81 176.55 25.21 18.32 1,347.69 1,187.69 180.87 48.21 2,499,611.47 214,285.40 1.08 187.10 25.33 18.09 1,370.29 1,210.29 191.01 51.54 2,499,621.52 214,288.98 0.62 197.73 25.34 18.09 1,371.20 1,211.20 191.41 51.67 2,499,621.93 214,289.13 0.58 198.16 25.47 18.01 1,392.88 1,232.88 201.20 54.86 2,499,631.63 214,292.56 0.58 208.42 25.63 17.75 1,415.43 1,255.43 211.46 58.17 2,499,641.81 214,296.12 0.78 219.17 26.31 17.40 1,437.91 1,277.91 221.90 61.48 2,499,652.16 214,299.67 2.79 230.08 26.86 17.09 1,460.26 1,300.26 232.59 64.80 2,499,662.77 214,303.25 2.27 241.24 27.43 17.05 1,482.51 1,322.51 243.49 68.14 2,499,673.58 214,306.86 2.28 252.62 28.27 16.58 1,504.61 1,344.61 254.67 71.52 2,499,684.68 214,310.51 3.47 264.28 21172017 10:10:18AM Page 4 COMPASS 5000.1 Build 81 Halliburton HALLI B U RTO N Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well TBU M-06 - Slot 132-06 Company: Hilcorp Alaska, LLC TVD Reference: TBU M£ @ 160.00usft Project: McArthur River MO Reference: TBU M-6 @ 160.00usft Site: Steelhead North Reference: True Well: TBU M-06 Survey Calculation Method: Minimum Curvature Wellbore: Plan: M-06RD Design: M-06RD WP04 Azimuth Depth . Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/.S +E/ -W Northing Easting OLS Vert Section (usft) (•) (•) (usft) usft (usft) (usft) (usft) (ustt) 1,366.53 1,575.00 29.25 15.98 1,526.53 1,366.53 266.22 74.89 2,499,696.14 214,314.16 4.09 276.29 1,600.00 29.85 15.72 1,548.28 1,388.28 278.08 78.26 2,499,707.91 214,317.82 2.45 288.61 1,625.00 3D.48 15.94 1,569.89 1,409.89 290.16 81.69 2,499,719.91 214,321.54 2.56 301.16 1,650.00 31.34 16.14 1,591.34 1,431.34 302.50 85.24 2,499,732.16 214,325.39 3.46 313.99 1,675.00 32.02 16.43 1,612.62 1,452.62 315.11 88.92 2,499,744.67 214,329.38 2.79 327.10 1,700.00 32.53 16.51 1,633.75 1,473.75 327.91 92.70 2,499,757.38 214,333.47 2.05 340.42 1,725.00 33.42 17.01 1,654.73 1,494.73 340.94 96.63 2,499,770.31 214,337.72 3.72 354.01 1,750.00 34.25 17.75 1,675.49 1,515.49 354.22 100.79 2,499,783.48 214,342.20 3.71 367.89 1,775.00 35.04 18.32 1,696.06 1,536-06 367.73 105.19 2,499,796.89 214,346.93 3.42 382.05 1,800.00 35.84 18.38 1,716.43 1,556.43 381.49 109.75 2,499,810.53 214,351.83 3.20 396.49 1,825.00 36.69 18.51 1,736.58 1,576.58 395.52 114.43 2,499,824.44 214,356.85 3.41 411.22 1,850.00 37.37 18.63 1,756.54 1,596.54 409.79 119.22 2,499,838.59 214,361.99 2.74 426.21 1,875.00 38.16 18.86 1,776.31 1,616.31 424.29 124.14 2,499,852.96 214,367.26 3.21 441.45 1,900.00 39.15 19.17 1,795.83 1,635.83 439.05 129.23 2,499,867.60 214,372.71 4.04 456.98 1,925.00 40.09 19.43 1,815.09 1,655.09 454.10 134.50 2,499,882.51 214,378.34 3.82 472.84 1,950.00 40.76 19.49 1,834.12 1,674.12 469.39 139.90 2,499,897.66 214,384.11 2.68 488.95 1,975.00 41.63 19.80 1,852.93 1,692.93 484.89 145.44 2,499,913.03 214,390.03 3.57 505.31 2,000.00 42.41 19.91 1,871.50 1,711.50 500.63 151.12 2,499,928.62 214,396.09 3.13 521.94 2,025.00 43.11 20.24 1,889.86 1,729.86 516.57 156.95 2,499,944.42 214,402.31 2.94 538.79 2,050.00 43.98 20.51 1,907.98 1,747.98 532.72 162.95 2,499,960.41 214,408.70 3.56 555.88 2,075.00 44.70 20.68 1,925.86 1,765.86 549.08 169.09 2,499,976.61 214,415.24 2.92 573.21 2,100.00 45.47 20.74 1,943.51 1,783.51 565.63 175.35 2,499,993.01 214,421.90 3.08 590.76 2,125.00 46.43 20.68 1,960.89 1,800.89 582.44 181.71 2,500,009.66 214,428.66 3.84 608.58 2,150.00 47.32 20.54 1,977.98 1,817.98 599.52 188.13 2,500,026.58 214,435.50 3.58 626.67 2,175.00 48.11 20.57 1,994.80 1,834.80 616.84 194.62 2,500,043.73 214,442.42 3.16 645.02 2,200.00 48.90 20.39 2.011.36 1,851.36 634.38 201.17 2,500,061.11 214,449.39 3.21 663.59 2,225.00 49.97 20.56 2,027.62 1,867.62 652.17 207.82 2,500,078.73 214,456.47 4.31 682.43 2,250.00 50.81 20.50 2,043.56 1,883.56 670.21 214.57 2,500,096.60 214,463.66 3.37 701.54 2,275.00 51.66 20.55 2,059.21 1,899.21 688.46 221.41 2,500,114.68 214,470.94 3.40 720.87 2,300.00 52.72 20.58 2,074.54 1,914.54 706.96 228.35 2,500,133.00 214,478.33 4.24 740.46 2,325.00 53.55 20.59 2,089.54 1,929.54 725.68 235.38 2,500,151.55 214,485.81 3.32 760.30 2,350.00 54.54 20.61 2,104.22 1,944.22 744.62 242.50 2,500,170.31 214,493.39 3.96 780.37 2,375.00 55.42 20.54 2,118.56 1,958.56 763.79 249.69 2,500,189.30 214,501.06 3.53 800.68 2,400.00 56.40 20.12 2,132.57 1,972.57 783.20 256.89 2,500,208.53 214,508.72 4.16 821.22 2,425.00 57.17 19.80 2,146.27 1,986.27 802.86 264.02 2,500,228.01 214,516.34 3.26 842.D0 2,450.00 57.81 19.40 2,159.71 1,999.71 822.72 271.10 2,500,247.69 214,523.89 2.89 862.95 2,475.00 58.03 19.02 2.172.98 2,012.98 842.73 278.07 2,500,267.52 214,531.35 1.56 884.02 2,500.00 58.04 18.78 2,186.22 2,026.22 862.79 284.94 2,500,287.41 214,538.70 0.82 905.12 2,525.00 58.00 18.62 2,199.46 2,039.46 882.88 291.74 2,500,307.32 214,545.99 0.57 926.23 2,550.00 57.94 18.12 2,212.72 2,052.72 902.99 298.41 2,500,327.27 214,553.16 1.71 947.34 2,575.00 57.96 17.88 2,225.98 2,065.98 923.15 304.96 2,500,347.25 214,560.20 0.82 968.46 2,600.00 57.67 17.41 2,239.30 2,079.30 943.31 311.38 2,500,367.25 214,567.10 1.97 989.55 2,625.00 57.51 17.06 2,252.70 2,092.70 963.47 317.63 2,500,387.25 214,573.85 1.34 1,010.61 2,650.00 57.39 16.75 2,266.15 2,106.15 983.63 323.76 2,500,407.26 214,580.46 1.15 1,031.64 2,675.00 57.51 16.68 2,279.60 2,119.60 1,003.81 329.82 2,500,427.29 214,587.01 0.53 1,052.67 211 712 01 7 10:10.18AM Page 5 COMPASS 5000.1 Build 81 HALLIBURTON Database: Company: Project: Site: Well: Wellbore: Design: Planned Survey Measured Depth (usft) 2,700.00 2,725.00 2,750.00 2,775.00 2,800.00 2,825.00 2,850.00 2,875.00 2,900.00 2,925.00 2,950.00 2,975.00 3,000.00 3,072.86 3,168.71 3,260.90 3,357.21 3,449.22 3,547.59 3,643.09 3,738.50 3,831.92 3,927.73 4,023.52 4,117.41 4,210.85 4,305.63 4,401.60 4,497.82 4,590.07 4,686.07 4,780.89 4,873.99 4,970.50 5,066.34 5,160.45 5,255.33 5,350.76 5,444.12 5,539.18 5,633.32 5,728.34 5,823.77 5,919.03 6,013.63 Sperry EDM - NORTH US + CANADA Hilcorp Alaska, LLC McArthur River Steelhead TBU M-06 Plan: M-06RD M-06RD WP04 Inclination 57.55 57.68 57.48 57.46 57.38 57.36 57.43 57.42 57.47 57.61 57.48 57.22 57.28 57.06 56.93 56.93 56.94 56.50 56.36 56.22 56.95 57.24 56.90 56.94 57.11 56.76 56.57 56.35 56.46 56.45 56.11 56.39 56.04 56.37 54.46 54.41 54.31 54.32 54.33 54.17 54.42 54.59 54.52 54.42 54.20 Azimuth 16.29 16.17 16.01 15.99 16.13 16.34 16.62 17.00 17.13 17.28 17.59 17.73 17.69 17.84 19.17 19.25 19.37 19.50 20.67 21.20 21.71 20.45 19.67 19.24 18.68 18.65 18.38 18.19 17.98 17.98 17.62 17.80 18.60 18.84 18.87 19.02 18.18 18.69 20.27 21.09 20.75 20.87 21.26 20.51 20.29 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well TBU M-06 - Slot B2-06 TBU M-6 Q 160.00usft TBU M-6 @ 160.00usft True Minimum Curvature Vertical Map Map Depth TVDss +N/ -S +E/ -W Northing Easling DLS Vert Section (usft) Usti (usft) (usft) (usft) (usft) 2,133.02 2,293.02 2,133.02 1,024.04 335.80 2,500,447.36 214,593.49 1.33 1,073.73 2,306.41 2,146.41 1,044.31 341.70 2,500,467.48 214,599.89 0.66 1,094.81 2,319.82 2,159.82 1,064.58 347.55 2,500,487.61 214,606.23 0.97 1,115.89 2,333.26 2,173.26 1,084.85 353.36 2,500,507.72 214,612.53 0.10 1,136.94 2,346.72 2,186.72 1,105.09 359.19 2,500,527.82 214,618.85 0.57 1,157.98 2,360.20 2,200.20 1,125.30 365.08 2,500,547.88 214,625.23 0.71 1,179.01 2,373.67 2,213.67 1,145.50 371.05 2,500,567.93 214,631.69 0.98 1,200.04 2,387.13 2,227.13 1,165.67 377.14 2,500,567.94 214,638.28 1.28 1,221.06 2,400.59 2,240.59 1,185.81 383.33 2,500,607.92 214,644.95 0.48 1,242.09 2,414.00 2,254.00 1,205.96 389.57 2,500,627.92 214,651.68 0.75 1,263.13 2,427.42 2,267.42 1,226.09 395.89 2,500,647.88 214,658.49 1.17 1,284.17 2,440.91 2,280.91 1,246.14 402.27 2,500,667.78 214,665.36 1.14 1,305.16 2,454.43 2,294.43 1,266.17 408.67 2,500,687.64 214,672.25 0.28 1,326.12 2,493.93 2,333.93 1,324.48 427.35 2,500,745.47 214,692.34 0.35 1,387.15 2,546.15 2,386.15 1,400.70 452.86 2,500,821.05 214,719.71 1.17 1,467.19 2,596.45 2,436.45 1,473.65 478.28 2,500,893.36 214,746.90 0.07 1,544.03 2,649.00 2,489.00 1,549.83 504.97 2,500,968.86 214,775.44 0.10 1,624.29 2,699.48 2,539.48 1,622.36 530.56 2,501,040.75 214,802.80 0.49 1,700.76 2,753.88 2,593.88 1,699.34 558.71 2,501,117.02 214,832.81 1.00 1,782.14 2,806.88 2,646.88 1,773.54 587.09 2,501,190.50 214,863.00 0.48 1,860.86 2,859.42 2,699.42 1,847.66 616.22 2,501,263.88 214,893.93 0.89 1,939.69 2,910.18 2,750.18 1,920.84 644.43 2,501,336.36 214,923.91 1.17 2,017.38 2,962.26 2,802.26 1,996.38 672.02 2,501,411.20 214,953.33 0.77 2,097.23 3,014.54 2,854.54 2,072.06 698.75 2,501,486.20 214,981.91 0.38 2,177.02 3,065.64 2,905.64 2,146.55 724.34 2,501,560.05 215,009.31 0.53 2,255.39 3,116.62 2,956.62 2,220.74 749.40 2,501,633.60 215,036.17 0.38 2,333.35 3,168.71 3,008.71 2,295.82 774.55 2,501,708.05 215,063.14 0.31 2,412.20 3,221.73 3,061.73 2,371.78 799.64 2,501,783.37 215,090.09 0.28 2,491.88 3,274.97 3,114.97 2,447.96 824.52 2,501,858.93 215,116.82 0.21 2,571.75 3,325.95 3,165.95 2,521.09 848.26 2,501,931.45 215,142.33 0.01 2,648.37 3,379.24 3,219.24 2,597.12 872.67 2,502,006.86 215,168.59 D.47 2,727.96 3,431.92 3,271.92 2,672.22 896.65 2,502,081.36 215,194.40 0.33 2,806.56 3,483.70 3,323.70 2,745.73 920.82 2,502,154.25 215,220.35 0.81 2,883.65 3,537.38 3,377.38 2,821.69 946.56 2,502,229.56 215,247.94 0.40 2,963.49 3,591.78 3,431.78 2,896.36 972.06 2,502,303.58 215,275.25 1.99 3,042.01 3,646.51 3,486.51 2,968.76 996.91 2,502,375.36 215,301.86 0.14 3,118.19 3,701.80 3,541.80 3,041.84 1,021.50 2,502,447.82 215,328.23 0.73 3,194.96 3,757.47 3,597.47 3,115.38 1,046.02 2,502,520.73 215,354.53 0.43 3,272.15 3,811.91 3,651.91 3,186.87 1,071.31 2,502,591.59 215,381.56 1.37 3,347.54 3,867.45 3,707.45 3,259.05 1,098.55 2,502,663.07 215,410.56 0.72 3,424.03 3,922.39 3,762.39 3,330.45 1,125.84 2,502,733.79 215,439.59 0.40 3,499.79 3,977.57 3,817.57 3,402.77 1,153.33 2,502,805.41 215,468.83 0.21 3,576.48 4,032.91 3,872.91 3,475.32 1,181.27 2,502,877.26 215,498.53 0.34 3,653.50 4,088.27 3,928.27 3,547.75 1,208.91 2,502,948.99 215,527.93 0.65 3,730.34 4,143.46 3,983.46 3,619.76 1,235.69 2,503,020.33 215,556.46 0.30 3,806.57 211712017 10:10:16AM Page 6 COMPASS 5000.1 Build 81 HALLIBURTON Database: Sperry EDM - NORTH US+CANADA Company: Hill Alaska, LLC Project: McArthur River Site: Steelhead Well: TBU M-06 Wellbore: Plan: M-06RD Design: M-06RD WP04 I Planned Survey Measured Map Vertical Depth Inclination Azimuth Depth TVDss (usft) (•) (•) (usfl) daft 6,108.41 54.80 19.40 4,198.50 4,038.50 6,202.60 54.36 19.55 4,25309 4,093.09 6,296.40 54.52 19.64 4,307.64 4,147.64 6,390.16 54.49 19.97 4,362.08 4,202.08 6,487.39 54.32 20.99 4,418.67 4,258.67 6,582.05 54.28 20.16 4,473.91 4,313.91 6,676.15 54.56 20.11 4,528.66 4,368.66 6,771.75 54.47 20.06 4,584.15 4,424.15 6,865.97 54.42 19.21 4,638.94 4,478.94 6,961.34 54.38 19.33 4,694.46 4,534.46 7,056.06 54.29 18.79 4,749.69 4,589.69 7,149.76 54.28 18.21 4,804.38 4,644.36 7,246.02 54.14 16.48 4,860.68 4,700.68 7,300.00 54.23 16.59 4,892.27 4,732.27 Start Dir 12.3°/100': 7300' MD, 4892.27'TVD : 60° LT TF 7,317.00 55.29 14.39 4,902.08 4,742.08 End Dir : 7317' MD, 4902.08' TVD 1.47 4,802.62 7,400.00 55.29 14.39 4,949.34 4,789.34 7,437.00 55.29 14.39 4,970.41 4,810.41 Start Dir4°/100' : 7437' MD, 4970.4l'TVD 1,603.69 7,500.00 52.79 14.03 5,007.40 4,847.40 7,600.00 48.82 13.40 5,070.59 4,910.59 7,700.00 44.85 12.70 5,138.98 4,978.98 7,800.00 40.89 11.89 5,212.26 5,052.26 7,900.00 36.93 10.93 5,290.06 5,130.06 8,000.00 32.99 9.79 5,371.99 5,211.99 8,100.00 29.05 8.37 5,457.68 5,297.68 8,200.00 25.14 6.56 5,546.68 5,386.68 8,300.00 21.26 4.13 5,638.58 5,476.58 8,400.00 17.42 0.68 5,732.93 5,572.93 8,500.00 13.68 355.38 5,829.25 5,669.25 8,516.56 13.07 354.22 5,845.36 5,685.36 End Dir : 8516.56' MD, 5845.36' TVD 5,483.91 5,263.48 8,600.00 13.07 354.22 5,926.64 5,766.64 8,700.00 13.07 354.22 6,024.05 5,864.05 8,800.00 13.07 354.22 6,121.46 5,961.46 8,900.00 13.07 354.22 6,218.87 6,058.87 9,000.00 13.07 354.22 6,316.28 6,156.28 9,100.00 13.07 354.22 6,413.69 6,253.69 9,200.00 13.07 354.22 6,511.09 6,351.09 9,300.00 13.07 354.22 6,608.50 6,448.50 9,400.00 13.07 354.22 6,705.91 6,545.91 9,500.00 13.07 354.22 5,803.32 6,643.32 9,600.00 13.07 354.22 6,900.73 6,740.73 9,700.00 13.07 354.22 6,998.14 6,838.14 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well TBU M-06 - Slot B2-06 TBU M-6 @ 160.00usft TBU M-6 @ 160.00usft True Minimum Curvature 2/172017 10:10:18AM Page 7 COMPASS 5000.1 Build 81 Map Map +N/ -S +E/ -W Northing Easling DLS Vert Section (usft) (usft) (usft) (usft) 4,038.50 3,592.34 1,261.88 2,503,092.25 215,584.41 0.99 3,883.22 3,764.71 1,287.47 2,503,163.97 215,611.76 0.48 3,959.52 3,836.59 1,313.06 2,503,235.21 215,639.10 0.19 4,035.36 3,908.41 1,338.93 2,503,306.36 215,666.71 0.29 4,111.20 3,982.48 1,366.59 2,503,379.74 215,696.17 0.87 4,189.63 4,054.45 1,393.60 2,503,451.03 215,724.93 0.71 4,265.87 4,126.30 1,419.95 2,503,522.22 215,753.02 0.30 4,341.85 4,199.41 1,446.68 2,503,594.65 215,781.53 0.10 4,419.14 4,271.61 1,472.44 2,503,666.20 215,809.05 0.74 4,495.31 4,344.81 1,498.03 2,503,738.75 215,836.42 0.11 4,572.43 4,417.54 1,523.16 2,503,810.85 215,863.31 0.47 4,648.99 4,489.69 1,547.30 2,503,882.38 215,889.21 0.50 4,724.75 4,564.21 1,570.58 2,503,956.32 215,914.30 1.47 4,802.62 4,606.18 1,583.04 2,503,997.97 215,927.77 0.23 4,846.32 4,619.56 1,586.74 2,504,011.25 215,931.80 12.30 4,860.19 4,685.65 1,603.69 2,504,076.91 215,950.37 0.00 4,928.41 4,715.11 1,611.25 2,504,106.18 215,958.64 0.00 4,958.82 4,764.54 1,623.77 2,504,155.29 215,972.36 4.00 5,009.80 4,839.81 1,642.15 2,504,230.09 215,992.57 4.00 5,087.28 4,910.85 1,658.63 2,504,300.70 216,010.78 4.00 5,160.21 4,977.30 1,673.12 2,504,366.78 216,026.89 4.00 5,228.22 5,038.85 1,685.57 2,504,428.01 216,040.84 4.00 5,290.98 5,095.20 1,695.90 2,504,484.09 216,052.54 4.00 5,348.20 5,146.07 1,704.07 2,504,534.75 216,061.95 4.00 5,399.59 5,191.22 1,710.03 2,504,579.73 216,069.01 4.00 5,444.90 5,230.42 1,713.77 2,504,618.83 216,073.70 4.00 5,483.91 5,263.48 1,715.25 2,504,651.84 216,075.99 4.00 5,516.44 5,290.24 1,714.48 2,504,678.62 216,075.87 4.00 5,542.31 5,294.06 1,714.13 2,504,682.44 216,075.62 4.00 5,545.94 5,312.84 1,712.23 2,504,701.26 216,074.18 0.00 5,563.79 5,335.34 1,709.96 2,504,723.81 216,072.45 0.00 5,585.17 5,357.84 1,707.68 2,504,746.36 216,070.73 0.00 5,606.55 5,380.34 1,705.40 2,504,768.91 216,069.00 0.00 5,627.94 5,402.85 1,703.13 2,504,791.46 216,067.27 0.00 5,649.32 5,425.35 1,700.85 2,504,814.01 216,065.55 0.00 5,670.70 5,447.85 1,698.58 2,504,836.56 216,063.82 0.00 5,692.08 5,470.35 1,696.30 2,504,859.11 216,062.10 0.00 5,713.47 5,492.86 1,694.02 2,504,881.67 216,060.37 0.00 5,734.85 5,515.36 1,691.75 2,504,904.22 216,058.64 0.00 5,756.23 5,537.86 1,689.47 2,504,926.77 216,056.92 0.00 5,777.61 5,560.36 1,687.20 2,504,949.32 216,055.19 0.00 5,799.00 2/172017 10:10:18AM Page 7 COMPASS 5000.1 Build 81 HALLIBURTON Database: Sperry EDM - NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: McArthur River Site: Steelhead Well: TBU M-06 Wellbore: Plan: M-06RD Design: M-06RD WP04 Planned Survey Measured Well TBU M-06 - Slot B2-06 TVD Reference: Vertical Depth Inclination Azimuth Depth (usft) (°) (°) (usft) 9,800.00 13.07 354.22 7,095.55 9,900.00 13.07 354.22 7,192.96 10,000.00 13.07 354.22 7,290.36 10,100.00 13.07 354.22 7,387.77 10,200.00 13.07 354.22 7,485.18 10,300.00 13.07 354.22 7,582.59 10,400.00 13.07 354.22 7,680.00 10,500.00 13.07 354.22 7,777.41 10,604.70 13.07 354.22 7,879.39 Start Dir 4°/100' : 10604.7' MD, 7879.39'TVD 7,325.18 10,700.00 9.61 345.99 7,972.83 10,800.00 6.42 328.29 8,071.85 10,900.00 4.68 289.86 8,171.41 11,000.00 5.88 247.18 8,271.02 11,100.00 8.90 226.22 8,370.20 11,200.00 12.48 216.44 8,468.45 11,300.00 16.25 211.06 8,565.31 11,382.68 19.44 208.17 8,644.00 COAL39 5,992.45 7,812.83 5,782.39 11,400.00 20.11 207.68 8,660.30 11,500.00 24.02 205.36 8,752.96 11,600.00 27.95 203.65 8,842.84 11,700.00 31.90 202.34 8,929.49 11,800.00 35.85 201.29 9,012.50 11,827.96 36.96 201.03 9,035.00 HIX_FW 6,022.98 8,210.20 5,793.45 11,876.12 38.87 200.62 9,073.00 COAL59 8,308.45 5,779.40 1,620.96 11,887.72 39.33 200.52 9,082.00 HTKE-FW 5,758.71 1,607.32 2,505,149.56 11,900.00 39.82 200.42 9,091.46 11,932.25 41.10 200.17 9,116.00 HK2T 5,949.46 8,500.30 5,731.49 12,0OO.DO 43.79 199.69 9,165.99 12,100.00 47.76 199.05 9,235.73 12,200.00 51.74 198.50 9,300.33 12,300.00 55.72 197.99 9,359.48 12,400.00 59.70 197.54 9,412.89 12,500.00 63.68 197.12 9,460.31 12,600.00 67.67 196.73 9.501.49 12,700.00 71.65 196.36 9,536.25 12,784.03 75.00 196.06 9,560.35 End Dir :12784.03' MD, 9560.35' TVD 12,800.00 75.00 196.06 9.564.49 12,900.00 75.00 196.06 9,590.37 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well TBU M-06 - Slot B2-06 TVD Reference: TBU M-6 @ 16(1 MD Reference: TBU Moi @ 160.00usft North Reference: True Survey Calculation Method: Minimum Curvature 9,404.49 4,790.35 1,267.03 2,504,189.79 215,616.36 0.00 4,953.21 9,430.37 4,697.52 1,240.31 2,504,097.65 215,587.38 0.00 4,856.74 211712017 10:10:1 BAM Page 8 COMPASS 5000.1 Build 81 Map Map TVDss +NIS +E/.W Northing Easting DLS Vert Section usft (usft) (usft) (usft) (usft) 6,935,55 6,935.55 5,582.87 1,684.92 2,504,971.87 216,053.47 0.00 5,820.38 7,032.96 5,605.37 1,682.65 2,504,994.42 216,051.74 0.00 5,841.76 7,130.36 5,627.87 1,680.37 2,505,016.97 216,050.01 0.00 5,863.15 7,227.77 5,650.37 1,678.09 2,505,039.52 216,048.29 0.00 5,884.53 7,325.18 5,672.88 1,675.82 2,505,062.08 216,046.56 0.00 5,905.91 7,422.59 5,695.38 1,673.54 2,505,084.63 216,044.84 0.00 5,927.29 7,520.00 5,717.88 1,671.27 2,505,107.18 216,043.11 0.00 5,948.68 7,617.41 5,740.38 1,668.99 2,505,129.73 216,041.38 0.00 5,970.06 7,719.39 5,763.94 1,666.61 2,505,153.34 216,039.58 0.00 5,992.45 7,812.83 5,782.39 1,663.60 2,505,171.86 216,037.02 4.00 6,009.72 7,911.85 5,795.25 1,658.63 2,505,184.83 216,032.37 4.00 6,021.10 8,011.41 5,801.40 1,651.85 2,505,191.14 216,025.74 4.00 6,025.53 8,111.02 5,800.80 1,643.29 2,505,190.75 216,017.16 4.00 6,022.98 8,210.20 5,793.45 1,632.97 2,505,183.66 216,006.67 4.00 6,013.47 8,308.45 5,779.40 1,620.96 2,505,169.91 215,994.33 4.00 5,997.04 8,405.31 5,758.71 1,607.32 2,505,149.56 215,980.18 4.00 5,973.78 8,484.00 5,736.67 1,594.85 2,505,127.82 215,967.18 4.00 5,949.46 8,500.30 5,731.49 1,592.10 2,505,122.71 215,964.30 4.00 5,943.79 8,592.96 5,697.85 1,575.39 2,505,089.50 215,946.78 4.00 5,907.22 8,682.84 5,657.98 1,557.27 2,505,050.08 215,927.68 4.00 5,864.26 8,769.49 5,612.06 1,537.82 2,505,004.65 215,907.12 4.00 5,815.10 8,852.50 5,560.32 1,517.13 2,504,953.43 215,885.18 4.00 5,760.00 8,875.00 5,544.85 1,511.14 2,504,938.11 215,878.81 4.00 5,743.57 8,913.00 5,517.18 1,500.62 2,504,910.71 215,867.62 4.00 5,714.23 8,922.00 5,510.33 1,498.05 2,504,903.92 215,864.89 4.00 5,706.97 8,931.46 5,503.01 1,495.32 2,504,896.66 215,861.97 4.00 5,699.21 8,956.00 5,483.38 1,488.06 2,504,877.22 215,854.24 4.00 5,678.45 9,005.99 5,440.40 1,472.48 2,504,834.63 215,837.61 4.00 5,633.04 9,075.73 5,372.81 1,448.73 2,504,767.64 215,812.22 4.00 5,561.80 9,140.33 5,300.56 1,424.18 2,504,696.01 215,785.91 4.00 5,485.85 9,199.48 5,224.00 1,398.95 2,504,620.10 215,758.82 4.00 5,405.55 9,252.89 5,143.51 1,373.17 2,504,540.26 215,73109 4.00 5,321.30 9,300.31 5,059.49 1,346.96 2,504,456.90 215,702.83 4.00 5,233.50 9,341.49 4,972.33 1,320.44 2,504,370.41 215,674.20 4.00 5,142.59 9,376.25 4,882.46 1,293.76 2,504,281.23 215,645.33 4.00 5,049.00 9,400.35 4,805.17 1,271.30 2,504,204.51 215,620.99 4.00 4,968.62 9,404.49 4,790.35 1,267.03 2,504,189.79 215,616.36 0.00 4,953.21 9,430.37 4,697.52 1,240.31 2,504,097.65 215,587.38 0.00 4,856.74 211712017 10:10:1 BAM Page 8 COMPASS 5000.1 Build 81 HALLIBURTON Database: Sperry EDM - NORTH US +CANADA Company: Hilcorp Alaska, LLC Project: McArthur River Site: Steelhead Well: TBU M-06 Wellbore: Plan: M-06RD Design: M-06RD WP04 Planned Survey Halliburton Standard Proposal Report Local Co-ordinate Reference: Well TBU M-06 - Slot B2-06 TVD Reference: TBU M-6 @ 160.00usft MD Reference: TBU M-6 @ 160.00usft North Reference: True Survey Calculation Method: Minimum Curvature Measured Map Map Vertical +El -W Depth Inclination Azimuth Depth TVDss +NIS (usft) V) (1) (usft) usft (usft) 13,000.00 75.00 196.06 9,616.25 9,456.25 4,604.70 13,084.03 75.00 196.06 9,638.00 9,478.00 4,526.70 Start Dir 5-1100': 13084.03' MD, 9638'TVD - WF1 - M-06RD WP04 W F1 Tilt 1 13,100.00 75.80 196.06 9,642.03 9,482.03 4,511.85 13,116.45 76.62 196.06 9,645.95 9,485.95 4,496.50 M-06RD WP01 WF1 Rough Tgtt 2,503,819.96 215,500.06 5.00 13,175.31 79.56 196.06 9,658.09 9,498.09 4,441.16 M-06RD WP03 EPT Tgt 215,470.29 0.00 4,466.87 1,104.84 13,179.94 79.80 196.06 9,658.92 9,498.92 4,436.78 TBU M-29RD2 wags WF3 Tgt3 4,268.23 1,049.82 2,503,440.71 13,200.00 80.80 196.06 9,662.30 9,502.30 4,417.78 13,263.06 83.95 196.06 9,670.67 9,510.67 4,357.72 End Dir :13263.011 9670.67' TVD 2,503,156.12 215,291.31 13,300.00 83.95 196.06 9,674.56 9,514.56 4,322.42 13,400.00 83.95 196.06 9,685.10 9,525.10 4,226.86 13,500.00 83.95 196.06 9,695.63 9,535.63 4,131.29 13,600.00 83.95 196.06 9,706.17 9,546.17 4,035.73 13,700.00 83.95 196.06 9,716.71 9,556.71 3,940.17 13,800.00 83.95 196.06 9.727.24 9,567.24 3,844.60 13,900.00 83.95 196.06 9,737.78 9,577.78 3,749.04 13,959.04 83.95 196.06 9,744.00 9,584.00 3,692.62 WF2 215,052.66 0.00 3,076.35 719.74 2,502,302.35 14,000.00 83.95 196.06 9,748.32 9,588.32 3,653.48 14,100.00 83.95 196.06 9,758.85 9,598.85 3,557.91 14,200.00 83.95 196.06 9,769.39 9,609.39 3,462.35 14,300.00 83.95 196.06 9,779.93 9,619.93 3,366.79 14,400.00 83.95 196.06 9,790.46 9,630.46 3,271.22 14,500.00 83.95 196.06 9,801.00 9,641.00 3,175.66 14,600.00 83.95 196.06 9,811.54 9,651.54 3,080.10 14,625.95 83.95 196.06 9,814.27 9,654.27 3,055.30 TBU M-29RD2 wags WF2 Tgt2 14,700.00 83.95 196.06 9,822.07 9,662.07 2,984.53 14,800.00 83.95 196.06 9,832.61 9,672.61 2,888.97 14,900.00 83.95 196.06 9,843.15 9,683.15 2,793.41 15,000.00 83.95 196.06 9,853.68 9,693.68 2,697.84 15,100.00 83.95 196.06 9,864.22 9,704.22 2,602.28 15,131.83 83.95 196.06 9,867.57 9,707.57 2,571.86 TBU M-29RD2 wp06 WF1 Tgtt 15,200.00 83.95 196.06 9,874.76 9,714.76 2,506.72 15,268.75 83.95 196.06 9,882.00 9,722.00 2,441.02 WF3 - M-06RD WP04 WF3 Tgt 2 15,300.00 83.95 196.06 9,885.29 9,725.29 2,411.15 15,400.00 83.95 196.06 9,895.83 9,735.83 2,315.59 15,500.00 83.95 196.06 9,906.37 9,746.37 2,220.03 211712017 10: f0:18AM Page 9 COMPASS 5000.1 Build 81 Map Map +El -W Northing Seating DLS Vert Section (usft) (usft) (usft) 9,456.25 1,213.59 2,504,005.51 215,558.41 0.00 4,760.26 1,191.14 2,503,928.08 215,534.06 0.00 4,679.19 1,186.87 2,503,913.34 215,529.42 5.00 4,663.75 1,182.45 2,503,898.10 215,524.63 5.00 4,647.80 1,166.52 2,503,843.17 215,507.36 5.00 4,590.29 1,165.26 2,503,838.82 215,505.99 5.00 4,585.73 1,159.79 2,503,819.96 215,500.06 5.00 4,565.98 1,142.50 2,503,760.34 215,481.31 5.00 4,503.56 1,132.34 2,503,725.30 215,470.29 0.00 4,466.87 1,104.84 2,503,630.43 215,440.46 0.00 4,367.55 1,077.33 2,503,535.57 215,410.63 0.00 4,268.23 1,049.82 2,503,440.71 215,380.80 0.00 4,168.90 1,022.32 2,503,345.85 215,350.97 0.00 4,069.58 994.81 2,503,250.98 215,321.14 0.00 3,970.26 967.30 2,503,156.12 215,291.31 0.00 3,870.93 951.06 2,503,100.12 215,273.70 0.00 3,812.30 939.80 2,503,061.26 215,261.48 0.00 3,771.61 912.29 2,502,966.39 215,231.65 0.00 3,672.29 884.78 2,502,871.53 215,201.82 0.00 3,572.96 857.28 2,502,776.67 215,171.98 0.00 3,473.64 829.77 2,502,681.81 215,142.15 0.00 3,374.32 802.26 2,502,586.94 215,112.32 0.00 3,274.99 774.75 2,502,492.08 215,082.49 0.00 3,175.67 767.62 2,502,467.46 215,074.75 0.00 3,149.89 747.25 2,502,397.22 215,052.66 0.00 3,076.35 719.74 2,502,302.35 215,022.83 0.00 2,977.02 692.23 2,502,207.49 214,993.00 0.00 2,877.70 664.73 2,502,112.53 214,963.17 0.00 2,778.38 637.22 2,502,017.77 214,933.34 0.00 2,679.05 628.47 2,501,987.57 214,923.84 0.00 2,647.44 609.71 2,501,922.90 214,903.51 0.00 2,579.73 590.80 2,501,857.69 214,883.00 0.00 2,511.45 582.21 2,501,828.04 214,873.68 0.00 2,480.41 554.70 2,501,733.18 214,843.85 0.00 2,381.08 527.19 2,501,638.32 214,814.01 0.00 2,281.76 211712017 10: f0:18AM Page 9 COMPASS 5000.1 Build 81 HALLIBURTON Halliburton Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well TBU M-06 - Slot 132-06 Company: Hilcorp Alaska, LLC TVD Reference: TBU M-6 @ 160.00usft Project: McArthur River MD Reference: TBU M-6 @ 160.00usft Site: Steelhead North Reference: True Well: TBU M-06 Survey Calculation Method: Minimum Curvature Wellbore: Plan: M-06RD Design: M-06RD WP04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (°) (') (usft) usft (usft) (usft) (usft) (usft) 9,756.38 15,595.00 83.95 196.06 9,916.38 9,756.38 2,129.24 501.06 2,501,548.20 214,785.68 0.00 2,187.40 j Total Depth: 15595'MD, 99161 -7" z 8112" Targets Target Name -hltlmiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Seating -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) M-06RD WP04 WF3 Tgt 2 0.00 0.00 9,882.00 2,441.02 590.80 2,501,857.69 214,883.00 j - plan hits target center - Point M-06RD WP04 WF1 Tgt 1 0.00 0.00 9,638.00 4,526.70 1,191.14 2,503,928.08 215,534.06 - plan hits target center I -Circle (radius 50 00) Cacing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 15,595.00 9,916.38 7" x B 1/2" 7 B-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (°) V) 11,887.72 9,082.00 HTKE-FW 11,382.68 8,644.00 COAL39 11,876.12 9,073.00 COAL59 11,932.25 9,116.00 HK2T 13,084.03 9,638.00 WF1 11,827.96 9,035.00 H1X_FW 15,268.75 9,882.00 WF3 13,959.04 9,744.00 WF2 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NIS +Fl -W (usft) (usft) (usft) (usft) Comment 7,30000 4,892.27 4,606.18 1,583.04 Start Dir 12.3°/100': 7300'MD, 4891: 60°LTTF 7,317.00 4,902.08 4,619.56 1,586.74 End Dir : 7317' MD, 4902.08' TVD 7,437.00 4,970.41 4,715.11 1,611.25 Start Dir 0/100' : 7437' MD, 4970.4l'TVD 8,516.56 5,845.36 5,294.06 1,714.13 End Dir : 8516.56' MD, 5845.36' TVD 10,604.70 7,879.39 5,763.94 1,666.61 Start Dir 4°/100': 10604.7'MD, 7879.39'TVD 12,784.03 9,560.35 4,805.17 1,271.30 End Dir : 12784.03' MD, 9560.35' TVD 13,084.03 9,638.00 4,526.70 1,191.14 Start Dir 5-/100': 13084.03' MD, 9638'TVD 13,263.06 9,670.67 4,357.72 1,142.50 End Dir : 13263.06' MD, 9670.67' TVD 15,595.00 9,916.38 2,129.24 501.06 Total Depth: 15595'MD, 9916.38TVD 2/17201710:10:1 BAM Page 10 COMPASS 5000.1 Build 81 Hilcorp Alaska, LLC McArthur River Steelhead TBU M-06 Plan: M-06RD M-06RD WP04 Sperry Drilling Services Clearance Summary Anticollision Report 17 February, 2017 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: Sternen! -TRU M416 - Plan: M46RD -Md6RD Wage Well Coordinates: 2,099,431.63 N, 214,23290E @0.49.541.29" N,151.36.05.54- W) Datum Height: TRU li@160.DDuaR Soon Range: 7.300.00 to 15,595.00 usft. Measured Depth. Scan Radius Is 1,759.50 raft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation Is Unlimited Geodetic Scala Factor Applied Version: 5000.1 Build: 61 Scan Type: GLOBAL FILTER APPLIED. All .11palhs x4min 20911OW1000 of reference Scan Type: 2500 lar_«I �_1■lc� i-� o I Sperry Drilling Services HALLIBURTON Anticollision Report for TBU M-06 - M-06RD WP04 Hileorp Alaska, LLC McArthur River ClosestApproach 3D ProxlmRy Scan on Cannot Survey Data (North Reference) 13,601.BB 813.50 13,601.88 Rotor... Design: sbeiheaM -TSD M46 -Plan: M46RD - M46RD WP04 10,164.00 5.D02 Centre Dlabnce Pass - Scan Rro,r: 7,300.00 d 15,595.00 mea. Measurer) Depth. 13,650.00 815.00 13,650.00 Scan Retltos Is 1,769.50 was. Clearance Factor cudR is Unlimited. Max Ellipse Separation is Unlimited 10,164.00 5.007 Ellipse Separation Measured Minimum @abacureM Ellipse @Measured Clearance Summary Based on Sib Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name- Wellborn Name -Denied (milt) (usa) (malt) iasai usR Grayling G -04 -G04 -G-04 13,601.BB 813.50 13,601.88 653.50 10,164.00 5.D02 Centre Dlabnce Pass - G -04 -G -04-G-04 13,650.00 815.00 13,650.00 652.25 10,164.00 5.007 Ellipse Separation Pass - G -04 -G -04-G-04 13,75D.00 826.96 13,750.00 65997 10.164.00 4.952 Clearance Factor Pasa- G-04-G-04RD-G-04RD 14,275.00 481.62 14.275.0 326.98 10,309.70 3.114 Clemance Factor PaSs- G-D4-G-04RD-G-04R0 14,375.00 464.80 14,375.0 318.93 10.32848 3.184 Ellipse Separation Pass - G-D4-G-04RD-G-04R0 14,408.40 463.95 14,406.40 32945 10,334.31 3.233 Centre Dlstarwe Pass- G06-G-0680-G-06RD 15,100.00 1,755.58 15,100.00 1,574.07 10,805.95 9715 Clearance Factor Pasa- G-06-G-06RD-G-0BRD 15,595.00 1,605.66 15,595.00 1,475.62 10,810.57 12.340 Ellipse Separation Pass - G -07 -G -W -G-67 15,595.00 677.14 15,595.00 504.30 10,383.45 3.918 Clearance Factor Pass - G -09 -G -09-G-09 7.300.00 1,276.28 7.300.00 1.156.92 6,221.30 10.693 Clearance Factor Paes- G-09-G-09 PB1-609 PR1 7,30900 1,276.28 7.30090 1,15616 6.221.30 10.679 Clearance Factor Pass- G09 -G09 PB2-G-09 PB2 7,3000D 1,276.28 7,300.00 1.156.92 6,221.30 10.693 Clearance Factor Paes- G-09-G-09 P83 -G-09 PB3 7,300.00 1,276.28 7.300.00 1.156.92 6,221.30 10.693 Clarence Factor Pass - G -09-G-09 Pad -G-09 Pad 7.3 ,OD 1,276.28 7,300.00 1,15B.92 6,221.30 10.693 Clearance Factor Pass - G-16-Gt6-G-16 7,300.DD 1,271.91 7.300.0 817.06 6,13D.92 2.801 Clearance Factor Pass- GiBDPN-G-18-G-10 7,30090 807.40 7,300.00 36399 6.344.08 1,821 Clearance Factor Pess- G-18DPN - G-18DPN - G-1 BDPN 7.30090 817.46 7,300.00 465.61 6,299]9 2.323 Clearance Factor Pace - G -20 -G -20-G-20 14,250.00 924.68 14,250.00 449.14 10.107.69 1.944 Clearance Factor Pasa- G-20-G-20-G20 14,375.00 897.97 14,375.00 440.65 10.197.41 1.964 Ellipse Separation Pass - G -20 -G -20-G20 14,500.37 888.07 14,508.37 448.61 10.207,78 2,021 Centre Distance Pass - G -21 RD -G -2I RD -G21 RD 15.500.00 1.344.05 15,500.00 1.158.19 10,701.80 7.231 Clearance Factor Pass- G.21RD-G-21 R0 -G-21 RD 15,59590 1,285.45 15.595.00 1,108.64 10,714.53 7.270 Ellipse Separmon Paes- G -25 -G -25-G25 G -25 -G -25-G-25 G -25 -G -25-G-25 - - - GJ2-GJ2-G-32 - - - G32 -"2-G-32 - - - G02 -G 2-G-02 17 Fsbrvary, 2017 - 11:40 Pass 2 s77 COMPASS Hilcorp Alaska, LLC HALLI B U RTO N McArthur River Anticollision Report for TBU M-06 - M-06RD WP04 Closest Approach 3D Proximity Scan on Current Survey Data (Hart Reference) Reference Design: Steelhead -TBU M -06 -Plan: M46RD -M46RD WP04 Scan Range: 7,300.00 to 15,59500 unit. assumed Depth. Scan Radius is 1,759.50 left. Clenonce Factor cutup is Unlimited. Max Elllpas Separation Is Unlimited Measuretl Minimum @Measured Ellipse @Measured Clearance Smarm., Based on aIle Name Dept Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Weitore Name - Design dot) (usRi (left) (raft) sen G33 - G43 - G-33 -- 33 -G33 -G-33 G-33 33-G33 G3,IRD 4RD-G34RD-G34RD 15,595.00 1,]26.42 15,595.00 1,35240 10.291.02 4.616 Clearance Factor Pass - King Salmon K -21 -K -21-K-21 K-21- K -21-K-21 K -21 -K -21-K-21 K -21-K-21 RD -K-21 RD K -21-K-21 RD -K-21 RD K -21-K-21 RD -K-21 RD K-25 (K-16) - K-25 - K-25 13,532.83 61905 13,532.83 500.82 13,553.86 5,236 Cen9e Distance Pass - K-25 (K-16) - K-25 - K-25 13.62500 622.61 13,625.00 497.68 13.616.43 4.984 Ellipse Separation Pass - K -25(K -16) -K -25-K-25 13,875.00 664.15 13,075.00 524.15 13.808.92 4.744 Clearance Facer Pass - Steelheed TBUM-06-h406-M-06 7,600.00 9.60 T,800.00 1.21 7,599.88 1.144 Clearance Facer Pasa- TBUM-07-MO7-M-07 7.30000 1,26907 7,30000 848.35 6,44DCD 3016 Clearance Factor Pass- TBUM-07-M-07-M-07 7130000 1.269.07 T,300.00 901.70 6.44000 3.454 Centre Distance Pass - TBU M -II -M -11-M-11 15.595.00 1.196.14 15,595.00 1,111.09 10.290.00 14.063 Clearance Factor Pase- TBUM-I2-M-12-M-12 11,77500 1,919.81 11,775.00 855.83 10.715.00 6.219 Clearance Factor Pass- TBUM-I2-M-12-M-12 12,350.00 904.56 12,35000 794.26 10,71500 7.518 Ellipse Separsrron Pass - TBUM-I2-M-12-M-12 12,575.81 893.65 12,575.81 796.59 10,71500 9.208 Centre Dletance Pasa- TBU M -14 -M14 -M-14 15,595.00 1.460.55 15,595.00 1,344.40 9,190.00 12.583 Clearance Factor Pass- TBUM-25-M-25-M-25 13,937.15 1,708.23 13.937.15 1.59249 10,74018 1059 Clearance Factor Pass - TBU M -25 -M -25-M-25 14,150.00 1,694.74 14.190.00 1.581.56 10,70000 14.974 Ellipse Separation Pass - TBU M -25 -M -25-M-25 14.17661 11694.53 14,176.61 1,581.69 10,70000 15.018 Centre Distance Paes- TBU M -28 -M -28-M-28 11846.76 SB2.85 11,646]6 414.83 10,879.23 3,469 Centra Distance Pass - TBU M -28 -M -26-M-28 11.6scea 582.85 11,850.00 414.80 10,880.50 3.468 Clearance Factor Pass- TBUM-28-Plan: M-28R0-M-28RDWP11 12,410.31 293.05 12,41031 148.25 11,23695 2.024 Ellipse Separation Pass- 1 ]FeOvary. 2017 - 11:40 Page 3 of 7 COMPASS HALLIBURTON Hilcorp Alaska, LLC McArthur River Anticollision Report for TBU M•06 - M-06RD WP04 Closest Approach SD Proslmit5 Scan on Cement Survey Data (Norte Reference) Reference Design: SMeIMad-TBU MAS -Plan: MASRD-hl WP04 Scan Range: 1,300.00 to 15,595.00 usR. Measured Depth. Scan Radius is 1,159.50 ush. Clearance Factor l utoS is Unlimited Max Ellipse Separation is Unlimited Measured Minimum saga asur.d Ellipse @Measured Clearence Summery Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warring Comparison Well Name -Waltham Nam. - Deslsn (usR) (usa) lusttl (usa) usR TBU M -20 -Plan: M-28RD - M-28RD WP11 12.425.00 293,34 12.425.00 14835 11.229.83 2023.Clearance Factor Pass - TBU M-29 - M-29 - M-29 15,225.00 611.42 15,225,00 555.77 10,459.00 5.569 Clearance Factor Pass - TBU M-29 - M-29 - M-29 15,235.14 67735 15,235.14 555.76 10,455]5 5.571 Ellipse Separation Pass - TBU W29 - M -29A - M -29A 13,775.00 2129D 13,115X0 8398 11,510.D9 1651 Clearance Factor Pass - TRU M -29 -M -29A -M -29A 13.825.00 20480 13,025.00 82.14 11,465.74 1.670 Ellipse Sarnwel n Pass- TBU M -29 -M -29A -M -29A 13,940.63 195.97 13,948.63 93.08 11,356.42 1919.Contra Dislance Pass- TBU 130 -M -30-M-30 10,321.19 182.75 10,321.19 591,80 10,07415 4,462 Centre Distance Pass - TBU M30 - M-30 - M-30 10,325.00 762.15 1D,325.00 591.7B 10,078.04 4,461 Ellipse SepareSon Pass - TBU M30 -M -30-M-30 10,350.00 762.91 10.350.00 591.04 10,099.61 4,460 Clearance Factor Pasa- TBU M 1 -M -31-M31 11,900.00 185]2 11,900.00 609.09 11,347.63 4.448 Clearance Fatter Pass- TBU M-31- M-31- M-31 11,950X0 111.58 11,950.00 603.2D 11,318.33 4.459 Ellipse Separation Pass- TBU 131 -M -31-M-31 12.304]0 155.12 12.304.10 614.16 11,058XD 5.357 Centre Distance Pass- TBU M31-M-31A-W31A 15,595.00 1,133.95 15,595.00 1.687AB 9,759.54 37.079 Clearance Factor Pass - T31J Wl - M-31 L1 -M41 L1 11,869.15 538.67 11.869.15 417.81 11,265,00 4,457 Clearance Factor Pass - TBU W2 - M-32 - M-32 13,315.00 238.46 13,375.00 B0.53 11,367.15 1.510 Clearance Factor Pass - TSU M32 -M -32-M-32 13,404.24 237.63 13,404.24 BLEB 11,346.14 1.524 Centre Distance Pass - TSU M32 -M-32 Pat -M32 P81 14,562.51 968.94 14.562.51 096.58 9,906XD 13.742 Centre Distance Pass- TBU M -32-M-32 Pat -M42 PB1 14,575.00 961.03 14,575.00 89641 9,906.OD 13.695 Ellipse Separation Pass - TRU M -32-M-32 Pat -M42 PB1 14,750.00 984.95 14,750.00 911,30 9,906.00 13.373 Clearance Factor Pass- TBU M32 -M32 PB2-M42 PB2 13,982.83 515.34 13,902.83 469.36 10,652X0 5.429 Ellipse Separation Pass - TBU M32 -M42 PB2-132 PB2 14,000.00 515.59 14,000.00 469.54 10,652.00 5.427 Clearance Factor Pass - TBUM32-M32 P83 -M32 PB3 13,375.00 23640 13,375.00 60.53 11,367.15 1.510 Clearance Factor Pass - TBU M-32-Md2 P33 -M32 PB3 13,404.24 23763 13,404.24 8166 11,346.14 1.524 Centre Distance Pass- TBU M-32-M32RD-M32RD 12,550.00 34612 12.550X0 165.81 12.047.84 1.907 Clearance Foods Pass - TBU M32-M32RD-M32RD 12,575.00 347.12 12.575.00 16585 12,02788 1.910 Ellipse Sepal Pasa- TBU M32-M-32RD-M-32RD 12,623.08 U7D5 12,623.08 167.2B 11,986.6D 1.931 Centre Distance Pass- TBU M32-M32RD Pal -M-32RD Pal 13,403.59 59028 13,403.59 49219 11,111.00 6,055 Ellipse Separation Pass- TBUM-32-M32RD PB1-M-32RD PBt 13,425.00 59066 13,425.00 493RD 11,111.0 BX4B Clearance Each, Pass - r1 Febmary, 2017 - 11:40 Page 4 of COMPASS HALLIBURTON Anticollision Report for TBU M-06 - M-06RD WP04 Survey tool nroaram From To SuiveylPlan survey Tool luanl luanl 109.09 3,000.00 NSG WL 3,072.66 7,3DODD MWD 7.300,01) 15.595.00 A-WR0 WP04 MWD'sc.sag Ellipse eaor terms are correlated across survey tool be -on points. Calculated ellipses incorporate sudaca armrs. Separation is Me actual distance between ellipsoids. Distance Between causes is the straight line distance between wellbore centres. Clearance Factor= Distance Between Profiles I10istanca Between Profiles - Ellipse SepmaGon). All station coordinates were calculated using Me Minimum Curvature method. Hileorp Alaska, LLC McArthur River 17 Febmery. 2017 - 11,40 Page 5 077 COMPASS HALLIBURTON Anticollision Report for TBU M-06 - M-06RD WP04 Direction and Coordinates are relative 0 True NOM Reference. Vertical capNe are relative W TBU M-6 ® 160.00usi Northing and Easting are trai to TBU M-06 - Slot B2-06. Coordinate System Is US State Plena 1927 (&act solution), Alaska Zone 04. Central Meridian W-150.00', Gdd Convergence st Surface is: -1.40 °. 5 N 1500- Ladder Plot 1 1 1 t t 3000 6000 9000 12000 15000 Measured Depth (3000 tin) Hilcorp Alaska, LLC McArthur River K-21,K-21RD,K-21RDVO K-25(K-16),K-25,K-25VO PIan:BLeMetl La-Vre,SBeltearl laVme, te-VmeNP1 PIan:TBV M35,M35.M35 WPi V0 PIan:TBUM36,M36,M36WP1 VO PIan:TBUM37,M37,M37 Wp1 VO TBUM01."i.M-01 VO TBUM02,M02,M-02VO TBUM03,M03,M03VO TBUM .W04,M64VO TBUM-05.M5,Mi TBUM-W,M06,MD6VO TBUM07,M07,MD7VO TBUM-09,1009,M-09VO TBU%10,M.10,M10VO TBUM-11'%l1'%11 VO TBUM-12,M12,M12VO TBUM13,M-13,M13VO TBUM14,%14,M14VO TBUM74, M14RD,M14RDVO TBUM15,M15,M15VO TBUM16,M16,M16VO TBU M16, M-15RD, M16RD VO TBUM17,M17,M17VO TBUM-18,M18,M18V6 TBUM19,M19,M19VO 17F srk.. 2017-11:00 P., 6 ef7 COMP455 ==W,ii_�►i\IY.,,1`�Il�i1��/Yl�f1l��1 r Jet f � 1 1 1 t t 3000 6000 9000 12000 15000 Measured Depth (3000 tin) Hilcorp Alaska, LLC McArthur River K-21,K-21RD,K-21RDVO K-25(K-16),K-25,K-25VO PIan:BLeMetl La-Vre,SBeltearl laVme, te-VmeNP1 PIan:TBV M35,M35.M35 WPi V0 PIan:TBUM36,M36,M36WP1 VO PIan:TBUM37,M37,M37 Wp1 VO TBUM01."i.M-01 VO TBUM02,M02,M-02VO TBUM03,M03,M03VO TBUM .W04,M64VO TBUM-05.M5,Mi TBUM-W,M06,MD6VO TBUM07,M07,MD7VO TBUM-09,1009,M-09VO TBU%10,M.10,M10VO TBUM-11'%l1'%11 VO TBUM-12,M12,M12VO TBUM13,M-13,M13VO TBUM14,%14,M14VO TBUM74, M14RD,M14RDVO TBUM15,M15,M15VO TBUM16,M16,M16VO TBU M16, M-15RD, M16RD VO TBUM17,M17,M17VO TBUM-18,M18,M18V6 TBUM19,M19,M19VO 17F srk.. 2017-11:00 P., 6 ef7 COMP455 HALLIBURTON Anticollision Report for TBU M-06 - M-06RD WP04 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor Hileorp Alaska, LLC McArthur River K4l,K-21,K-21 VU K-21,K-21RD,K-21RDV0 K -25(K -16),K -25,K -25V0 Plan:Sheh L-Une,Spellre L Vhe,IaVreWP7AVO Plan:TBUM35.M35,M35 WP1 VO PIen:MUM36,M36,W6 WPi V0 Plan:TBUM37,M37,W37 Wpi V0 TBUM-0I,M-01,M-01V0 MUM-02,M4)2,MB2V0 MUM-03,M-03,M-03VO TBU%04,M-04,M4VO TBUM-05,M-05,M-05V0 TBUM N,M-06,M-06V0 MUM -07,M -07,M -07V0 TBUM-09,M-09,M-09V0 TBUM-I0,M-10,M-10V0 TBUM-II,M-11,M-11 VO TBUM-12,W2,1VI-12V0 TBUM-I3,M-13,M-13VO TBUM-I4,1VI-14,M-14V0 TBUM-I4, M-14RD,M-14RDV0 TBUM-I5,1VI-15,M-15VO TBUM-i6,M-16,M-16VO MUWl6,M-16RD,M-16RD VO MUM -17,M -17,M -17V0 TBUM-i8,M-18'w8VO TBUM-79,M-19,M-19V0 TBU M -I9, M -19R0, M-19RDV0 17 Fe W. 2017 - 11:40 Pe0e 7017 CQN w III ' h'r - `• N��T•lP/S'SI��� ---------------------------------- Hileorp Alaska, LLC McArthur River K4l,K-21,K-21 VU K-21,K-21RD,K-21RDV0 K -25(K -16),K -25,K -25V0 Plan:Sheh L-Une,Spellre L Vhe,IaVreWP7AVO Plan:TBUM35.M35,M35 WP1 VO PIen:MUM36,M36,W6 WPi V0 Plan:TBUM37,M37,W37 Wpi V0 TBUM-0I,M-01,M-01V0 MUM-02,M4)2,MB2V0 MUM-03,M-03,M-03VO TBU%04,M-04,M4VO TBUM-05,M-05,M-05V0 TBUM N,M-06,M-06V0 MUM -07,M -07,M -07V0 TBUM-09,M-09,M-09V0 TBUM-I0,M-10,M-10V0 TBUM-II,M-11,M-11 VO TBUM-12,W2,1VI-12V0 TBUM-I3,M-13,M-13VO TBUM-I4,1VI-14,M-14V0 TBUM-I4, M-14RD,M-14RDV0 TBUM-I5,1VI-15,M-15VO TBUM-i6,M-16,M-16VO MUWl6,M-16RD,M-16RD VO MUM -17,M -17,M -17V0 TBUM-i8,M-18'w8VO TBUM-79,M-19,M-19V0 TBU M -I9, M -19R0, M-19RDV0 17 Fe W. 2017 - 11:40 Pe0e 7017 CQN w R Hileon AJr s, LLC RK& MSL=96' Steelhead Platform Well: M-06 Completed: Last API: 50-733-20585-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 28" 444' Conductor 6.625 27" Surf 47(' 13-3/8' 68 L-80 8TC 12.415" Surf 1,401' 9-5/8" 47 L-80 BTC -M 8.681" Surf 7,610' 7" 26 L-80 UNC 6.276" 7,346' 12,494' TUBING DETAIL 4-1/2" 12.6 L-80 TC 11 1 3.958" Surf 8,902' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 1 444' 444' 3.813 6.625 4.5 WellStarTRSV 12.6 MI 2 1,606' 1,553' 3.833 6250 4-Vr SFO -S Mandrel 3 2,235' 2,034' 3.813 5.950 4.5 XXO SVLN CIM 12.6 TCII 4 3,642' 2,812' 3.833 6.250 4-1/2" SFO -1 Mandrel 5 5,580 3,897 3.833 6.250 4-1/2' SFO -1 Mandrel 6 7,226' 4,855' 3.833 6.250 4-1/2" SFO -1 Mandrel 7 8,584' 5,654' 3.810 5.563 4-1/2" Dura Sleeve/GLV 8 8,604' 5,665' 3.850 5.960 BOT 5.3 Production Packer 9 8,625' 5,678' 3.813 5.000 X Profile 10 8,803' 5,783' 3.700 5.020 BOT Gun Drop Sub 11 8,902' 5,840' Open F6 E -Line Cut End of Tubing 12 9,099' 5,950 8' Tubing Tail Fish 13 9,450 6,141' 7,716' 7,728' 7'PosSet Plug w/ cement on top 14 11,730' 8,011' 11,739' 11,762' 7" PosiSet Plu w/ cement on to 15 12,330' 8,601' Plugged GD4 7" PosiSet Plug w/ cement on top 12,366' 8,613' 8,636' 24' Plugged Updated BV: JU-02/23/17 PERFORATION DETAIL Zone Top (MD) Btm (MD) T op (TVD) Btm (TVD) FT Date Status D14 8,932' 8,940' 5,857' 5,861' 8' 3/1/2011 Open D14 8,950' 8,966' 5,867' 5,876' 16' 3/1/2011 Open D16B 9,210' 9,230' 6,011' 6,021' 20' 2/27/2011 Open 0168 9,235' 9,245' 6,024' 6,030' 10' 2/27/2011 Open D16C 9,278' 9,298' 6,047' 6,058' 20' 2/28/2011 Open D16C 9,308' 9,328' 1 6,064' 6,074' 1 20' 2/28/2011 Open D16C 9,341' 9,351' 6,081' 61087' 10' 2/28/2011 Open F6 11,382' 11,390' 7,669' 7,677' 8' Plugged F7 11,430' 11,442' 7,716' 7,728' 12' Plugged F11 11,739' 11,762' 8,020' 8,043' 23' Plugged GD4 12,342' 12,366' 8,613' 8,636' 24' Plugged Updated BV: JU-02/23/17 H eery Alaaka, LLC RBt0T8G head -78' �stw cdGT0 20' as 7 Tv Esiit)C @9aJ Li3/8" .i I rA 9woAw 05908 sK M A .,P\\ a RpdwewK Depth (MD Grade ID OD ID Top km 1 .4,898" PYaaM t +•• ±7,340' Surf r TilnC®9A>Y a13-3/8r-6g ��• = aoem B Surf T®TCCel1Qb 8,604' .e' Mom BUT S-3 Production Packer 8.681" Surf ±7,300'(KOP)L-80 3.813 5.000 X Profile r L 6.27fi" PBTR 9,412' 12,494' TD 12SUL' i Steelhead Platform Well: M-06 PROPOSED Last Completed: FUTURE PTD: 209-004 API: 50-733.20585-00 CASING DETAIL TUBING DETAIL 4-1/2" 1 12.6 1L-80 TC-tl I 3.958" ±8,600' 8,902' JEWELRY DETAIL No Depth (MD Grade ID OD ID Top km 1 .4,898" 1 Conductor27" 2 ±7,340' Surf 470' Cement Retainer a13-3/8r-6g L-80 ED 32.415" Surf 1,401' 8,604' 5,665' L-80 BUT S-3 Production Packer 8.681" Surf ±7,300'(KOP)L-80 3.813 5.000 X Profile c 6.27fi" 7,346' 12,494' TUBING DETAIL 4-1/2" 1 12.6 1L-80 TC-tl I 3.958" ±8,600' 8,902' JEWELRY DETAIL No Depth (MD Depth (TVD) ID OD Item 1 ±/,JUV 1 .4,898" 1 CIBPSetforwhipstat 2 ±7,340' I ±4,927 I Cement Retainer D14 8,932' 1 8,944 5,857' a 8,604' 5,665' 3.850 5.960 BUT S-3 Production Packer 6 8,625' 5,678' 3.813 5.000 X Profile c 8,803' 5,783' 3.700 5.020 BOT Gun Drop Sub d 8,902' 5,840' 9,245' E -Line Cut End of Tubing e 9,099' 51950 Open Tubi Tail Fish f 9,450' 61141' 6,047' 7" PosiSet Plug w/ cement on t g 11,730' 8,011' 7" posSet Plug w/ cementoja on top b 12,334 8,601' 6,074' Y PosiSet Plug w/ Cement on top 2/28/2011 Open ' Updated By: Al. 02/23/17 PERFORATION DETAIL Zone ' Top MD Btm IMD Top RM (TVD) FT Date Status D14 8,932' 1 8,944 5,857' 5,861' 8' 3/1/2011 Open .a D14 8,950' 8,966' 5,867' 5,876' 16' 3/1/2011 Open 9,230'6,011' 6,021' 20 2/27/2011 Open' 9,245' 6,024'6,030' 10' 2/27/2011 Open ' 9,298' 6,047' 6,056' 20' 2/28/2011 Open W9,210'' ' 9,328' 6,064' 6,074' 20' 2/28/2011 Open ' 9,351' 6,081' 6,087' iD 2/28/2011 Open 2' 11,390' 7,669' 7,677' 8'Plugged ' 11,442' 7,716' 7,728' 12' Plugged Fil 11,739' 11,762' 8,020' 8,043' 23' Plugged 604 12,342' 12,366' 8,613' 8,636' 24' Plugged Updated By: Al. 02/23/17 ff M'IMP Awk , LLC Well Work Prognosis Well: M-06 Date: 02/21/2017 Well Name: M-06 API Number: 50-733-20585-00 Current Status-. Gas Producer Leg: Leg B-2 (NE Corner) Estimated Start Date: May 01, 2017 Rig: Hilcorp Rig 51 ✓ Reg. Approval Req'd? 403 Date Reg. Approval Reevd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 209-004 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) Current Bottom Hole Pressure: 1,483 psi @ 5,857' TVD 0.253 lbs/ft (4.87 ppg) 2011 SIBHP Maximum Expected BHP: 1,483 psi @ 5,857' TVD 0.253 lbs/ft (4.87 ppg) 2011 SIBHP Maximum Potential Surface Pressure: 697 psi Using 0.1 psi/ft gradient per 20AAC25.280(b)(4) Brief Well Summary M-06 is a depleted Gas Producer drilled in 2009. This workover will plug back the existing completion and prepare the well to sidetrack into the West Foreland Sands with a fall back option of adding the G and Hemlock again at a later date. 31-Eg4 {/GAJ ari-Ww,- Last Casing Test: 09/07/2009 3,000 psi at 12,408' for 30 minutes on chart Procedure: 1. MIRU Rig. 2. RU a -line and RIH to +/-7,960' and punch tubing. Work over fluid will be FIW. BOP's will be closed as needed to circulate the weii. 3. ND Wellhead, NU BOP and test to 250psi low/3,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. RU a -line and RIH to +/-8,600' and cut tubing. 6. Unseat hanger and POOH with completion. 7. RIH with bit and scraper to ±7,346, circulate clean. POOH. Tit 8. RIH with cement retainer and set at ±7,340' 9. RIH and sting into cement retainer. 10. RU cementing equipment and establish an injection rate with FIW. a. Mix and pump 80 barrels cement to isolate existing completion. Un -sting from retainer and circulate hole clean. b. POOH w/ work string. C."r �t3 74 11. Pressure Test casing to 2,50-0psig for 39 and chart. 12. RIH with bit and scraper to ±7,335' circulate clean. POOH. 13. RU a -line and RIH w/ CIBP to ±7.300', ±5' above casing connection. POOH A 14. PU whipstock and mills and RIH to CIBP. (tl` 15. Orient and set whipstock in 9-5/8". 16. Swap well to OBM drilling fluid. 17. Mill 8-1/2" window and 20' of new formation. POOH and LD mills. ***Remaining Procedure to be included on the Permit to Drill Sundry for the sidetrack*** t Co^car. Tbf fyJde(* Wppl /oaf P%irc:el JeW /+wy 4# war oe/" 074o 74C fP'wifr �ioofrCe/ i7erY 7�P T��d anof w.�eR i/ w<f 5�trr nA rn py�� 7iC �{ / ff4Yf i4 1rOf fowfr T*4h y fro+ ^e / tvc rate Ai' VqA Yet �✓L� WAf ,Gyd.,10 %CCovlYj from Yhhe&, 0 T�iCN�� A� M. irv#,,,, A► WdI for uo%:II S�GJV 4�w ''r je0/-1 Rif.p Al.x , LLC General sequence of operations pertaining to drilling Procedure: (informational only) 1. PU directional BHA and TIH to window. 2. Drill 8-1/2" hole to West Forelands sands. 3. Run and cement 7" casing. 4. Swap to completion sundry. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. BOP Drawing S. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form Well Work Prognosis Well: M-06 Date: 02/21/2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS +per 7 //,7 on aac oe oan 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Cperffikis s ❑ Suspend C] Perforate E] Other Stimulate El Pull Tubing ❑ Change Aac ed? ❑ Plug for Rednll Perforate New Pool El Re-enter Susp Well ❑ Alter Casi-g❑ Outer: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Cru! N bet: Hikorp Alaska, LLC Exploratory ❑ Development Q Strafigraphic ❑ Service ❑ 2D9-DD4 ' 3. Address: 3800 Centerpoint Drive, Suite 1400 6.9P( Numb . Anchorage, AK 99503 50-733-'r 5.1^ 7. If perforating: 8, Well Name 0 Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑ Tratl 3} U. it MM 9. Property Designation (Lease Number): ,V 10, Field/Pool(s): ADL0017594 & ADL0018730 . McArthur River Field / Middle Kenai Gas Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Dep PSP (psi): R''cga (M.O: :_nk (h•.DJ 12,502 • 8,770 9,099 • 5,95 897 9,412, 11,668, 12,317 9,099 Casing Length Size Buret Collapse Structural Conductor 470' 28"70' 470' Surface 1,401' 13-3/8" 1,401' 1,3715,0'0p5� 2.260 ps: Intermediate Production 7,610' 9518" 7 10' 5,080' 6.870 psi 4,760 psi Liner 5,148' 7' ^49W 8,762' 7,240 psi 5,410 pt3 Perforation Depth MD (ft): Perforation DepthTVD Tubing S Tubing Grade: Turfing MD (ft): 8,932 - 9,351 • 5,857 - 6,087 4-112" 12.6# / L-80 8,902 Packers and SSSV Type:eccers and SSSV MD (ft) arid TVD (ft): Baker S-3 Pkr & Wellstar TRSV 8,604' (MD) 5,685' (rVD) & 444' (MCS; 444 n) D 12. Attacrnents: Proposal Summary 0 ore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP tch (1 Exploratory ❑ Shatigreph:-c ❑ Oeaa!opmenl O Service ❑ 14. Estimated Date for 15. Well Status after proposed work Commencin O WIM017 g Operations: OIL [] VJINJ ❑ VVDSp_ ❑ Suspended ❑' • GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing Is true and the pro ure approved herein will not be deviated from without prior written ap al. Contact Dei r0aricaa 9071 283-132? Email tlmadowo@hllcom Can Printed Name Stan Golis Title Operations Manager L!.�� �� ♦`W. Signature '4 w,.l Phone 907 777-9356 Date b 1 t Zof -% COMMISSION USE ONLY Conditions of approval: Notify mmissio o that a representative may witness . Plug Integrity ❑ BOP eat q0 Mechanical IntegrityTest El Location Clearance Other. „f 35Q2io-,,o-,, h� �D4ic(C5 f" Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes No Subsequent Form Required: / O -N ❑ (� APPROVED BY �1 Approved by: COMMISSIONER THE COMMISSION Date: 3 - -7 �) 3 0, ,1 14 L 3-10-"/7 � � Submit Form Dupkatd Fomt 10de3 ReNted 112015 I id for 1 mordM from the date of approval. aehxienb m DupRrate TRANSMITTAL LETTER CHECKLIST WELL NAME: % ?\ L,t„ 311 — p( / i PTD: —O6V Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: _lUN-ni'. L6, POOL: 1Jk_Jtl:hA I'd6Y 9441,1r.Kk(61� A/. far't]04 (91/ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. API No. 50- (If last two digits _- Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- __) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of weld until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool MCARTHUR RIVER, HEMLOCK OIL - 520120 MCARTHUR RIVER, W FOREL Well Name: TRADING BAY-UNITDLI-06RD ProgramDEV _ Well bore seg PTD#:2170640 Company HILCORP ALASKA LLC _ Initial Class/Type ._ DEV./_PEND GeoArea 820 Unit 12070 On/Off Shore Off Annular Disposal n Administration '1 Permit fee attached_ _ _ .. _ NA. - '2 Lease number appropriate_ .... _ _ Yes ADL0018730, entire wellbore. 3 Unique well name and number _ _ _ _ _ _ _ _ _ _ _ _ Yes _ TBV M-06RD 4 Well located in.a defned.pool _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes MCARTHUR RIVER,. HEMLOCK OIL - 520120; .MCARTHUR RIVER, W FORELAND OIL - 520190; both governed 5 Well located proper distance from drilling unit boundary Yes _ _ Order No. 228A CO 228A contains no spacing restrictions with respect to drilling unit boundaries... 6 Well located proper distance from other wells.. _ _ _ _ _ Yes CO 228A has no interwell spacing restrictions. . . ... ... 7 Sufficient acreageavailable in drilling unit... _ _ _ _ _ Yes 8 If. deviated, is wellbore plat. included _ _ _ Yes 9 Operator only affected party.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes Wellbore will be more than 500' from an external property line where ownership. or landownership changes, 10 Operator has. appropriate bond in force _ _ _ _ _ _ _ _ Yes 11 Permit can be issued without conservation order. _ _ _ _ Yes _ Appr Date 12 Permit. can be issued without administrative_ approval _ _ ... _ _ _ _ Yes PKB 4/24/2017 13 Can permit be approved before 15 -day waitYes ---- � -. ... 14 Well located within area and. strata authorized by Injection Order# (put Q# in.comments) (For. NA 15 All wells within.1/4 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 17 Nonconven, gas conforms to AS31.05.0300. 1.A),lj.2.A-D) . . . ........... . . . . . NA _ 18 Conductor string provided _ _ _ _ _ _ _ _ ....... NA _ _ Conductor set in M-06. Engineering 19 Surface casing protects all known USDWs _ _ _ ..... NA _ Surface casing set and cemented in. M-06 _ _ ......... 'I20 CMT vol adequate to circulate on conductor & surf csg _ _ _ _ _ _ _ _ _ _ .. __ _ ____ _ _ _ _ NA 21 CMT vol adequate to tie-in long string to surf tag _ _ _ _ _ _ _ _____ _ _ _ _ _ _ No. 7" liner will. be cemented up to 10000 ft MD. Above Hemlock 22 CMT will cover. all known_ productive horizons ___ _ _____ _ _ _ _ _ _ _ _ _ _ _ _ Yes 23 Casing designs adequate for C,. T, B & permafrost _ _ _ Yes _ BTC provided Adequate tankage or reserve pit _ _ _ _ _ .. _ Yes Rig has steel pits ..,All,waste to approved disposal site. I24 25 If a re -drill, has_a 10-403 for abandonment been approved .... _ _ _ _ Yes _ 317-099. 26 Adequate wellbore separation proposed... ..... _ _ _ _ _ _ _ _ _ _ _ _ Yes Close. crossing with several wells. _Hilcorp to minimize collision. risk. 27 Ifdiverter required, does it meet regulations _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ Wellhead in place., Will use BOPS Appr Date 28 Drilling fluid, program schematic .& equip list adequate. ..... _ _ _ _ .. Yes Max form pressure =.4744 psi (9.2 PPG EMW) will drill with 8.9-9.5 ppg mud....... GLS 4/26/2017 29 BOPEs,.do they meet regulation _ _ . ........... . . . . . . . . ... . Yes .. _ Rig 51 has 5000 psi BOPE . 30 BOPE.press rating appropriate; test to(put psig in comments).... _ _ Yes _ MASP=2501. psi Will test BOPE to 3500 psi .(Alt talc for MASP using 2/3 gas column) 31 Choke. manifold complies w/API. RP -53 (May 84)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 32 Work will occur without operation shutdown___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ .. Need sundry approval for perforating and. running completion.. 33 Is presence of H2S gas probable .. _ _ _ _ _ _ _ _ ......... _ _ _ Yes _ _ _ Rig has sensors and alarms.. 34 Mechanical condition of wells within AOR verified (For service well only) _ .. ... _ _ NA 35 Permit can be issued w/o hydrogen sulfide measures ..... _ _ _ _ _ No _ H2S measures required, Steelhead. Platform is a designated H2S site. Geology 36 Data. presented on potential overpressure zones Yes .. Expected reservoir pressure is 9,2_ppg EMW; will be drilled using 8.9 to 9.5 ppg mud.. Appr Date 37 Seismic analysis of shallow gas. zones..... _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ PKB 4/24/2017 38 Seabed condition survey (if off -shore) _ ... _ _ _ _ _ _ _ _ _ _ _ _ _ _ __________ _ NA ... _ _ _ _ ........... _ _ _ _ . _ ..... _ _ _ _ _ _ _ ... 39 Contact name/phone for weekly.progress reports [exploratory only) ... _ .... _ _ _ _ _ _ _ _ _NA.. _ _ Offshore development sidetrack to be drilled fromthe Steelhead Platform, Geologic Date: Engineering Date Public Date . Sundry approval to perforate and run ESP completion. GIs Commissioner: Com mi fi�ner--: // Com is er RECEIVED AUG ^ , 2017 AOCCC TBU M-06RD 50-733-20585-01-00 McArthur River Field Kenai Peninsula Borough, Alaska lirna5 7(117—.hina74 7(117 Provided by: CANIIG Approved by: John Serbeck Distribution Date: July 20, 2017 Compiled by: Allen Odegaard Garnet Knopp Mike Skiles 21 7064 28 45 7 J TBU M-06RD TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW................................................................................................2 1.1 Equipment Summary ......................................................................................................................2 1.2 Crew................................................................................................................................................2 2 GENERAL WELL DETAILS...................................................................................................................3 2.1 Well Objectives...............................................................................................................................3 2.2 Hole Data........................................................................................................................................3 2.3 Daily Activity Summary ...................................................................................................................4 3 GEOLOGICAL DATA.............................................................................................................................8 3.1 Lithostratigraphy............................................................................................................................. 8 3.2 Lithology Details............................................................................................................................. 9 3.2.1 Tyonek Formation.................................................................................................................10 3.2.2 Hemlock Formation...............................................................................................................19 3.2.3 Hemlock H1X_FW.................................................................................................................19 3.2.4 Hemlock HTKE-FW...............................................................................................................20 3.2.5 Hemlock HK2T......................................................................................................................20 3.2.6 Hemlock HK2T_LOWER.......................................................................................................20 3.2.7 HemlockHK3T......................................................................................................................21 3.2.8 Hemlock HK4T......................................................................................................................21 3.2.9 Hemlock HK5T......................................................................................................................22 3.2.10 Hemlock HK6T......................................................................................................................22 3.2.11 Hemlock HK7T......................................................................................................................23 3.2.12 West Foreland Formation......................................................................................................24 3.2.13 West Foreland WFT..............................................................................................................24 3.2.14 West Foreland WF ............................................................................................................25 -2 3.2.15 West Foreland WF ............................................................................................................27 -3 3.3 Sampling Program......................................................................................................................29 4 Drilling Data.........................................................................................................................................30 4.1 4.1 Surveys...................................................................................................................................30 4.2 Bit Record.....................................................................................................................................38 4.3 Mud Record..................................................................................................................................39 4.4 Drilling Progress...........................................................................................................................40 5 SHOW REPORTS...............................................................................................................................41 6 DAILY REPORTS................................................................................................................................42 Enclosures 2" / 100' Formation Log (MD/TVD) 5" / 100' Formation Log (MD/TVD) 2" / 100' Drilling Dynamics Log (MD/TVD) 2" / 100' Gas Ratio Log (MD/TVD) 2" / 100' LWD Combo Log (MD/TVD) Final Data CD 1 CANRIG TBU M-06RD MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Baseline flame ionization total gas & chromatography. 0 hrs. — Effective Circulating Density ECD Halliburton 0 hrs. — Hook Load / Weight on bit Ri Watch 0 hrs. — Mud Flow In Ri Watch 0 hrs. — Mud Flow Out Ri Watch 0 hrs. — Mudlogging Unit Computer System HP Compaq Pentium 4 X2, DML & Ri Watch 0 hrs. Pit Volumes, Pit Gain/Loss Ri Watch 0 hrs. — Pump Pressure Ri Watch 0 hrs. — Pump stroke counters Ri Watch 0 hrs. — Rate of Penetration Ri Watch 0 hrs. — RPM Ri Watch 0 hrs. — 1.2 Crew Mud Logging Unit Type: Arctic Mud Loaaina Unit Number: ML030 Logging Geologists Years' Days Sample Catchers Years Days Allen Odegaard 19 29 Brendon Schmidt 0.25 18 Mike Skiles 11 6 Jake Robertson 4 16 Garnet Knopp 1 25 Years' experience as Logging Geologist .Z Days at wellsite between rig up and rig down of logging unit. CANRIG TBU M-06RD 2 GENERAL WELL DETAILS 2.1 WellObiectives M-06RD is an oil production well planned to be re -drilled in a south-westerly direction from the existing M- 06 utilizing the existing casing program down to 7,279' MD / 4,880' TVD. At 7,279' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock and West Foreland targets. A 8,320'x 8-1/2" open hole section is planned. A 7" 29# L-80 DWC/C production liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 3-1/2" ESP completion. The well very closely followed the planned directional path. The kickoff point was 7,279' MD at 54.20 and began immediately dropping angle to 11.9° by 8,475' MD. Held inclination at 110-140 until 10,563' MD. Continue drilling while dropping angle to 50 at 10,752' MD. Continue drilling while building angle to 840 at 13,218' MD. Held –840 to 15,472' (TD). 7" liner was hung from the 9-5/8" casing at 7,002' MD and ran down to 15,467' MD. Operator: HILCORP ALASKA, LLC Well Name: TBU M-06RD Field: McArthur River Field County: Kenai Peninsula Borough State: Alaska Company Representatives: Shane Hauck, Evan Harness, Harold Soule, Andy Lundale Location: Surface Coordinates 970' FNL, 532' FWL, Sec 33, T9N, R1 3W, SM, AK Mud Line Elevation 160' AMSL Rotary Table Elevation 187' AMSL Classification: Development - Oil API #: 50-733-20585-01-00 Permit #: 217-064 Rig Name/Type: Steelhead 51 / Steelhead Platform Spud Date June 05, 2017 Total Depth Date: June 24, 2017 Total Depth 15,472' MD / 9,911.42' TVD Primary Targets West Foreland Oil Pool Total Depth Formation: West Foreland Completion Status: — LWD-MWD Services. Halliburton / Sperry Drilling Services Directional Drilling Halliburton / Sperry Drilling Services Drilling Fluids Service Halliburton / Baroid Wireline Logging Service — 2.2 Hole Data Hole Section Max Depth TD Formation MW ppg Dev °inc Csg Dia Shoe Depth LOT pp9 MD TVD MD TVD ft ft 8'/z' 1 15,472' 1 9,911.42' WF3 9.10 82.28 7" 1 15,467' 9,910.31 N/A CANRIG TBU M-06RD 2.3 Daily Activity Summary June 3, 2017 Pump cement, pull out of hole, lay down 4" drill pipe and 3.5" tubing, rig up E -line, test casing, run in hole with E -line, tag cement @ 7,881', run in hole with junk basket. June 4, 2017 Run in hole with junk basket, pull out of hole with junk basket, Re -run junk basket until clean, Make up whipstock bottom hole assembly, perform shallow hole test, Make up rest of bottom hole assembly and run in hole with whipstock. June 5, 2017 Run in hole with whipstock, Clean/Prep pits for oil based mud, Swap over to oil based mud, Mill window from 7279' to 7340', Preform FIT test to 12.68 ppg EMW, pullout of hole. June 6, 2017 Pull out of hole, lay down milling assembly, Test bops, pick up bottom hole assembly, run in hole. June 7, 2017 Run in hole to window, circulate & condition mud, drill ahead from 7,340' to 8,230' @ report time. June 8, 2017 Drill ahead from 8,230' to 9,940' @ report time. June 9, 2017 Drill ahead from 9,940' to 11072', Circulate bottoms up, Prepare for bit trip. June 10, 2017 Pulled out of hole to surface, replacing bit & servicing bottom hole assembly @ report time. June 11, 2017 Ran in hole to bottom w/ new drill bit and serviced bottom hole assembly, circulated, drilled ahead; drilling ahead at 11,316' @ report time. June 12, 2017 Drilled ahead from 11,316' to 12,310' @ report time. June 13, 2017 Drilled ahead from 12,310' to 12,424'. Pulled out of hole for new bit due to low rate of penetration. At surface at report time. June 14, 2017 Ran in hole to bottom, washing/reaming the last few stands. Resumed drilling according to plan. Drilling ahead at 12,658' @ report time. June 15, 2017 Drilled ahead from 12,658' to 12,878'. Wiper trip to 11,020'. Ran in hole back to bottom and resumed drilling. Drilling ahead at 13,037'. June 16, 2017 Drilled ahead to 13,272'—low penetration rate. Circulated bottoms up then began pulling out of hole. Pulling out of hole at 5,084' @ report time. C,ANKIG 4 if TBU M-06RD June 17, 2017 Pulled out of hole to surface, laid down bottom hole assembly. Testing blow out prevention equipment @ report time. June 18, 2017 Completed blow out prevention equipment testing. Troubleshot new directional bottom hole assembly and began run back in hole. Running in hole at 6,560' @ report time. June 19, 2017 Ran back in hole to bottom with new bit & bottom hole assembly. Resumed drilling from 13,272' to 13,424'. Began wiper trip to 11,070' to rearrange position of torque reducers. Running back to bottom @ report time. June 20, 2017 Ran in hole back to bottom. Drilled ahead from 13,424'. Drilling ahead at 13,890' @ report time. June 21, 2017 Drilled ahead to 13,922'—low penetration rate and sticking on bottom. Broke free and pulled out of hole to surface. At surface replacing bottom hole assembly@ report time. June 22, 2017 Drilled ahead from 11,316' to 12,310'@ report time. Replaced bit & bottom hole assembly, changing from rotary steerable to mud -motor with 1.220 bend. Ran back in hole. Worked tight spot @ 13,500'-13,600'. RIH at 13709' @ report time. June 23, 2017 Completed RIH to 13,922' and resumed drilling @ 01:40. Drilled ahead from 13,922' to 15,003'. Pulled out of hole 10 stands for short wiper trip then ran in hole back to 15,003'. Resuming drilling ahead right @ report time. June 24, 2017 Resumed drilling at 15,003' after wiper trip. Drilled to total depth (TD) @ 15,472'. Circulated bottoms up then began pulling out of hole. Pulling out at 3120' @ report time. June 25, 2017 Pulled out of hole, laid down bottom hole assembly, Ran back in hole with cleanout assembly. Slip & cut drill line at the window. Continue RIH to TD. Circulating at TD @ report time. June 26, 2017 Circulated bottoms up at TD then pulled out of hole to window, working tight spot @ 12,700'. Ran back in hole to TD. Circulating at TD @ report time. June 27, 2017 Pulled out of hole to window, pumped dry job, completed pulling out of hole & laid down bottom hole assembly (cleanout assembly). Rig up and run 7" liner. Running 7" liner near 600'@ report time. June 28, 2017 Continued running liner to window. Circulated & conditioned mud, got parameters with drive sub. Continued running liner into open hole to hanger & packer assembly. Make up hanger & packer assembly as per Baker rep. Continued running liner into open hole on drill pipe from derrick. Currently running in at 9400' @ report time. CANRIG J— TBU M-06RD June 29, 2017 Continued running liner in open hole to TD, final value TBD. Circulated & conditioned mud for cement job. Rigged up cementers. Pumped cement job. Had trouble setting packer. Circulated 2x bottoms up, washed up coal cuttings. Rig down cementers. Pumped dry job, detached drill pipe from liner top and pulled drill pipe out of hole. Laying down Baker running tool @ report time. June 30, 2017 Checked running tool—good. Changed out lower rams to VBR and tested. Picked up casing scraper bottom hole assembly and singled in on 4" DP to 4,172'. Pick up second 7" scraper. Running in hole at 4,172'@ report time. July 1, 2017 Tripped in hole with scraper; casing pressure test. Rig down Canrig Mudlogging unit. CANRIG TBU M-06RD 7 CANRIG 6 5 2191% 2.2940 7 076% 489% 8 2 0.31% 22 144 9 0.92% 10 046% 11 748% 12 1 534% 9.01% 14 24 4.58% 8.24% 15 22 1145% 023% Cade DmdpUon Haas PernM Code DnalaOon Noun Pm ffl . 1 RIG UP B TEAR DOWN 29.50 001% . 14 NIPPLE UP B 0 15.00 4,5896 2 DRILL ACTUAL 72.50 22.14% . 15 TEST B.0 P. 3750 11 45% 3 REAMING 1600 4.89°o 16 DRILL STEM TEST 000 0.00% 4 CORING 000 000°0 ® 17 PLUG BACK 000 0.00% 5 COND MUD S CIRCULATE 7.50 2.29°o I] 18 SQUEEZE CEMENT 000 0.00% ■ 6 TRIPS 71.75 219100 © 19 FISHING 000 000°0 7 LUBRICATE RIG 2.50 076% 20 DIRECTIONAL WORK 0.00 0.00% ■ 8 REPAIR RIG 100 031% 21 WAITING TIME 000 000% 9 CUT OFF DRILLING LINE 300 0.9290 22 MEETINGS. SAFETY 075 0.23% 10 DEVIATION SURVEY 1.50 046°e 23 WELL CONTROL 000 0.00% I1 WIRE LINE LOGS 24.50 7,4800 24 COMPLETION 2700 8.24% 12 RUN CASING 8 CEMENT 1750 5 04% 25 BILLING CODES 0.00 O N% 13 WAIT ON CEMENT 000 000° 7 CANRIG TBU M-06RD 3 GEOLOGICAL DATA 3.1 Lithostratigraphy ops picked by Hilcorp Geologists FORMATION PROGNOSED ACTUAL MD ft TVD ft SSTVD ft MD ft TVD k SSTVD ft KOP 8,556 7,057 -6,897 7,279' 4,880' -4,720' Coal -39 11,383 8,644 -8,484 11,364' 8,653' -8,493' H1X FW 11,828 9,035 -8,875 11,784' 9,030' -8,870' Coal -59 11,876 9,073 -8,913 11,632' 8,898' -8,738' HTKE-FW 11,888 9,082 -8,922 11,849' 9,084' -8,924' HTK2 11,932 9,116 -8,956 11,892' 9,119' -8,959' WF 1 13,084 9,638 -9,478 12,966' 9,629' -9,469' WF 2 13,959 9,744 -9,584 13,562' 9,718' -9,558' WF 3 15,269 9,882 -9,722 14,796' 9,827' -9,667' TD 15,595 9,916 -9,756 15,472' 9,911' -9,751' CANRIG TBU M-06RD 3.2 Litholouv Details Lithology descriptions of all Kenai Group and Cenozoic rock cuttings samples started immediately after drilling out the surface conductor, then continued as per pre-set plans and procedures, and modified when directed by the Hilcorp operations geologist. The Kenai Group of Alaska's Cook Inlet Basin, which includes the Sterling, Beluga, Tyonek, Hemlock and West Foreland Formations, was deposited by a variable -energy fluvial system within a large closed fore - arc basin. The characteristic sedimentary stratigraphy consists of dominant massive to thinly bedded sandstone and claystone-siltstone, generally abundant thin inter -beds of air fall and re -deposited volcanic ash, minor beds of basal or modal conglomerate and extensively -distributed thin beds of coal and carbonaceous rocks. Gradational upward -fining sequences and bi-modal distribution zones are abundant within sandstone sections. Note that in Canrig's Lithology Descriptions, the special modifying term "tuffaceous" was created to address the pervasive presence and diversity of soft -sediment volcanogenic- origin rocks in the Cook Inlet area. Though generally applied to significantly ash -rich clay -silt -sand lithologies, its wide use in descriptions may include discernible micro -shard concentrations of disaggregated volcanic glass to vitric air fall volcanic ash to smectite-bentonite clays derived from devitrified ash to rare layers of vitric ignimbrite. CANE IG J- TBU M-06RD 3.2.1 Tyonek Formation The Tyonek formation is a series of alternating tuffaceous sandy siltstones, tuffaceous siltstones, sand and clay with occasional coal and carbonaceous shales. The tuffaceous siltstones are typically medium gray with pale brown and olive hues to medium dark gray with pale olive to very pale brown hues. They are easily friable to friable with a crumbly to pulverulent tenacity and often display bit curled to a rare platy cuttings habit. Typically have a dull to earthy luster with a silty to gritty texture and have a massive structure. The sands are typically medium gray to medium gray with pale olive hues to yellowish brown to grayish brown. Grain size is typically lower medium to lower fine to occasionally lower coarse and trace 2-4mm grains. They are typically sub -rounded to rounded to sub -angular with moderate to poor sorting and are sub spherical to trace sub discoidal. The sands are typically comprised of translucent smoky gray to transparent quartz and trace lithics. Ranges from unconsolidated to easily friable to trace amounts of firm clasts. The coals are typically black to very dark gray to occasionally matte black. They display brittle to crumbly to dense tenacity with hackly to conchoidal to irregular fracture. They usually display flakey to an occasional wedge-like cuttings habit. Luster is often vitreous to earthy to slightly waxy with a matte texture. 7,279' to 11,784' MD (-4,720' to -8,870' TVDSS) 10 CANRIG Drill Rate ft/hr Total Gas (units Maximum Minimum Avera e Maximum Minimum Average 452.7 0.11 1342 510.6 1.6 50.9 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C41 C4N C51 C5N 7,432 4,972 239 61,457 0 0 0 0 0 0 7,466 4,994 178 47,870 0 0 0 0 0 0 7,549 5,049 251 65,035 0 0 0 0 0 0 7,710 5,163 130 35,712 0 0 0 0 0 0 7,942 5,346 130 25,010 0 0 0 0 0 0 8,062 5,450 135 36,043 0 0 0 0 0 0 8,197 5,572 198 53,500 0 0 0 0 0 0 8,252 5,623 251 65,146 0 3 0 0 0 0 8,408 5,771 221 59,700 0 4 0 0 0 0 8,475 5,836 294 77,358 0 6 0 0 0 0 8,582 5,941 177 46,463 0 4 0 0 0 0 8,771 6,124 247 65,610 0 8 0 0 0 0 8,880 6,231 161 42,385 0 8 0 0 0 0 9,110 6,455 223 61,742 0 0 0 0 0 0 9,231 1 6,573 158 43,255 0 9 0 0 0 0 9,356 6,694 282 77,112 0 17 0 0 0 0 9,600 6,932 306 81,817 0 1 16 0 0 0 0 9,692 7,022 234 61,538 0 15 0 0 0 0 10,078 7,396 214 57,302 0 15 0 0 0 0 10,159 7,475 391 105,583 0 41 4 0 0 0 10,382 7,692 444 120,933 0 23 0 0 0 0 10,452 7,760 278 68,141 0 16 0 0 0 0 10,558 7,864 226 60,262 0 21 0 0 0 0 10,650 7,954 292 78,921 0 23 0 0 0 0 10,696 8,000 228 62,321 462 68 0 0 0 0 10,716 8,019 202 56,686 0 16 0 0 0 0 10,830 8,133 193 53,867 1 0 1 29 0 0 0 0 11,012 8,313 262 65,519 1 324 1 46 0 0 0 0 11,338 8,628 511 132,889 1 0 1 28 0 0 0 0 10 CANRIG TBU M-06RD Tuffaceous Claystone / Tuffaceous Siltstone (7340'-7390') = light gray to pinkish gray; mushy, clotted, crumbly; hydrophilic, very slightly cohesive; slightly adhesive; no fracture; massive cuttings; dull, earthy luster; matte to silty textures; inter -bedded with tuffaceous sand/sandstone. Sand / Sandstone (7390'-7450') = medium to medium light gray, occasional yellowish gray; lower medium to upper fine grained, common upper to lower clast size; angular to sub -angular to sub -round; moderate sphericity; moderate to well sorted; impact to pitted texture mature nature; non to very weak siliceous cement; dominant grain support; appears arenaceous; clean; good estimated porosity and permeability; no hydro -carbon indicators. Coal (7450'-7500') = matte black to grayish black to very dark brownish black; tough to brittle tenacity; occasionally slightly crumbly; irregular to splintery, hackly fracture; dominantly sub -wedge-like to occasionally sub -platy cuttings habit; waxy to matte luster; abrasive texture; dominantly sub -bituminous; no petroleum odor or sample fluorescence; no oil indicators. Carbonaceous Shale (7500'-7480') = black to some mottled grayish black; firm to hard; overall resinous luster with some earthy laminations; matte texture; sub -planar to hackly fracture; often inter -bedded with coal; no odor or sample fluorescence; no oil indicators. Tuffaceous Clay (7480'-7590') = pale yellowish brown to pinkish gray; very soft; lumpy to clumpy; clustered to clotted, very hydrophilic; non to very slight cohesive; slightly adhesive; amorphous fracture; earthy luster; ashy texture; massive gradation clay and silt abundant coal cavings. Sand (7590'-7660') = very light gray; clast size range coarse lower to medium lower and minor fines with depth; sub -rounded; moderate developed sphericity; impacted medium grains to polished and chipped coarse grains; sub -mature; very weak siliceous cement; slight to moderate silt and clay matrix increasing with depth; silt and clay structured matrix; loosely attached; some local grain support; composed of 90% quartz, 10% lithic fragments; fair to poor to poor porosity and permeability. Sand / Tuffaceous Clay (7660'-7720') = pale yellowish brown to medium gray fine to medium grained sand; quartz -dominated with lesser black lithics and cream -colored feldspars; and occasional very coarse grains of clear -iridescent blue subhedral quartz; poor to fair sorting; sub -angular to rounded; interspersed with firm angular clasts of light brown tuffaceous claystone. Coal / Tuffaceous Siltstone (7720'-7750') = coal fragments of varying size interspersed with light to medium brown sub -angular clasts of tuffaceous siltstone. Tuffaceous Claystone / Tuffaceous Siltstone (7750'-7830') = medium brown to medium gray firm subangular clumps of tuffaceous claystone and siltstone; some brown/black micro -bedding; smaller percentages of fine-grained salt -and -pepper colored quartz -dominated sand -stone; occasional millimeter - scale inter -bedding of siltstone and fine-grained sandstone. Coal / Tuffaceous Claystone (7830'-7860') = coal dominated; with lesser firm angular fragments of medium brown tuffaceous claystone and silt -stone; and minor fine to medium -grained tuffaceous sandstone; and very minor very coarse sand sized to granule sized sub -rounded clasts of quartz. Sand / Tuffaceous Sandstone (7860'-7940') = pale yellowish gray to salt and pepper colored coarse grained sand and grain -supported clumps of medium -grained tuffaceous sandstone; quartz -dominated with lesser black and cream -colored lithics; fair sorting; sub -rounded; moderate to high sphericity; minor sub -angular clumps of light brown tuffaceous siltstone with occasional blown/black wavy micro -bedding; siltstone content increasing downward. 11 CANRIG J- TBU M-06RD Coal / Tuffaceous Siltstone (7940'-8030') = coal inter -bedded with light gray to dark gray firm to friable sub -angular clumps of tuffaceous siltstone and claystone; and lesser salt -and -pepper colored fine to medium grained tuffaceous sandstone; silt/claystone has occasional wavy black/brown laminations and millimeter scale alternating beds of silt -stone and fine-grained quartz -rich sandstone; very occasional individual sub -rounded to rounded quartz grains up to granule conglomerate sized; clear to iridescent blue in color. Tuffaceous Claystone / Tuffaceous Siltstone (8030'-8100') = light gray to dark gray firm to friable sub- angular clumps of tuffaceous claystone and siltstone; flaky habit; dull to shiny luster; clayey texture; with some minor coal clasts and coarse sand to granule conglomerate sized sub -rounded quartz grains; some silt-stone/sandstone inter -bedding and wavy black/brown laminations; tuffaceous sandstone content increasing gradationally downward. Tuffaceous Sandstone / Sand (8100'-8180') = olive green to pale yellowish brown tuffaceous siltstone and medium -grained tuffaceous sandstone; clay -supported with sub -equal proportions of quartz and black and pink lithics; fair to well sorted; sub -rounded; moderate to high sphericity; grades downward into cleaner, better -sorted sand; medium to coarse grained; rich in clear to blue quartz and translucent tan feldspar; with lesser black lithics; sub -angular to rounded; moderate sphericity. Coal / Tuffaceous Siltstone / tuffaceous claystone (8180'-8260') = fragments of coal interspersed with firm to fragile rounded to sub -angular shiny chunks of light to medium gray tuffaceous claystone and clay - supported tuffaceous siltstone; occasional medium to very coarse sand sized sub -angular to sub -rounded particles of clear to light blue quartz and smoky tan colored feldspar; sand content varies vertically; sand is poor to fairly sorted. Sand / Tuffaceous Sandstone (8260'-8340') = buff to light gray medium to coarse grained sand; dominated by clear to smoky colored quartz with lesser black, pink, and brown lithics; poor to fair sorting; angular to rounded; moderate sphericity; with some larger rounded black and tan clasts of fine to medium grained tuffaceous sandstone, and minor massive medium gray sub -angular clasts of tuffaceous siltstone; very minor coal fragments and individual grains of quartz up to granule conglomerate sized. Sand / Coal (8340'-8420') = fragments of coal interspersed with tan to light gray sand consisting of sub- equal proportions of clear to light blue quartz and creamy feldspar; with minor black and red lithic grains; lower medium to upper coarse grained; fair sorting; angular to subrounded; moderate sphericity; also friable sub -rounded clumps of clay supported fine to medium grained quartz -rich tuffaceous sandstone; minor flaky chunks of medium gray tuffaceous siltstone and claystone. Coal / Tuffaceous Siltstone (8420'-8500') = conchoidal fragments of coal of varying sizes mixed with light to medium gray sub -angular firm to friable clasts of tuffaceous siltstone and claystone; some showing light to dark gray wavy inter -bedding; also subrounded to rounded olive colored clasts of fine to medium grained tuffaceous sandstone, dominated by clear quartz and milky feldspar grains; and minor angular to sub -rounded individual grains of quartz, coarse sand to granule conglomerate sized, clear to blue translucent colored. Tuffaceous Sandstone / Sand (8500'-8590') = medium light gray to light gray with light greenish gray secondary hues; very coarse upper to fine upper, mostly medium upper to medium lower; trace to 10% in very coarse range, mostly angular bit -broken; very poor sorting; very angular to sub rounded; low to moderate sphericity; bit impacted coarser to sub -rounded finer grains; sub -mature; mostly tuffaceous hydrophilic clay cement; dominant grain support; trace local matrix support; predominantly quartz; becoming generally coarser with depth; overall fair to good estimated porosity and permeability; no oil odor, fluorescence or other oil indicators. 12 CANRIG TBU M-06RD Coal (8590'-8640') = dominantly black to brownish black; tough to brittle tenacity, occasionally slightly crumbly; irregular, splintery, hackly fracture; dominantly sub -wedge-like to occasionally sub -platy cuttings habit; greasy to waxy luster; abrasive texture; dominantly sub -bituminous; no petroleum odor or sample fluorescence; no other oil indicators. Conglomerate Sandstone / Sand (8640'-8740') = light gray to medium light gray with light greenish gray and light olive gray secondary hues; very coarse upper to fine lower grained, mostly coarse lower to medium upper; scattered to abundant very coarse clear to white quartz and medium gray clasts; very angular to angular to sub -rounded, occasionally nodular, mostly sub -angular to angular; abundant bit impact; very poor sorting; low to moderate sphericity; sub -mature nature; some very light gray hydrophilic tuffaceous clay matrix; some hard siliceous cement; overall fair to good estimated porosity and permeability; no oil odor, fluorescence or other oil indicators. Coal / Carbonaceous Shale (8740'-8800') = black to grayish black; mottled dark yellowish brown carbon clays in micro -laminations; firm in coals to soft in clays; resinous mottled earthy lusters; hackly coal fracture to sub -planar carbon clay fracture; composed of sub -bituminous to lignitic coal with micro laminae of very carbon clay and shale; no oil odor, fluorescence or other oil indicators. Sand / Tuffaceous Sandstone (8800'-8880') = buff to light gray medium to coarse grained sand; dominated by clear to smoky colored quartz with lesser black, pink, light blue, and brown lithic fragments; poor to fair sorting; angular to rounded; moderate sphericity; with some larger rounded black and tan clasts of fine to medium grained sand -stone; and minor massive medium gray sub -angular clasts of tuffaceous siltstone; very minor coal fragments and individual grains of bit broken quartz up to granule conglomerate sized. Coal (8880'-8930') = dominantly black to brownish black; tough to brittle tenacity, occasionally slightly crumbly; irregular, splintery, hackly fracture; dominantly sub -wedge-like to occasionally sub -platy cuttings habit; greasy to waxy luster; abrasive texture; dominantly sub -bituminous; no petroleum odor or sample fluorescence; no oil indicators. Tuffaceous Siltstone (8930'-9000') = buff to light gray medium to pinkish gray; very poor to poorly indurated; clustered to clotted consistency; mushy to pasty; tacky to slimy; non to slightly cohesive; moderately adhesive, hydrophilic; sub -earthy to amorphous fracture; massive cuttings habit; PDC bit buttercurl cuttings observed; moderate earthy luster; silty to clayey ashy texture; inter -beds and grades with tuffaceous claystone; inter -beds with coals and carbonaceous shale; no petroleum odor or sample fluorescence; no oil indicators. Siltstone / Tuffaceous Claystone (9000'-9070') = moderate olive brown to light to medium olive gray; moderately hard to moderately soft, irregular to earthy fracture; sub -tabular to common PDC style cuttings; dull earthy luster, occasionally sub -waxy; moderately clayey to silty texture; occasional carbonaceous material in siltstone; no petroleum odor over oil based mud; no petroleum odor or sample fluorescence; no oil indicators. Coal / Carbonaceous Clay and Silt (9070'-9730') = black mottled grayish brown; firm becoming hard in larger fragments; earthy mottled resinous luster; matte to silty in carbon clay; sub -planar to sub -tabular fracture along shale partings; composed of micro laminations of coal and very carbon clay and silt; grading to tuffaceous siltstone; no petroleum odor or sample fluorescence; no oil indicators. Conglomerate Sandstone / Sandstone (9730'-9240') = light to medium light gray with light greenish gray and light olive gray secondary hues; coarse lower to fine upper, mostly medium upper to medium lower; scattered to abundant very coarse to pebble sized clear to white; often bit broken quartz and medium gray nodular clasts; very angular to angular to sub -rounded, mostly sub -angular; abundant bit 13 CANRIG _i TBU M-06RD impact; poor sorting; moderate sphericity; locally common very light gray ashy clay hydrophilic and soluble in-fill/cement; occasional trace to scattered siliceous zones; predominantly grain supported; composition is 95% quartz, 5% lithics; overall fair to good porosity and permeability; no oil odor, fluorescence or other oil indicators. Coal (9240'-9290') = dominantly black to brownish black; tough to brittle tenacity, occasionally crumbly; irregular, splintery, hackly fracture; dominantly sub -wedge-like to occasionally sub -platy cuttings habit; greasy to waxy luster; abrasive texture; no petroleum odor or sample fluorescence above oil based drilling fluid; no other oil indicators. Conglomerate Sandstone / Sandstone (9290'-9400') = light to medium light gray, light greenish gray and light olive gray secondary hues; coarse lower to fine upper, mostly medium upper to medium lower; scattered to abundant very coarse to pebble sized clear to white; often bit broken quartz and medium gray nodular clasts; very angular to angular to subrounded, mostly sub -angular; abundant bit impact; very poor sorting; moderate sphericity; locally common very light gray ashy clay hydrophilic and soluble in- fill/cement; occasional trace to scattered siliceous zones; predominantly grain supported; composition is 95% quartz, 5% lithics; overall fair to good porosity and permeability; no oil odor, fluorescence or other oil indicators; often inter -bedded with thin coal seams. Tuffaceous Siltstone (9400'-9450') = pinkish gray to light to medium gray; very poor induration; lumpy to clumpy to clotted consistency; slightly mushy to pasty; slightly to moderately cohesive; moderate to good adhesiveness; amorphous to sub -earthy fracture; sub-nodufar to massive habit; earthy luster; silty to ashy texture; hydrophilic; no oil odor, fluorescence or other oil indicators; often inter -bedded with thin coal seams. Sand / Tuffaceous Sandstone (9450'-9500') = golden brown to light olive gray sub -rounded soft to firm clasts of fine to medium grained tuffaceous sandstone and associated individual medium to very coarse sized sand grains; primarily quartz but black lithics increasing downward; poor to fair sorting; sub -angular to rounded; moderate to high sphericity. Tuffaceous Sandstone / Tuffaceous Siltstone (9500'-9550') = light olive gray to dark gray firm to friable sub -angular clasts of massive tuffaceous siltstone and sub -rounded clasts of fine to medium grained quartz -rich tuffaceous sandstone; fair sorting; sub -angular to rounded grains in a clayey matrix; with silt - stone content increasing downward; and occasional coal fragments. Tuffaceous Sandstone (9550'-9600') = buff to olive gray colored rounded to sub -angular clasts of fine to medium grained, quartz -dominated tuffaceous sandstone with clayey matrix; and lesser massive friable sub -angular chunks of tuffaceous siltstone; and minor sub -rounded to angular individual clear to smoky quartz grains up to granule conglomerate sized. Tuffaceous Sandstone / Tuffaceous Siltstone / Tuffaceous Claystone (9600'-9650') = tawny to dark gray friable to firm fragments of tuffaceous claystone and siltstone with some wavy laminations; and sub - rounded clasts of fine to very fine grained clay -supported tuffaceous sandstone dominated by clear quartz and creamy feldspar. Coal / Tuffaceous Sandstone (9650'-9700') = fragments of coal inter -bedded with fine to medium grained tuffaceous sandstone, rich in subhedral quartz and tawny feldspar; and olive gray to dark gray friable clasts of tuffaceous siltstone and claystone. Tuffaceous Claystone / Tuffaceous Siltstone (9700'-9760') = olive gray to pale yellow brown firm to soft clumps of tuffaceous claystone and siltstone; some showing black/brown micro -bedding; lesser clasts of black and tan fine grained tuffaceous sandstone dominant in quartz and cream colored feldspar; minor coal fragments. 14 CANRIG _i TBU M-06RD Tuffaceous Claystone / Sand (9760'-9820') = light gray to dark gray firm to friable nodules of varying size, of tuffaceous claystone, siltstone, and lesser clay -supported fine grained creamy feldspathic arenite; some coal clasts showing fine inter -bedding with fine grained quartz -rich sandstone; also quartz - dominated sub -rounded to very angular fine to lower coarse sand grains which increase in content downward. Sand (9820'-9880') = tan to medium gray quartz -dominated sand, lower medium to upper coarse grained; with minor milky feldspar and black lithics; fair sorting; angular to subrounded; moderate sphericity; with larger fragile sub -rounded clasts of fine to medium grained quartz -rich tuffaceous sandstone; and subangular clasts of olive gray tuffaceous claystone and siltstone, occasionally with planar laminations present; no visible cut or odor. Sand (9880'-9950') = tan to medium gray sand rich in clear quartz with lesser milky feldspar and black, pink, and blue lithics; lower medium to upper very coarse grained with a few conglomerate clasts; fair sorting; angular to subrounded, with small clusters of fine to medium -grained tuffaceous sandstone and larger fragile clumps of tuffaceous claystone and siltstone; minor conchoidally fractured coal fragments. Tuffaceous Siltstone / Tuffaceous Claystone (9950'-10000') = tawny to medium gray soft angular clumps of tuffaceous claystone and laminar tuffaceous siltstone; with lesser fragments of quartz/feldspar rich fine to medium grained tuffaceous sandstone. Sand / Tuffaceous Siltstone / Coal (10000'-10100') = pale yellowish brown to olive gray quartz - dominated sand, medium grained; with minor black, pink, and orange lithic grains and occasional blue quartz grains up to conglomerate sized; fair to well sorted; subangular to rounded; with larger sub - rounded chunks of fine to medium grained tuffaceous sandstone and large subangular laminar chunks of tuffaceous claystone and siltstone, frequently with black/grey/brown micro -bedding visible; sand content decreases downward; with coal dominant at 10080'. Tuffaceous Siltstone / Coal (10100'-10180') = light to medium gray large subangular clumps of tuffaceous siltstone, with earthy luster and some planar laminations; minor clumps of clay supported fine to medium grained tuffaceous sandstone rich in clear quartz and milky feldspar; abundant coal near 10110'. Siltstone / Tuffaceous Claystone (10180'-10250') = moderate olive brown to light to medium olive gray; moderately hard to moderately soft; irregular to earthy fracture; sub -tabular to common PDC bit buttercurl cuttings observed in claystone pieces; dull earthy luster, occasionally sub -waxy; moderately clayey to silty texture; occasional carbonaceous material in siltstone; no oil odor, fluorescence or other oil indicators; often inter -bedded with thin coal seams. Tuffaceous Siltstone (10250'-10310') = medium light gray to light bluish gray; stiff; crumbly; blocky to earthy fracture; massive cuttings habit; dull, earthy luster; gritty sucrosic texture; thinly bedded with ashy clay, and thin sand lenses; locally pale brown to grayish red carbonaceous siltstone; slightly to moderately calcareous; no oil odor, fluorescence or other oil indicators; often inter -bedded with thin coal seams. Coal (10310'-10370') = dominantly black to brownish black; tough to brittle tenacity, occasionally slightly crumbly; irregular, splintery, hackly fracture; dominantly sub -wedge-like to occasionally sub -platy cuttings habit; greasy to waxy luster; abrasive texture; dominantly sub -bituminous; no petroleum odor or sample fluorescence; no other hydro -carbon indicators. Conglomerate Sandstone / Sand (10370'-10480') = light gray to medium light gray with light greenish gray and light olive gray secondary hues; coarse lower to fine upper, mostly medium upper to medium lower; scattered to abundant very coarse to pebble sized clear to white often bit broken quartz grains; very angular to angular to sub -rounded, occasionally nodular, mostly subangular; abundant bit impact; 15 CANING TBU M-06RD poor sorting; moderate sphericity; locally common very light gray to almost white ashy clay hydrophilic and soluble infill; also occasional trace to scattered siliceous zones; predominantly grain supported; composition is 95% quartz, 5% lithic fragments; overall fair to good porosity and permeability; no oil odor; no fluorescence over oil based mud or other indicators. Tuffaceous Siltstone (10,480'-10,530') = pale yellowish brown; poor induration; brittle; hydrophilic; amorphous to sub -earthy fracture; amorphous to sub -platy cuttings habit; slight visible fracture; ashy to silty texture; trace to occasion -ally common off white to gray ash in sample; no oil indicators; often inter- bedded thin coal seams. Coal (10530'-10580') = dominantly black to brownish black; tough to brittle tenacity, occasionally slightly crumbly; irregular, splintery, hackly fracture; dominantly sub -wedge-like to occasionally sub -platy cuttings habit; greasy to waxy luster; abrasive texture; dominantly sub -bituminous, no petroleum odor or sample fluorescence; no oil indicators. Sand / Conglomeratic Sand (10580'-10660')= dominantly light olive gray, transitions to slightly higher lightness values with light gray to medium light gray as a secondary hue; very fine upper to very coarse; fines upward; nearly all disaggregated; apparent soluble tuffaceous matrix; dominantly very angular to angular to subangular, but some scattered subrounded; equant subspherical shape; predominantly quartz, trace to 10% lithic fragments; often interbedded with thin coal seams, no petroleum odor or sample fluorescence; no other hydrocarbon indicators. Tuffaceous Siltstone (10,660'-10,710') = pale yellowish brown; poor induration; brittle; hydrophilic; amorphous to sub -earthy fracture; amorphous to sub -platy cuttings habit; slight visible fracture; ashy to silty texture; trace to occasionally common off white to gray ash in sample; no oil indicators; commonly interbedded with thin coal seams. Sand (10710'-10770') = light gray to olive gray quartz rich sand with lesser black lithics; lower medium to lower very coarse grained with occasional grains up to granule sized; poor to fair sorting; angular to rounded; low to high sphericity; with larger subrounded nodules of consolidated salt -and -pepper tuffaceous sandstone; fine to medium grained; and subangular fragments of tuffaceous siltstone often showing black/brown fine planar laminations; minor coal fragments. Tuffaceous Sandstone / Coal (10770'-10830') = olive gray to dark gray firm subrounded nodules of varying size, of quartz rich fine to medium grained tuffaceous sandstone with abundant black lithic minerals and clayey matrix; fair sorting; subangular to rounded; moderate to high sphericity; also numerous individual loose sand grains, most commonly quartz, ranging in size from medium sand to conglomerate sized; occasional subangular fragments of microbedded gray tuffaceous siltstone; numerous coal fragments. Coal / Tuffaceous Siltstone (10830'-10880') = numerous coal fragments of all sizes interspersed with firm to fragile sub -rounded nodules of medium gray salt and pepper tuffaceous sandstone; with sub -equal proportions of clear to smoky quartz and black lithics and minor feldspar content; fine to medium grained; subangular to subrounded; fair sorting; minor individual sub -rounded to subangular sand grains mostly quartz, ranging from coarse sand to granule sized; and soft subangular clumps of gray/brown tuffaceous si Itsto n e/claysto ne. Coal / Tuffaceous Sandstone (10880'-10970') = numerous coal fragments of all sizes interspersed with firm to soft nodules of light to medium gray clay supported tuffaceous sandstone; quartz dominated; very fine to medium grained; with scattered granule sized individual clear and blue subrounded quartz grains; quartz rich medium to coarse grained sand content decreasing downward; lesser clumps of tuffaceous siltstone with some showing bedding. 16 CANRIG rf TBU M-06RD Coal / Tuffaceous Sandstone (10970'-11070') = abundant conchoidal and blocky coal fragments of varying size; subrounded; medium gray nodules of medium to coarse grained tuffaceous sandstone with some clayey matrix; mostly quartz and cream colored feldspar, with minor black lithics; loose sand grains whose abundance varies vertically; also dominated by quartz but grain size up to granule; minor grey tuffaceous siltstone clasts; dull cut fluorescence in tuffaceous sandstone clasts. Sand / Tuffaceous Sandstone (11070'-11140') = light olive gray to medium gray quartz dominated sand with lesser tan feldspar and minor lithic grains; fine to coarse grained; poor to fair sorting; subangular to rounded grains; with abundant firm rounded nodules of consolidated clay supported tuffaceous sandstone, also quartz rich; upper fine to lower coarse grained; moderate sorting; subangular to rounded grains; and angular clasts of laminated tuffaceous siltstone; loose sand content decreasing downward. Tuffaceous Sandstone / Sand (11140'-11200') = medium gray to medium brown subrounded firm nodules of clay supported tuffaceous sandstone; quartz -dominated; fine to medium grained; fair sorting; subangular to subrounded; with abundant loose sand particles of same mineralogy, but grain size up to coarse sand; poorly sorted; subrounded; minor fragments of coal and brown tuffaceous siltstone. Sand / Coal (11200'-11280') = light gray to dark gray quartz and feldspar rich sand, upper fine to lower coarse grained; poor to fair sorting; subrounded to rounded; with abundant coal flakes and fragments throughout; numerous firm rounded nodules of quartz -rich clay -supported medium grained tuffaceous sandstone; and angular fragments of tuffaceous siltstone; with minor firm angular blocks of light cream colored tuffaceous claystone. Sand (11280'-11360') = light olive gray to medium gray sand, quartz dominated with lesser tan feldspar and black lithics; upper fine to lower coarse; poor to fair sorting; subrounded to rounded; moderate to high sphericity; with occasional rounded clusters of fine to medium grained tuffaceous sandstone of same mineralogy; with clayey matrix; occasional fibrous or conchoidal fragments of laminated gray tuffaceous siltstone. Note: Coal 39 was from 11,364' to 11,385' MD (-8,493' to -8,512' TVDSS) Coal / Tuffaceous Sandstone (11360'- 11420') = abundant blocky and conchoidal coal fragments of varying size interspersed with sub -equal quantities of medium gray laminated tuffaceous siltstone fragments and firm rounded nodules of quartz -rich fine to medium grained tuffaceous sandstone. Sand / Tuffaceous Sandstone (11420'-11510') = light gray to medium gray sand, rich in clear quartz and white to tan feldspar, with minor black lithics; upper fine to upper coarse grained; poor to fair sorting; subangular to rounded; with soft clumps of fine to medium grained tuffaceous sandstone of same mineralogy, and creamy to gray subangular nodules of tuffaceous siltstone; no visible fluorescence or odor. Sand (11510'-11570') = tan to medium gray quartz dominant sand, upper fine to upper coarse grained; fair sorting; angular to rounded; with abundant coal fragments of varying size; and fragile clumps of fine to medium grained tuffaceous sandstone also quartz dominant; and angular fragments of tuffaceous siltstone showing occasional planar laminations. Sand / Conglomerate Sand / Conglomerate (11570'-11660') = light olive gray with light medium gray as secondary hue; very fine lower to conglomerate sized granule; mostly fine upper to medium upper grained, but large portion coarse to conglomerate; moderately to poorly sorted; dominantly angular to subangular with some very angular and some subrounded; poor to very poor sphericity; 90% quartz, 10% lithic fragments; interbedded with tuffaceous siltstone; slightly to moderately calcareous; petroleum odor masked by oil based mud; trace dull yellow sample fluorescence over oil based mud; moderately dull yellow cut fluorescence. 17 CANRIG TBU M-06RD Note: Coal 59 was from 11,632' to 11,669' MD (-8,738' to -8,770' TVDSS) Coal (11660' - 11730') = grayish black to brownish black, olive black, black; moderately hard to hard; tough, occasionally slightly brittle tenacity; irregular to sub -planar fracture; occasionally blocky, sub - conchoidal; sub -platy to wedge-like cuttings habit; sub -flaky to scattered sub -bladed; overall sub -greasy to sub -earthy luster; matte to abrasive texture; ranging from dominantly sub -bituminous to bituminous; non -calcareous; oil indicators masked by oil based drilling fluid. Conglomerate Sand (11730'-11860') = overall light to medium olive gray to light olive brown; dominantly milky, sub -transparent to transparent, white to off white individual grains, scattered light to medium green; trace scattered red to red -orange; dominantly upper coarse to lower coarse, scattered upper medium to occasionally subgranular sized fragments; very poorly to poorly sorted; dominantly very angular to angular, rare subangular to subrounded; dominantly low to very low sphericity, scattered irregular; unconsolidated; quartz framework with rare dark lithics; light to medium green fragments have cryptocrystalline, chert -like texture; petroleum odor masked by oil based mud; moderately fast yellow streaming fluorescence; dull yellow moderately weak cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderately dull yellow residual cut fluorescence; hydrocarbon indicators possibly masked by oil based mud. 18 CANRIG J TBU M-06RD 3.2.2 Hemlock Formation The Hemlock formation is comprised mainly of conglomeratic and tuffaceous sandstone with occasional tuffaceous siltstones and trace coal beds. The tuffaceous sandstones are often medium gray to medium dark gray with a slight light olive gray to olive gray. Grain size is typically lower fine to upper fine with occasional coarse grading to lower medium to upper medium and occasional coarse grained. Individual clasts are often spherical to sub -discoidal with sub rounded to rounded, and rarely, subangular grains. Typically grains are well to moderately well sorted and either appear completely unconsolidated or occur in very fragile clusters. Overall the clasts have a tuffaceous matrix and are grain supported. They appear to be texturally sub mature to immature and dominated by translucent or transparent quartz with pitted or etched faces. Black and green mafic lithics are also semi -common. The conglomeratic sands observed are typically medium dark gray to medium gray with pale olive to moderate brown to black secondary hues. They are unconsolidated to easily friable with lower medium to upper fine grains and 3-5mm bit broken quartz grains being semi -common. They often display poor to moderate sorting, sub rounded to angular with sub spherical to trace sub -discoidal sphericity. The tuffaceous siltstones can often grade to a sandy siltstone and are typically poorly indurated. Overall tenacity ranges from crumbly to brittle with an irregular to earthy fracture. Cuttings are commonly "bit stacked" to slightly tabular with a dull to earthy luster and a silty to gritty texture. Carbonaceous banding is common but not abundant. 3.2.3 Hemlock H1X_FW 11,784' to 11,849' MD -8,870' to -8,924' TVDSS Drill Rate tUhr Total Gas units Maximum Minimum Avera a Maximum Minimum Average 210.8 11.3 80.8 77.0 12.0 24.1 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C41 C4N C51 C5N No notable gas peaks Conglomerate Sand (11730'-11860) = overall light to medium olive gray to light olive brown; dominantly milky, sub -transparent to transparent, white to off white individual grains, scattered light to medium green, trace scattered red to red -orange; dominantly upper coarse to lower coarse, scattered upper medium to occasionally subgranular sized fragments; very poorly to poorly sorted; dominantly very angular to angular, rare subangular to subrounded, dominantly low to very low sphericity, scattered irregular; unconsolidated; quartz framework with rare dark lithics; light to medium green fragments have cryptocrystalline, chert -like texture; petroleum odor masked by oil based mud; moderately fast yellow streaming fluorescence; dull yellow moderately weak cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderately dull yellow residual cut fluorescence; hydrocarbon indicators possibly masked by oil based mud. 11 19 CA -MIG J— TBU M-06RD 3.2.4 Hemlock HTKE-FW 11,849' to 11,892' MD (-8,924' to -8,959' TVDSS) Drill Rate ft/hr Drill Rateft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Average 124.7 6.7 87.3 36.0 14.0 18.2 14.0 Gas Peaks Average MD Depth TVD Depth I Total Gas C1 C2 C3 C41 C4N C51 C5N No notable gas peaks C5N Carbonaceous Shale (11860'-11930') = black to brownish black to brownish gray as fine disseminated carbonaceous material interbedded in shale; shale grades to and interbedded with a less indurated carbonaceous claystone/siltstone; moderate to low density; crumbly to firm friable; tabular to cuttings; common PDC bit buttercurl cuttings; dull luster; matte texture; non -calcareous; very dull yellow to no fluorescence in shale pieces. Sand (11930'-11990') = very light gray to pale yellowish brown quartz dominated sand, with minor gray, tan, pink and black lithics; upper fine to upper coarse grained; fair sorting, subangular to rounded; moderate to high sphericity; with minor firm to soft tuffaceous sandstone clasts of same mineralogy; and occasional coal clasts; dull cut fluorescence. 3.2.5 Hemlock HK2T 11,892' to 11,962' MD (-8,959' to -9,011' TVDSS) Sand (11930'-11990') = very light gray to pale yellowish brown quartz dominated sand, with minor gray, tan, pink and black lithics; upper fine to upper coarse grained; fair sorting; subangular to rounded; moderate to high sphericity; with minor firm to soft tuffaceous sandstone clasts of same mineralogy; and occasional coal clasts; dull cut fluorescence. 3.2.6 Hemlock HK2T_LOWER 11,962' to 12,127' MD (-9,011' to -9,123' TVDSS) Drill Rate ft/hr Drill Rateft/hr Total Gas units Maximum Minimum Total Gas (units) Maximum Average Minimum I Average Maximum 14.0 Minimum Average 293.9 6.1 103.6 89.0 12.0 34.3 C3 C41 Gas Peaks C51 C5N MD Depth TVD Depth I Total Gas C1 C2 C3 C41 C4N C51 C5N 11,913 9,134 1 89 1 17485 1 1488 1 844 1 111 219 1 45 1 44 Sand (11930'-11990') = very light gray to pale yellowish brown quartz dominated sand, with minor gray, tan, pink and black lithics; upper fine to upper coarse grained; fair sorting; subangular to rounded; moderate to high sphericity; with minor firm to soft tuffaceous sandstone clasts of same mineralogy; and occasional coal clasts; dull cut fluorescence. 3.2.6 Hemlock HK2T_LOWER 11,962' to 12,127' MD (-9,011' to -9,123' TVDSS) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Average 382.7 2.7 107.0 88.0 14.0 38.9 Gas Peaks MD Depth TVD Depth I Total Gas C1 C2 C3 C41 C4N C51 C5N No notable gas peaks 20 CANRIG J_ TBU M-06RD Sand (11990'-12070') = light gray to pale yellowish brown clean quartz rich sand, with minor tawny feldspar and pink and black lithic grains; upper fine to upper coarse grained; fair sorting; subrounded to rounded; with occasional granule conglomerate sized quartz grains and subrounded clusters of consolidated sandstone; showing moderate streaming fluorescence, dull yellow moderate cut fluorescence, light brown visible cut; also occasional sub -angular clasts of gray/black laminated tuffaceous siltstone. Sand (12070'-12150') = milky white to yellowish brown sand, dominated by quartz grains, with lesser white -tan feldspar and minor pink and black lithics; low clay content; some consolidated clusters; upper fine grained to upper coarse grained with a few conglomerate sized grains; fair sorting; subangular to rounded; moderate to high sphericity; some consolidated clusters show low to moderate cut and streaming fluorescence; minor larger subangular tuffaceous claystone clasts and coal fragments. 3.2.7 Hemlock HUT 12,127' to 12,229' MD (-9,123' to -9,183' TVDSS) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Average 293.6 1.8 95.9 57.0 16.0 32.5 Gas Peaks MD Depth TVD Depth I Total Gas C1 C2 C3 C41 C4N C51 C5N No notable gas peaks Sand (12150'-12220') = light gray to medium gray sand, very rich in clear to blue quartz, with eggshell colored feldspar and lesser black, orange and pink lithics; upper fine to upper coarse grained with occasional conglomerate grains; fair sorting; subangular to rounded; moderate sphericity; with occasional firm consolidated sandstone clusters which produce moderate bright yellow streaming and cut fluorescence; and minor fragments of coal and laminated tuffaceous siltstone. 3.2.8 Hemlock HK4T 12,229' to 12,374' MD (-9,183' to -9,263' TVDSS) Drill Rate ftlhr Total Gas (units Maximum Minimum Average Maximum Minimum Average 123.5 1.3 58.4 42 0 10.0 26.1 Gas Peaks MD Depth TVD I Depth I Total Gas C1 C2 C3 C41 C4N C51 C5N No notable gas peaks Sand / Conglomerate (12220'-12310') = light olive gray to light olive brown sand, quartz dominant, with lesser cream to tan colored feldspar and very minor black lithics; upper fine to lower very coarse grained with some granule sized grains; poor to fair sorting; subangular to rounded; low clay content; occasional sub- angular fragments of coal and gray/ black laminated tuffaceous siltstone; some consolidated sandstone clusters showing moderate yellow streaming fluorescence; weak yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; dull yellow residual cut fluorescence. CAN�JG 21 J— TBU M-06RD Sand / Tuffaceous Siltstone (12310'- 12400') = tan to medium gray quartz/feldspar rich sand, upper fine to upper coarse grained with some conglomerate clasts; fair sorting; subangular to rounded; and occasional consolidated sandstone clusters of same mineralogy; sand content diminishing downward; medium gray tuffaceous siltstone fragments showing fine gray/black laminations and curved cuttings habit; siltstone content increasing downward. 3.2.9 Hemlock HK5T 12,374' to 12,581' MD (-9,263' to -9,359' TVDSS) Drill Rate ft/hr Drill Rateft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Average 215.1 1.2 72.7 67.0 5.0 25.5 Avera e Gas Peaks 1.2 MD Depth TVD Depth I Total Gas C1 C2 C3 C41 C4N C51 C5N No notable gas peaks MD Depth Sand / Tuffaceous Sandstone (12400'-12490') = light olive gray to medium gray, abundant in clear to blue quartz and tan feldspar with minor black lithic grains; upper fine to upper coarse grained to some conglomerate grains; fair sorting; sub -angular to rounded; with occasional consolidated sandstone clusters; minor subangular fragments of tuffaceous siltstone and coal; clusters show moderate light yellow streaming fluorescence and dull cut fluorescence. Sand (12480'-12560') = light gray to dark gray salt and pepper sand, subequal proportions of quartz, feldspar and black lithic grains; upper fine to very coarse grained with numerous conglomerate grains; poor sorting with larger clast sizes favoring quartz; sub -angular to subrounded'abundant coal fragments; minor fragments of gray tuffaceous siltstone; very few consolidated sandstone clusters. 3.2.10 Hemlock HK6T 12,581' to 12,798' MD (-9,359' to -9,424' TVDSS) Sand (12560'-12640') = light olive gray to pale yellow brown sand, quartz dominated with lesser tan feldspar and black lithic components; minor clay content; upper fine to upper coarse grained with a few conglomerate clasts; fair sorting; subangular to subrounded; moderate sphericity; scattered coal fragments of all sizes; minor firm subangular chunks of tuffaceous claystone and laminated tuffaceous siltstone; occasional consolidated sandstone clusters showing moderate streaming fluorescence and dull yellow cut fluorescence. 22 CANRIG Drill Rateft/hr Total Gas units Maximum Minimum Average Maximum Minimum Avera e 242.6 1.2 96.2 84.0 6.0 28.8 Gas Peaks MD Depth TVD Depth I Total Gas C1 C2 C3 C41 C4N C51 C5N 12,587 9,520 1 84 1 17,836 863 511 87 136 32 31 Sand (12560'-12640') = light olive gray to pale yellow brown sand, quartz dominated with lesser tan feldspar and black lithic components; minor clay content; upper fine to upper coarse grained with a few conglomerate clasts; fair sorting; subangular to subrounded; moderate sphericity; scattered coal fragments of all sizes; minor firm subangular chunks of tuffaceous claystone and laminated tuffaceous siltstone; occasional consolidated sandstone clusters showing moderate streaming fluorescence and dull yellow cut fluorescence. 22 CANRIG J— TBU M-06RD Sand / Tuffaceous Sandstone (12640'- 12740') = pale yellowish brown to dark gray sand, quartz - dominant; with lesser milky white and pink feldspar and black lithics; upper fine to very coarse grained with abundant conglomerate grains; poor to fair sorting with larger clasts predominantly quartz; sub- angular to subrounded; minor subangular fragments of tuffaceous siltstone and claystone; occasional consolidated sandstone clusters showing mild yellow streaming fluorescence and dull cut fluorescence and residual stain. Conglomerate Sandstone / Conglomerate Sand / Tuffaceous Sandstone (12740'-12880') = very light gray; clast size pebble to very coarse upper to coarse lower; angular bit impacted fragments to sub - rounded; very poor to moderate developed sphericity; moderate sorting; polished to chip texture; mature nature; non to very weak siliceous cement; unconsolidated; dominant grain support; slight visible clay matrix; composed of predominantly quartz with some lithic fragments; fair to good porosity and permeability; moderate yellow streaming fluorescence; weak yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; dull yellow residual cut fluorescence. 3.2.11 Hemlock HK7T 12.798' to 12.966' MD (-9.424' to -9.469' TVDSS) Conglomerate Sandstone / Conglomerate Sand / Tuffaceous Sandstone (12740'-12880') = very light gray; clast size pebble to very coarse upper to coarse lower; angular bit impacted fragments to sub - rounded; very poor to moderate developed sphericity; moderate sorting; polished to chip texture; mature nature; non to very weak siliceous cement; unconsolidated; dominant grain support; slight visible clay matrix; composed of predominantly quartz with some lithic fragments; fair to good porosity and permeability; moderate yellow streaming fluorescence; weak yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; dull yellow residual cut fluorescence. Tuffaceous Siltstone (12880'-12940') = light olive gray to medium gray firm to friable curved wedges of tuffaceous siltstone; planar habit; occasional fine light gray -dark gray laminations; and soft clumps of light gray tuffaceous claystone; minor fine to coarse grained subrounded sand grains throughout, mostly quartz; very minor consolidated sandstone clusters, no visible fluorescence. CANING 23 Drill Rate it/hr Total Gas units) Maximum Minimum Average Maximum MinimumI Average 148.0 1.2 54.8 115.0 7.0 32.5 Gas Peaks MD Depth TVD Depth Total Gas Cl C2 C3 C41 C4N C51 C5N 12,819 9,589 115 23,200 1534 962 111 265 54 62 11,861 9,600 83 16,311 1145 725 88 216 47 54 Conglomerate Sandstone / Conglomerate Sand / Tuffaceous Sandstone (12740'-12880') = very light gray; clast size pebble to very coarse upper to coarse lower; angular bit impacted fragments to sub - rounded; very poor to moderate developed sphericity; moderate sorting; polished to chip texture; mature nature; non to very weak siliceous cement; unconsolidated; dominant grain support; slight visible clay matrix; composed of predominantly quartz with some lithic fragments; fair to good porosity and permeability; moderate yellow streaming fluorescence; weak yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; dull yellow residual cut fluorescence. Tuffaceous Siltstone (12880'-12940') = light olive gray to medium gray firm to friable curved wedges of tuffaceous siltstone; planar habit; occasional fine light gray -dark gray laminations; and soft clumps of light gray tuffaceous claystone; minor fine to coarse grained subrounded sand grains throughout, mostly quartz; very minor consolidated sandstone clusters, no visible fluorescence. CANING 23 TBU M-06RD 3.2.12 West Foreland Formation The West Foreland formation is comprised mainly of tuffaceous sand, tuffaceous sandstone, and tuffaceous siltstones and occasional tuffaceous claystone and coal beds. The tuffaceous sand/sandstones are medium gray to pale yellowish brown to light olive gray, with lesser white to buff -colored feldspar and black lithic constituents; upper fine to medium to lower coarse grained, with occasional very coarse grains; poor to fair sorting; angular to sub -angular to sub -rounded to rounded; moderate to high sphericity; often interbedded with tuffaceous siltstone/claystone, sometimes micro - laminated; often interbedded with thin coals and carbonaceous shale. The tuffaceous siltstones are light olive gray to pale yellowish brown, also light olive gray to medium gray; they often contain platy and fissile fragments of tuffaceous siltstone and smaller milky pale grains of tuffaceous claystone; occasional casts of fine to medium grained tuffaceous sandstone and minor coal pieces; a few sub -angular fine to medium sized clear to light blue quartz sand grains; often interbedded with tuffaceous claystone, tuffaceous sandstone, loose sand, and occasional coals and carbonaceous shale. 3.2.13 West Foreland WFT 12,966' to 13,562' MD (-9,469' to -9,558' TVDSS) Tuffaceous Claystone (12940'-12990') = very pale gray soft subrounded clumps of massive claystone, occasionally with small angular black volcanic grains contained within; frosted luster; and lesser medium to dark gray subangular plated fragments of tuffaceous siltstone; minor fine sand grains mostly quartz; minor coal fragments of all sizes. Sand (12990'-13020') = olive gray to medium gray sand, quartz dominant; with minor black lithic grains; upper fine to upper coarse grained; fair sorting; subangular to subrounded; with occasional large soft clumps of tuffaceous claystone and siltstone; sand (13020'-13120) = light olive gray to medium gray quartz dominated sand with minor tan colored feldspar and black lithics; minor clay content which varies vertically; upper fine to very coarse grained with occasional conglomerate clasts; fair sorting with larger clast sizes favoring quartz; subangular to subrounded; moderate sphericity; minor larger fragments of platy tuffaceous siltstone and claystone; minor consolidated clusters of fine to medium grained sandstone of same mineralogy which shows moderate to fast light yellow streaming fluorescence and dull yellow cut. Tuffaceous Sandstone / Tuffaceous Siltstone (13120'-13240') = light olive gray to medium gray quartz rich sandstones; grain size is upper very fine to lower coarse; angular to sub -rounded; low to moderate sphericity; well to moderate sorting; sandstone nodules contain a volcanic ash that is white to bluish white in color and clumpy / soft texture; sample contains some black lithics, lower coarse to upper coarse in size, subrounded to rounded, with moderate sphericity; tuffaceous siltstone is light gray to medium gray, CAN1IG 24 Drill Rate fUhr Total Gas (units Maximum Minimum Average Maximum Minimum Avera e 167.1 0.5 64.8 56.0 8.0 1 21.9 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C41 C4N 051 CSN 13,186 9,674 52 10,107 708343 44 103 26 33 13,293 9,686 56 11,957 511 239 29 60 14 16 13,500 9,710 44 10,363 343 124 8 25 0 0 Tuffaceous Claystone (12940'-12990') = very pale gray soft subrounded clumps of massive claystone, occasionally with small angular black volcanic grains contained within; frosted luster; and lesser medium to dark gray subangular plated fragments of tuffaceous siltstone; minor fine sand grains mostly quartz; minor coal fragments of all sizes. Sand (12990'-13020') = olive gray to medium gray sand, quartz dominant; with minor black lithic grains; upper fine to upper coarse grained; fair sorting; subangular to subrounded; with occasional large soft clumps of tuffaceous claystone and siltstone; sand (13020'-13120) = light olive gray to medium gray quartz dominated sand with minor tan colored feldspar and black lithics; minor clay content which varies vertically; upper fine to very coarse grained with occasional conglomerate clasts; fair sorting with larger clast sizes favoring quartz; subangular to subrounded; moderate sphericity; minor larger fragments of platy tuffaceous siltstone and claystone; minor consolidated clusters of fine to medium grained sandstone of same mineralogy which shows moderate to fast light yellow streaming fluorescence and dull yellow cut. Tuffaceous Sandstone / Tuffaceous Siltstone (13120'-13240') = light olive gray to medium gray quartz rich sandstones; grain size is upper very fine to lower coarse; angular to sub -rounded; low to moderate sphericity; well to moderate sorting; sandstone nodules contain a volcanic ash that is white to bluish white in color and clumpy / soft texture; sample contains some black lithics, lower coarse to upper coarse in size, subrounded to rounded, with moderate sphericity; tuffaceous siltstone is light gray to medium gray, CAN1IG 24 J— TBU M-06RD quartz rich, lower very fine in size, very well sorted, firmly friable, subangular to rounded massive cuttings; good to moderate yellow streaming fluorescence; yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderate yellow residual cut fluorescence. Tuffaceous Sandstone / Tuffaceous Siltstone (13240'-13400') = light olive gray to medium gray quartz rich sandstones; grain size is upper very fine to lower medium; angular to subrounded; low sphericity; moderate sorting; sand nodules, upper coarse in size, rounded to well rounded; black lithics, lower medium to upper medium in size, subangular to subrounded, low sphericity; tuffaceous siltstone is light gray to medium gray, quartz rich, lower very fine, very well sorted, firmly friable, subangular; weak light yellow streaming fluorescence; weak yellow cut fluorescence; faint brown visible cut; weak bright yellow residual cut fluorescence. Tuffaceous Sandstone / Tuffaceous Siltstone (13400'-13540') = light olive gray to medium gray quartz rich sandstones; upper very fine to lower coarse grained; angular to subrounded; low to moderate sphericity; well to moderate sorting; sandstone pieces contain a volcanic ash that is off-white to blue - white in color and has a clumpy / very soft texture; sample contains some black lithics, lower coarse to upper coarse in size, subrounded to rounded with moderate sphericity; tuffaceous siltstone is light gray to medium gray, quartz rich, lower very fine in size, very well sorted, firmly friable, subangular to rounded massives; good to moderate yellow streaming fluorescence; yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderate yellow residual cut fluorescence. 3.2.14 West Foreland WF_2 13,562' to 14,796' MD -9,558' to -9,667' TVDSS Tuffaceous Siltstone / Volcanic Ash (13,540'-13,700') = tuffaceous siltstone is light gray to medium gray; quartz rich, lower very fine grained, very well sorted, firmly friable, angular to subangular to rounded massives; volcanic ash is light olive gray to medium olive gray in color, clay sized particulates, very well sorted, pulverulent tenacity, smooth texture, laminae structure; black lithics, lower medium to upper medium in size, subangular to subrounded, low sphericity; coal seam shows at 13,590' and is dominate, grayish black to black in color, angular to subangular in angularity, poorly sorted, conchoidal fracture, dense tenacity, dull luster; quartz sand nodules, light brown tan to medium brown tan in color, sub - rounded to rounded in shape, upper medium to upper coarse in size, well to moderately sorted, moderate to high sphericity, silica cement; sands are light olive gray to medium olive gray, unconsolidated, poorly sorted, lower fine to lower medium in size, angular to subrounded; common to scattered yellow to yellow - green light sample fluorescence; good to moderate yellow streaming fluorescence; yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderate yellow residual cut fluorescence. 25 CANRIG Drill Rate ft/hr Total Gas (units) Maximum MinimumI Average Maximum I Minimum Avera e 525.8 0.2 123.9 72.0 4.0 25.4 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C41 C4N C51 C5N 13,681 9,730 51 10,396 597 323 51 88 19 24 13,774 9,739 54 11,324 682 432 66 122 28 27 13,822 9,743 72 15,862 727 456 87 135 35 37 14,130 9,768 61 13,323 597 357 57 98 25 23 Tuffaceous Siltstone / Volcanic Ash (13,540'-13,700') = tuffaceous siltstone is light gray to medium gray; quartz rich, lower very fine grained, very well sorted, firmly friable, angular to subangular to rounded massives; volcanic ash is light olive gray to medium olive gray in color, clay sized particulates, very well sorted, pulverulent tenacity, smooth texture, laminae structure; black lithics, lower medium to upper medium in size, subangular to subrounded, low sphericity; coal seam shows at 13,590' and is dominate, grayish black to black in color, angular to subangular in angularity, poorly sorted, conchoidal fracture, dense tenacity, dull luster; quartz sand nodules, light brown tan to medium brown tan in color, sub - rounded to rounded in shape, upper medium to upper coarse in size, well to moderately sorted, moderate to high sphericity, silica cement; sands are light olive gray to medium olive gray, unconsolidated, poorly sorted, lower fine to lower medium in size, angular to subrounded; common to scattered yellow to yellow - green light sample fluorescence; good to moderate yellow streaming fluorescence; yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderate yellow residual cut fluorescence. 25 CANRIG r�J_ TBU M-06RD Tuffaceous Claystone / Sand (13700'- 13760') = light gray to dark gray curved and subangular firm fragments of massive tuffaceous claystone, rarely showing dark -light gray planar laminations and elongated sand sized clasts of black volcanic glass; minor unconsolidated sand grains throughout, varying vertically; mostly clear quartz; lower medium to lower coarse grained with rare grains as large as granule conglomerate; fair sorting; subhedral grains. Sand / Tuffaceous Claystone (13760% 13860) = proportions of sand and claystone fluctuating with MD depth; sand is medium olive gray to dark gray; dominated by clear to smoky quartz with lesser tan feldspars and black lithics; abundant clayey matrix; upper fine to lower coarse grained; fair to well sorted; subangular to rounded; moderate to high sphericity; commingled with light gray to beige soft to firm curved and subangular fragments of massive tuffaceous claystone and lesser platy tuffaceous siltstone; some fragments showing light -dark gray planar laminations; consolidated sandstone clusters have moderate bright yellow streaming fluorescence; moderate yellow cut fluorescence; light to medium brown visible cut; weak to moderate yellow residual cut fluorescence. Sand (13860'-14010') = medium olive gray to dark gray quartz rich sand with lesser tan and black lithics and minor clayey matrix; upper fine to upper coarse grained with a few granule conglomerate sized clasts; fair sorting; subangular to subrounded; with minor coal fragments and platy angular chunks of dark gray tuffaceous siltstone and light gray tuffaceous claystone; a few consolidated sandstone clusters showing moderate to fast light yellow streaming fluorescence; moderate bright yellow cut fluorescence; dark straw to brown visible cut; weak to moderate yellow residual cut fluorescence. Sand / Tuffaceous Sandstone (14010' - 14130') = overall light brown to light olive gray, light olive brown; milky, transparent, light gray and occasional light green individual grains; upper fine to lower medium; dominantly quartz framework with rare micas and dark lithic fragments; tuffaceous sandstone has white mushy clayey matrix, which also contains trace to 10% ash; friable to soft; crumbly tenacity, subangular to subrounded; moderate to moderately low sphericity; fair to poor sorting; non -calcareous; petroleum odor masked by oil based mud; even moderately bright yellow sample fluorescence; whitish yellow cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based mud. Sand (14130'-14230') = medium olive gray to dark gray quartz -rich sand with lesser tan and black lithics and minor clayey matrix; upper fine to upper coarse grained with a few granule conglomerate sized clasts; fair sorting; subangular to subrounded; with minor coal fragments and platy angular chunks of dark gray tuffaceous siltstone and light gray tuffaceous claystone; trace to 10% off-white to light gray ash; rare consolidated sandstone clusters showing moderate to fast light yellow streaming fluorescence; moderate bright yellow cut fluorescence; dark straw to brown visible cut; weak to moderate yellow residual cut fluorescence, oil indicators possibly masked or influenced by oil based mud. Sand / Tuffaceous Sandstone (14230' -14350') = overall light brown to light olive gray, light olive brown; milky, transparent, light gray and occasional light green individual grains; upper fine to lower medium; dominantly quartz framework with rare micas and dark lithic fragments; tuffaceous sandstone has white mushy clayey matrix, which also contains trace to 10% ash; friable to soft; crumbly tenacity; subangular to subrounded; moderate to moderately low sphericity; fair to poor sorting; non -calcareous; petroleum odor masked by oil based mud; even moderately bright yellow sample fluorescence; whitish yellow cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based drilling fluid. Tuffaceous Sandstone / Tuffaceous Siltstone / Sand (14350'-14480') = light olive gray to moderate olive brown; fragile massive clumps of clay -supported tuffaceous siltstone and fine to medium grained tuffaceous sandstone, with occasional medium to very coarse sand grains interspersed throughout, mostly quartz; minor coal particles; trace micas; intact sandstone clusters are predominantly quartz with CANT IG 26 scattered lithic fragments; petroleum odor masked by oil based mud; trace oil staining; moderate to fair yellow streaming fluorescence; dull yellow -white moderate cut fluorescence; faint dark straw to light brown visible cut; faint brown to faint straw residual cut ring; moderately dull yellow residual cut fluorescence; hydrocarbon indicators possibly masked by oil based drilling fluid. Sand / Tuffaceous Sandstone (14480' -14600) = overall light brown to light olive gray, light olive brown; milky, transparent, light gray and trace light green individual grains; upper fine to lower medium grained; dominantly quartz framework with rare micas and dark lithics; tuffaceous sandstone has a white mushy clayey matrix, which also contains trace to 10% off-white ash; friable to very friable to soft; crumbly tenacity; subangular to subrounded to rounded; moderate to moderately low sphericity; fair to poor sorting; non -calcareous; petroleum odor masked by oil based mud; even moderately bright yellow sample fluorescence; whitish yellow cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based mud. Sand / Tuffaceous Sandstone (14600' -14710') = overall light brown to light olive gray, light olive brown; milky, transparent to translucent, upper fine to lower medium grained; dominantly quartz framework with rare micas and dark lithics; tuffaceous sandstone has a white mushy clayey matrix, which also contains trace to 10% off-white ash; friable to very friable to soft; crumbly tenacity; sub -angular to subrounded to rounded; moderate to moderately low sphericity; fair to poor sorting; non- calcareous; petroleum odor masked by oil based mud; even moderately bright yellow sample fluorescence; whitish yellow cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based drilling fluid. Tuffaceous Claystone (14710'-14770') = light gray to medium olive gray fragile subangular clumps of massive tuffaceous claystone; waxy luster; lesser dark gray laminar fragments of tuffaceous siltstone; occasional sand grains strewn throughout, mostly subhedral quartz with lesser black lithics; grain size from medium sand to granule conglomerate with larger grain sizes favoring quartz. 3.2.15 West Foreland WF_3 14.796' to 15.472' MD (-9.667' to -9.751' TVDSS) Sand / Tuffaceous Sandstone (14770'-14900') = medium olive gray to medium olive brown sand, dominated by clear to smoky quartz; with lesser tan, bluish white, and black lithics; minor clayey matrix; lower fine to upper coarse grained with a few quartz clasts up to granule conglomerate sized; poor to fair sorting; subangular to rounded with quartz grains showing most maturity; moderate to high sphericity; occasional subrounded friable clumps of light gray tuffaceous claystone; minor subangular firm planar fragments of dark gray tuffaceous siltstone; occasional consolidated sandstone clusters of same mineralogy with moderate to fast bright yellow streaming fluorescence; moderate bright yellow cut fluorescence; light brown to medium straw visible cut; brown residual cut ring, moderate yellow residual cut fluorescence; minor oil stain; oil indicators possibly masked or influenced by oil based drilling mud. 27 CANING Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 600.7 2.1 148.6 48.0 7.0 26.8 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C41 C4N C51 C5N 15,381 9,898 1 49 9,809 1 878 389 44 102 25 35 Sand / Tuffaceous Sandstone (14770'-14900') = medium olive gray to medium olive brown sand, dominated by clear to smoky quartz; with lesser tan, bluish white, and black lithics; minor clayey matrix; lower fine to upper coarse grained with a few quartz clasts up to granule conglomerate sized; poor to fair sorting; subangular to rounded with quartz grains showing most maturity; moderate to high sphericity; occasional subrounded friable clumps of light gray tuffaceous claystone; minor subangular firm planar fragments of dark gray tuffaceous siltstone; occasional consolidated sandstone clusters of same mineralogy with moderate to fast bright yellow streaming fluorescence; moderate bright yellow cut fluorescence; light brown to medium straw visible cut; brown residual cut ring, moderate yellow residual cut fluorescence; minor oil stain; oil indicators possibly masked or influenced by oil based drilling mud. 27 CANING 0 TBU M-06RD Sand / Tuffaceous Sandstone (14900'- 15000') = yellowish gray to medium gray sand dominated by clear to smoky quartz, with minor tan and black lithics and some clayey matrix, upper fine to coarse grained with some grains up to granule conglomerate; larger grains almost all quartz; fair sorting; sub- angular to rounded; abundant firm to soft rounded tuffaceous sandstone clusters of same mineralogy but fine -medium grained; lesser soft light gray clumps of tuffaceous claystone with fine embedded angular clasts of volcanic glass; sandstone clusters showing fast- moderate yellow streaming fluorescence; moderate bright yellow cut fluorescence; brown visible cut; minor oil stain. Sand (15000'-15100') = light olive gray to medium gray sand dominated by clear to smoky quartz with minor tan and black lithics and varying levels of clayey matrix; lower medium to upper coarse grained with a few conglomerate quartz clasts; subangular to rounded; moderate sphericity; semiconsolidated sandstone clusters of same mineralogy; minor firm subangular dark gray fragments of tuffaceous siltstone and soft light gray tuffaceous claystone; moderate whitish yellow streaming and cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based mud. Sand / Tuffaceous Sandstone (15100' -15240') = overall light brown to light olive gray, light olive brown, milky, transparent to translucent; upper fine to lower medium grained; dominantly quartz framework with rare micas and dark lithics; tuffaceous sandstone has an off-white, mushy clayey matrix, which also contains trace to 10% off-white ash; friable to very friable to soft; crumbly tenacity; sub -angular to subrounded to rounded; moderate to moderately low sphericity; fair to poor sorting; non- calcareous; no petroleum odor above oil based mud; even moderately bright yellow sample fluorescence; whitish yellow cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based drilling fluid. Sand (15240'-15340') = light olive gray to medium gray sand dominated by clear to smoky quartz with minor dusky brown and black lithics and varying levels of clayey matrix; lower medium to upper coarse grained, with a few conglomerate quartz clasts; subangular to rounded; moderate sphericity; semi - consolidated sandstone clusters of same mineralogy; minor firm subangular dark gray fragments of tuffaceous siltstone and soft, light gray tuffaceous claystone; moderate whitish yellow streaming and cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based mud. Sand / Tuffaceous Sandstone (15340'- 15470') = overall light brown to light olive gray, light olive brown; milky, transparent to translucent; upper flne to lower medium grained; dominantly quartz framework with rare micas and dark lithics; tuffaceous sandstone has an off white, mushy clayey matrix, which also contains trace to 10% off-white ash; friable to very friable to soft; crumbly tenacity; sub -angular to subrounded to rounded; moderate to moderately low sphericity; fair to poor sorting; non- calcareous; no petroleum odor above oil based mud; even moderately bright yellow sample fluorescence; whitish yellow cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; minor to trace oil stain; sandstone clusters showing fast -moderate yellow streaming fluorescence; oil indicators possibly masked or influenced by oil based mud. �IG 28 J� TBU M-06RD 3.3 Sampling Program Set Type and Purpose Interval Frequency Distribution Debra Oudean A Washed and Dried 7,279'– 12,900' 30' Hilcorp Alaska LLC Reference 12,900'– 15,472' *15' 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 Debra Oudean B Washed and Dried 7,279'– 12,900' 30' Hilcorp Alaska LLC Reference 12,900'– 15,472' *10' 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 Box 1: 7,279'– 9,060' Box 2: 9,060'– 10,320' Box 3: 10,320'– 12,330' Box 4: 12,330'– 13,680' Box 5: 13,680'– 15,472' *Note: 15' samples were caught as the drill rate allowed; if the drilling rate was faster than 607hour, 30' samples were caught. Most of the 15' samples were from between 12,900' and 13,500'. CA—NI IG 29 J_ TBU M-06RD 4 DRILLING DATA 4.1 4.1 Surveys Measured Depth (ft) Incl. (�) Azim. (�) True Vertical Depth (ft) Latitude (ft) N(*), S(-) Departure (ft) E(*), W(-) Vertical Section (Incr) (ft) Dogleg Rate (0l100ft) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 100.0 0.46 161.57 100.00 -0.38 0.13 -0.34 0.46 200.0 0.24 141.70 200.00 -0.93 0.38 -0.81 0.25 300.0 0.40 263.49 300.00 -1.13 0.17 -1.06 0.56 400.0 0.26 288.30 399.99 -1.10 -0.40 -1.16 0.20 450.0 0.60 25.90 449.99 -0.83 -0.39 -0.89 1.37 455.0 0.62 26.49 454.99 -0.78 -0.37 -0.84 0.42 460.0 0.68 22.53 459.99 -0.73 -0.34 -0.79 1.50 465.0 0.80 16.24 464.99 -0.67 -0.32 -0.72 2.89 470.0 0.96 7.53 469.99 -0.59 -0.31 -0.65 4.16 475.0 1.12 358.29 474.99 -0.50 1 -0.30 -0.56 4.63 480.0 1.37 350.46 479.99 -0.39 -0.31 -0.45 6.04 485.0 1.65 344.73 484.99 -0.27 -0.34 -0.34 6.36 490.0 2.03 340.70 489.99 -0.11 -0.39 -0.20 8.02 495.0 2.40 339.22 494.98 0.07 -0.46 -0.04 7.49 500.0 2.88 337.80 499.98 0.28 -0.54 0.15 9.69 505.0 3.24 336.60 504.97 0.53 -0.64 0.37 7.31 510.0 3.51 337.21 509.96 0.80 -0.76 0.61 5.45 515.0 3.72 335.62 514.95 1.09 -0.89 0.86 4.65 520.0 3.86 336.41 519.94 1.39 -1.02 1.12 2.99 525.0 3.96 337.76 524.93 1.70 -1.15 1.40 2.72 530.0 4.09 336.73 529.92 2.03 -1.29 1.68 2.97 535.0 4.26 336.53 534.90 2.36 -1.43 1.97 3.41 540.0 4.45 335.28 539.89 2.71 -1.59 2.28 4.25 545.0 4.60 336.45 544.87 3.07 -1.75 2.59 3.52 550.0 4.72 337.23 549.86 3.44 -1.91 2.92 2.71 555.0 4.79 337.89 554.84 3.83 -2.07 3.26 1.78 560.0 4.89 337.74 559.82 4.22 -2.23 3.60 2.02 565.0 4.99 338.64 564.80 4.62 -2.39 3.95 2.53 570.0 5.06 339.15 569.78 5.02 -2.54 4.31 1.66 575.0 5.09 340.19 574.76 5.44 -2.70 4.68 1.94 580.0 5.17 341.54 579.74 5.86 -2.84 5.06 2.90 585.0 5.22 343.57 584.72 6.29 -2.98 5.45 3.81 590.0 5.27 345.19 589.70 6.73 -3.10 5.85 3.13 595.0 5.33 344.63 594.68 7.18 -3.22 6.26 1.58 30 CANRIG J- TBU M-06RD Measured Depth (ft) Incl. (�) Azim. (�) True Vertical Depth (ft) Latitude (ft) N(*), S(-) Departure (ft) E(*), W(-) Vertical Section (Inu) (ft) Dogleg Rate (0/100ft) 600.0 5.40 346.96 599.66 7.63 -3.34 6.67 4.58 610.0 5.46 347.15 609.61 8.56 -3.55 7.52 0.63 620.0 5.44 350.06 619.57 9.49 -3.74 8.39 2.77 630.0 5.44 354.58 629.52 10.42 -3.86 9.27 4.28 640.0 5.45 353.49 639.48 11.37 -3.96 10.17 1.04 650.0 5.54 355.04 649.43 12.32 -4.06 11.08 1.74 660.0 5.55 356.60 659.39 13.28 -4.13 12.00 1.51 670.0 5.57 0.68 669.34 14.25 -4.15 12.94 3.96 680.0 5.55 357.37 679.29 15.22 -4.17 13.87 3.21 690.0 5.62 357.09 689.24 16.19 -4.22 14.81 0.75 700.0 5.70 358.77 699.20 17.18 -4.25 15.76 1.84 710.0 5.77 1.80 709.15 18.18 -4.25 16.74 3.11 720.0 5.84 359.86 719.09 19.19 -4.23 17.72 2.08 730.0 5.86 0.64 729.04 20.21 -4.23 18.72 0.82 740.0 6.05 7.69 738.99 21.24 -4.15 19.74 7.55 750.0 6.23 9.24 748.93 22.30 -3.99 20.81 2.45 760.0 6.38 10.19 758.87 23.38 -3.81 21.90 1.83 770.0 6.50 11.38 768.81 24.48 -3.60 23.02 1.79 780.0 6.80 9.73 778.74 25.62 -3.39 24.18 3.56 790.0 7.13 8.60 788.67 26.82 -3.19 25.39 3.57 800.0 7.30 8.64 798.59 28.06 -3.00 26.64 1.70 810.0 7.53 8.40 808.50 29.34 -2.81 27.93 2.32 820.0 7.91 10.56 818.41 30.66 -2.59 29.27 4.78 825.0 8.19 10.97 823.36 31.35 -2.46 29.97 5.72 850.0 8.80 12.37 848.09 34.96 -1.71 33.66 2.58 875.0 9.42 13.89 872.77 38.82 -0.81 37.62 2.66 900.0 9.85 14.76 897.42 42.87 0.22 41.80 1.82 925.0 10.56 15.98 922.03 47.14 1.40 46.23 2.97 950.0 11.43 16.11 946.57 51.73 2.72 50.99 3.48 975.0 12.26 17.69 971.03 56.63 4.21 56.11 3.56 1,000.0 13.00 19.03 995.43 61.82 5.94 61.55 3.18 1,025.0 14.12 19.62 1,019.73 67.35 7.88 67.38 4.51 1,050.0 14.99 1 20.23 1,043.93 73.26 10.02 73.62 3.53 1,075.0 15.93 20.47 1,068.02 79.51 12.34 80.23 3.77 1,100.0 16.71 20.76 1,092.02 86.08 14.81 87.19 3.14 1,125.0 17.71 20.63 1,115.90 93.00 17.42 94.53 4.00 1,150.0 18.51 20.67 1,139.66 100.27 20.16 102.23 3.20 1,175.0 19.32 20.20 1,163.31 107.87 22.99 110.27 3.30 31 CANRIG J- TBU M-06RD Measured Depth (ft) Incl. (o) Azim. (c) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 1,200.0 20.36 19.93 1,186.82 115.84 25.90 118.69 4.18 1,225.0 21.19 19.39 1,210.20 124.19 28.89 127.50 3.41 1,250.0 21.92 19.31 1,233.45 132.85 31.93 136.63 2.92 1,275.0 22.93 19.13 1,256.56 141.86 35.07 146.12 4.05 1,300.0 23.74 19.04 1,279.51 151.22 38.31 155.97 3.24 1,325.0 24.49 18.42 1,302.33 160.89 41.58 166.13 3.17 1,350.0 24.94 18.31 1,325.04 170.81 44.88 176.54 1.81 1,375.0 25.21 18.32 1,347.69 180.87 48.21 187.09 1.08 1,400.0 25.33 18.09 1,370.29 191.01 51.54 197.72 0.62 1,425.0 25.47 18.01 1,392.88 201.20 54.86 208.41 0.58 1,450.0 25.63 17.75 1,415.43 211.46 58.17 219.15 0.78 1,475.0 26.31 17.40 1,437.91 221.90 61.48 230.07 2.79 1,500.0 26.86 1 17.09 1,460.26 232.59 64.80 241.23 2.27 1,525.0 27.43 17.05 1,482.51 243.49 68.14 252.61 2.28 1,550.0 28.27 16.58 1,504.61 254.67 71.52 264.26 3.47 1,575.0 29.25 15.98 1,526.53 266.22 74.89 276.27 4.09 1,600.0 29.85 15.72 1,548.28 278.08 78.26 288.59 2.45 1,625.0 30.48 15.94 1,569.89 290.16 81.69 301.13 2.56 1,650.0 31.34 16.14 1,591.34 302.50 85.24 313.96 3.46 1,675.0 32.02 16.43 1,612.62 315.11 88.92 327.07 2.79 1,700.0 32.53 16.51 1,633.75 327.91 92.70 340.40 2.05 1,725.0 33.42 17.01 1,654.73 340.94 96.63 353.98 3.72 1,750.0 34.25 17.75 1,675.49 354.22 100.79 367.86 3.71 1,775.0 35.04 18.32 1,696.06 367.73 105.19 382.02 3.42 1,800.0 35.84 18.38 1,716.43 381.49 109.75 396.45 3.20 1,825.0 36.69 18.51 1,736.58 395.52 114.43 411.18 3.41 1,850.0 37.37 18.63 1,756.54 409.79 119.22 426.17 2.74 1,875.0 38.16 18.86 1,776.31 424.29 124.14 441.40 3.21 1,900.0 39.15 19.17 1,795.83 439.05 129.23 456.94 4.04 1,925.0 40.09 19.43 1,815.09 454.10 134.50 472.79 3.82 1,950.0 40.76 19.49 1,834.12 469.39 139.90 488.90 2.68 1,975.0 41.63 19.80 1,852.93 484.89 145.44 505.26 3.57 2,000.0 42.41 19.91 1,871.50 500.63 151.12 521.88 3.13 2,025.0 43.11 20.24 1,889.86 516.57 156.95 538.73 2.94 2,050.0 43.98 20.51 1,907.98 532.72 162.95 555.81 3.56 2,075.0 44.70 20.68 1,925.86 549.07 169.09 573.14 2.92 2,100.0 45.47 20.74 1,943.51 565.63 175.35 590.69 3.08 2,125.0 46.43 20.68 1,960.89 582.44 181.71 608.50 3.84 32 CANING TBU M-06RD Measured Dept (ft) Incl. (0) Azim. (0) True Vertical Depth (ft> Latitude (ft) N(*), S(-) Departure (ft) E(*), W(-) Vertical Section (Incr) (ft) Dogleg Rate (0/100ft) 2,150.0 47.32 20.54 1,977.98 599.52 188.13 626.59 3.58 2,175.0 48.11 20.57 1,994.80 616.84 194.62 644.93 3.16 2,200.0 48.90 20.39 2,011.36 634.38 201.17 663.50 3.21 2,225.0 49.97 20.56 2,027.62 652.17 207.82 682.34 4.31 2,250.0 50.81 20.50 2,043.56 670.21 214.57 701.44 3.37 2,275.0 51.66 20.55 2,059.21 688.46 221.41 720.77 3.40 2,300.0 52.72 20.58 2,074.54 706.96 228.35 740.36 4.24 2,325.0 53.55 20.59 2,089.54 725.68 235.38 760.19 3.32 2,350.0 54.54 20.61 2,104.22 744.62 242.50 780.25 3.96 2,375.0 55.42 20.54 2,118.56 763.79 249.69 800.56 3.53 2,400.0 56.40 20.12 2,132.57 783.20 256.89 821.10 4.16 2,425.0 57.17 19.80 2,146.27 802.86 264.02 841.86 3.26 2,450.0 57.81 19.40 2,159.71 822.72 271.10 862.81 2.89 2,475.0 58.03 19.02 2,172.98 842.73 278.07 883.88 1.56 2,500.0 58.04 18.78 2,186.22 862.79 284.94 904.98 0.82 2,525.0 58.00 18.62 2,199.46 882.88 291.74 926.08 0.57 2,550.0 57.94 18.12 2,212.72 902.99 298.41 947.19 1.71 2,575.0 57.96 17.88 2,225.98 923.15 304.96 968.30 0.82 2,600.0 57.67 17.41 2,239.30 943.31 311.38 989.40 1.97 2,625.0 57.51 17.06 2,252.70 963.47 317.63 1,010.45 1.34 2,650.0 57.39 16.75 2,266.15 983.63 323.76 1,031.48 1.15 2,675.0 57.51 16.68 2,279.60 1,003.81 329.82 1,052.51 0.53 2,700.0 57.55 16.29 2,293.02 1,024.04 335.80 1,073.56 1.33 2,725.0 57.68 16.17 2,306.41 1,044.31 341.70 1,094.64 0.66 2,750.0 57.48 1 16.01 2,319.82 1,064.58 347.55 1,115.72 0.97 2,775.0 57.46 15.99 2,333.26 1,084.84 353.36 1,136.77 0.10 2,800.0 57.38 16.13 2,346.72 1,105.09 359.19 1,157.81 0.57 2,825.0 57.36 16.34 2,360.20 1,125.30 365.08 1,178.83 0.71 2,850.0 57.43 16.62 2,373.67 1,145.50 371.05 1,199.86 0.98 2,875.0 57.42 17.00 2,387.13 1,165.67 377.14 1,220.88 1.28 2,900.0 57.47 17.13 2,400.59 1,185.81 383.33 1,241.90 0.48 2,925.0 57.61 17.28 2,414.00 1,205.96 389.57 1,262.95 0.75 2,950.0 57.48 17.59 2,427.42 1,226.09 395.89 1,283.98 1.17 2,975.0 57.22 17.73 2,440.91 1,246.14 402.27 1,304.97 1.14 3,000.0 57.28 17.69 2,454.43 1,266.17 408.67 1,325.92 0.28 3,072.86 57.06 17.84 2,493.93 1,324.48 427.35 1,386.95 0.35 3,168.71 56.93 19.17 2,546.15 1,400.70 452.86 1,466.98 1.17 3,260.90 56.93 19.25 2,596.45 1,473.65 478.28 1,543.80 0.07 33 CANING TBU M-06RD Measured Depth (ft) Incl. (0) Azim. (c) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure Dep (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (0/100ft) 3,357.21 56.94 19.37 2,649.00 1,549.83 504.97 1,624.04 0.10 3,449.22 56.50 19.50 2,699.48 1,622.36 530.56 1,700.50 0.49 3,547.59 56.36 20.67 2,753.88 1,699.34 558.71 1,781.86 1.00 3,643.09 56.22 21.20 2,806.88 1,773.54 587.09 1,860.57 0.48 3,738.50 56.95 21.71 2,859.42 1,847.66 616.22 1,939.37 0.89 3,831.92 57.24 20.45 2,910.18 1,920.84 644.43 2,017.05 1.17 3,927.73 56.90 19.67 2,962.26 1,996.38 672.02 2,096.88 0.77 4,023.52 56.94 19.24 3,014.54 2,072.06 698.75 2,176.65 0.38 4,117.41 57.11 18.68 3,065.65 2,146.55 724.34 2,255.01 0.53 4,210.85 56.76 18.65 3,116.62 2,220.74 749.40 2,332.95 0.38 4,305.63 56.57 18.38 3,168.71 2,295.82 774.55 2,411.79 0.31 4,401.60 56.35 18.19 3,221.73 2,371.77 799.64 2,491.46 0.28 4,497.82 56.46 17.98 3,274.98 2,447.96 824.52 2,571.31 0.21 4,590.07 56.45 17.98 3,325.95 2,521.09 848.26 2,647.92 0.01 4,686.07 56.11 17.62 3,379.24 2,597.12 872.67 2,727.51 0.47 4,780.89 56.39 17.80 3,431.92 2,672.22 896.65 2,806.10 0.33 4,873.99 56.04 18.60 3,483.70 2,745.73 920.82 2,883.17 0.81 4,970.50 56.37 18.84 3,537.38 2,821.69 946.56 2,962.99 0.40 5,066.34 54.46 18.87 3,591.78 2,896.36 972.06 3,041.50 1.99 5,160.45 54.41 19.02 3,646.51 2,968.76 996.91 3,117.66 0.14 5,255.33 54.31 18.18 3,701.80 3,041.84 1,021.50 3,194.42 0.73 5,350.76 54.32 18.69 3,757.47 3,115.38 1,046.02 3,271.60 0.43 5,444.12 54.33 20.27 3,811.91 3,186.87 1,071.31 3,346.97 1.37 5,539.18 54.17 21.09 3,867.45 3,259.05 1,098.55 3,423.45 0.72 5,633.32 54.42 20.75 3,922.40 3,330.45 1,125.84 3,499.19 0.40 5,728.34 54.59 20.87 3,977.57 3,402.77 1,153.33 3,575.86 0.21 5,823.77 54.52 21.26 4,032.91 3,475.32 1,181.27 3,652.87 0.34 5,919.03 54.42 20.51 4,088.27 3,547.75 1,208.91 3,729.68 0.65 6,013.63 54.20 20.29 4,143.46 3,619.76 1,235.69 3,805.90 0.30 6,108.41 54.80 19.40 4,198.50 3,692.34 1,261.88 3,882.53 0.99 6,202.60 54.36 19.55 4,253.09 3,764.71 1,287.47 3,958.82 0.48 6,296.40 54.52 19.64 4,307.64 3,836.59 1,313.06 4,034.64 0.19 6,390.16 54.49 19.97 4,362.08 3,908.41 1,338.93 4,110.46 0.29 6,487.39 54.32 20.99 4,418.67 3,982.48 1,366.59 4,188.88 0.87 6,582.05 54.28 20.16 4,473.91 4,054.45 1,393.60 4,265.10 0.71 6,676.15 54.56 20.11 4,528.66 4,126.30 1,419.95 4,341.06 0.30 6,771.75 54.47 20.06 4,584.15 4,199.41 1,446.68 4,418.33 0.10 6,865.97 54.42 1 19.21 4,638.94 4,271.61 1,472.44 4,494.50 0.74 i 34 CANRIG J ! TBU M-06RD Measured Depth (ft) Incl. (0) Azim. (0) True Vertical Depth (ft) Latitude (ft) N(*), S(-) Departure (ft) E(*), W(-) Vertical Section (Incr) (ft) Dogleg Rate (0/100ft) 6,961.34 54.38 19.33 4,694.46 4,344.81 1,498.03 4,571.60 0.11 7,056.06 54.29 18.79 4,749.69 4,417.54 1,523.16 4,648.14 0.47 7,149.76 54.28 18.21 4,804.38 4,489.69 1,547.30 4,723.89 0.50 7,246.02 54.14 16.48 4,860.68 4,564.21 1,570.58 4,801.75 1.47 7,279.00 54.19 16.53 4,879.99 4,589.85 1,578.17 4,828.44 0.20 7,344.15 54.23 16.64 4,918.09 4,640.50 1,593.26 4,881.20 0.15 7,442.65 49.82 16.80 4,978.68 4,714.84 1,615.59 4,958.67 4.48 7,523.64 48.72 16.95 5,031.52 4,773.58 1,633.40 5,019.92 1.36 7,623.13 45.65 17.14 5,099.13 4,843.34 1,654.79 5,092.72 3.10 7,722.42 40.17 15.20 5,171.83 4,908.22 1,673.67 5,160.19 5.67 7,813.13 38.34 9.69 5,242.09 4,964.22 1,686.08 5,217.54 4.34 7,901.85 36.21 7.09 5,312.69 5,017.36 1,693.95 5,271.08 2.99 7,999.01 30.03 5.08 5,394.02 5,070.10 1,699.65 5,323.74 6.46 8,095.50 26.03 4.33 5,479.18 5,115.28 1,703.39 5,368.58 4.16 8,185.72 22.98 2.47 5,561.26 5,152.62 1,705.65 5,405.46 3.49 8,284.83 19.30 359.56 5,653.69 5,188.34 1,706.36 5,440.41 3.86 8,376.13 17.70 357.81 5,740.27 5,217.30 1,705.71 5,468.46 1.85 8,475.62 11.88 346.90 5,836.44 5,242.42 1,702.81 5,492.26 6.47 8,570.97 12.38 345.59 5,929.66 5,261.88 1,698.04 5,510.13 0.60 8,666.36 14.67 349.14 6,022.40 5,283.65 1,693.22 5,530.23 2.55 8,766.10 12.26 347.30 6,119.39 5,306.38 1,688.51 5,551.30 2.46 8,856.23 12.95 345.91 6,207.35 5,325.51 1,683.95 5,568.89 0.84 8,952.36 13.67 348.30 6,300.90 5,347.09 1,679.02 5,588.78 0.94 9,047.95 12.60 356.73 6,394.00 5,368.56 1,676.13 5,609.04 2.29 9,142.77 12.83 0.65 6,486.49 5,389.42 1,675.67 5,629.24 0.94 9,237.31 13.23 0.57 6,578.59 5,410.74 1,675.89 5,650.06 0.42 9,332.95 14.21 358.53 6,671.50 5,433.42 1,675.70 5,672.10 1.14 9,426.34 13.49 355.61 6,762.18 5,455.74 1,674.57 5,693.58 1.08 9,521.29 12.69 356.31 6,854.66 5,477.18 1,673.05 5,714.11 0.86 9,616.49 12.22 352.85 6,947.62 5,497.61 1,671.13 5,733.57 0.93 9,711.14 12.75 2.19 1 7,040.05 5,517.99 1,670.28 5,753.22 2.20 9,807.53 14.74 2.53 7,133.67 5,540.86 1,671.23 5,775.71 2.07 9,899.15 15.42 358.71 7,222.14 5,564.68 1,671.47 5,798.96 1.31 9,991.69 13.72 356.15 7,311.71 5,587.93 1,670.45 5,821.37 1.96 10,079.27 11.68 354.54 7,397.14 5,607.11 1,668.91 5,839.70 2.36 10,178.77 13.89 355.44 7,494.16 5,629.04 1,667.01 5,860.62 2.23 10,278.10 13.61 354.16 7,590.65 5,652.55 1,664.87 5,883.03 0.42 10,372.77 12.66 352.41 7,682.84 5,673.92 1,662.36 5,903.27 1.08 CANOIG 35 J_ TBU M-06RD Measured Depth (p Incl. (0) Azim. (c) True Vertical Depth (,) Latitude (ft) NO S(-) Departure + (ft) EO W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 10,468.02 12.94 356.07 7,775.72 5,694.91 1,660.25 5,923.23 0.90 10,563.92 12.40 350.83 7,869.29 5,715.79 1,657.87 5,943.02 1.32 10,659.78 9.05 335.79 7,963.48 5,732.84 1,653.14 5,958.55 4.53 10,752.30 5.87 315.50 8,055.22 5,742.85 1,646.84 5,966.86 4.41 10,847.20 6.25 283.27 8,149.62 5,747.49 1,638.41 5,969.47 3.56 10,943.65 8.24 263.31 8,245.31 5,747.89 1,626.44 5,967.14 3.30 11,037.22 8.56 237.91 8,337.91 5,743.41 1,613.87 5,959.92 3.95 11,134.00 12.46 218.57 8,433.07 5,731.41 1,601.25 5,945.36 5.38 11,225.55 16.44 204.25 8,521.74 5,711.87 1,589.76 5,923.72 5.81 11,323.62 20.35 202.84 8,614.78 5,683.49 1,577.44 5,893.28 4.01 11,418.51 21.36 202.99 8,703.45 5,652.37 1,564.28 5,859.99 1.07 11,513.74 24.24 206.01 8,791.23 5,618.83 1,548.93 5,823.84 3.26 11,608.77 27.37 205.79 8,876.78 5,581.62 1,530.87 5,783.49 3.29 11,703.69 28.29 203.15 8,960.72 5,541.29 1,512.54 5,740.05 1.62 11,799.05 32.36 200.24 9,043.02 5,496.55 1,494.82 5,692.45 4.53 11,892.09 38.09 198.08 9,119.00 5,445.86 1,477.28 5,639.11 6.31 11,986.67 44.07 199.31 9,190.26 5,387.03 1,457.33 5,577.29 6.38 12,081.44 50.47 200.19 9,254.53 5,321.56 1,433.79 5,508.17 6.79 12,175.61 53.62 199.46 9,312.45 5,251.71 1,408.63 5,434.43 3.40 12,272.50 56.51 197.96 9,367.93 5,176.48 1,383.17 5,355.38 3.24 12,367.27 57.54 197.31 9,419.51 5,100.71 1,359.09 5,276.13 1.23 12,462.23 60.91 199.57 9,468.09 5,023.35 1,333.26 5,194.92 4.10 12,552.72 65.85 197.48 9,508.63 4,946.66 1,307.61 5,114.40 5.84 12,649.66 72.45 193.41 9,543.12 4,859.39 1,283.57 5,023.95 7.85 12,744.77 74.76 192.88 9,569.97 4,770.54 1,262.83 4,932.71 2.49 12,839.74 74.87 191.59 9,594.84 4,680.97 1,243.41 4,841.08 1.31 12,932.66 73.92 192.33 9,619.84 4,593.42 1,224.86 4,751.60 1.28 13,029.17 75.39 193.62 9,645.38 4,502.73 1,203.95 4,658.53 2.00 13,123.84 79.82 195.47 9,665.70 4,413.26 1,180.72 4,566.13 5.05 13,218.65 84.45 198.32 9,678.67 4,323.44 1,153.43 4,472.45 5.72 13,322.14 83.39 198.79 9,689.63 4,225.88 1,120.69 4,370.00 1.12 13,416.39 82.92 198.11 9,700.86 4,137.11 1,091.07 4,276.83 0.87 13,511.09 83.67 198.13 9,711.92 4,047.72 1,061.82 4,183.13 0.79 13,606.39 83.10 199.58 9,722.89 3,958.14 1,031.23 4,088.93 1.63 13,701.97 84.92 198.41 9,732.87 3,868.26 1,000.30 3,994.38 2.26 13,796.67 85.08 197.70 9,741.12 3,778.57 971.06 3,900.39 0.76 13,892.84 84.88 196.74 9,750.17 3,687.03 943.04 3,804.87 1.02 13,918.14 85.05 196.54 9,752.39 3,662.88 935.82 3,779.72 1.02 C "I IG 36 J TBU M-06RD Measured Dept (ft) Incl. (c) Azim. (0) True Vertical Depth (ft) Latitude (R) N(*), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (0/100ft) 14,013.45 85.99 197.04 9,759.84 3,571.91 908.37 3,684.89 1.11 14,108.50 85.25 196.60 9,767.10 3,481.20 880.95 3,590.32 0.91 14,204.01 84.94 196.69 9,775.26 3,390.02 853.69 3,495.33 0.34 14,298.50 84.69 195.93 9,783.80 3,299.71 827.26 3,401.37 0.84 14,392.93 84.76 196.17 9,792.49 3,209.35 801.26 3,307.47 0.26 14,487.10 84.63 195.75 9,801.19 3,119.19 775.47 3,213.82 0.46 14,581.70 85.56 196.56 9,809.28 3,028.66 749.24 3,119.69 1.30 14,676.75 85.31 195.87 9,816.85 2,937.68 722.78 3,025.08 0.77 14,771.50 85.01 195.68 9,824.84 2,846.83 697.12 2,930.77 0.38 14,867.10 84.45 194.62 9,833.62 2,754.94 672.25 2,835.63 1.25 14,964.56 83.51 194.61 9,843.84 2,661.16 647.79 2,738.74 0.96 15,056.97 82.70 195.08 9,854.94 2,572.47 624.28 2,647.04 1.01 15,153.04 82.45 194.95 9,867.35 2,480.46 599.60 2,551.83 0.30 15,245.60 81.96 194.89 9,879.91 2,391.85 576.00 2,460.17 0.53 15,341.19 81.77 194.85 9,893.43 2,300.39 551.72 2,365.58 0.20 15,435.57 1 82.28 194.45 9,906.53 2,209.97 528.07 2,272.15 0.68 15,472.00 1 82.28 194.45 9,911.42 2,175.01 519.06 2,236.06 0.01 Note: Survey @ 15,472' is a projection to bit depth. 37 CANF2IG J TBU M-06RD 4.2 Bit Record BIT NO. SIZE TYPE SIN JETS/ IN OUT Feet HRS AVE ROP CONDITION TFA Drilled Ft/HR Mill 8.5" Window Mill / Baker Oil Tools 12619457 N/A 7,279' 7,340' 61' 13.50 9.96 — 1 8.5" HDBS MMD75DC 12896068 7x12 / 0.7731 7,340' 11,072' 3,732' 35.18 146.0 1 -4 -BT -S -X -1 -NO -PR 2 8.5" HDBS MMD75DC 12896069 7x12 / 0.7731 11,072' 12,424' 2,340' 22.66 48.15 8-4-RO-C-X-1-WT-PR 3 8.5" HDBS MMD75DC 12920423 7x12/ / 0.7731 x12,424' 13,272' 848' 22.45 70.47 1 -2 -CT -N -X -1 -WT -PR 4 8.5" Varel V71 1 PDG1 HRU 4009435 4x12,4x11 /0.8130 13,272' 13,922' 650' 13.65 87.36 4 -2 -BT -C -X -I -CT -PR 5 8.5" HDBS MM75D 12670051 5x14 / 0.7517 13,922' 15,472' 1,550' 13.40 140.70 2 -1 -CT -C -X -I -SD -TD 5RR 8.5" HDBS MM75D 12670051 5x14 / 15,472' 15,472' — — — — 0.7517 38 CANRIG TBU M-06RD 4.3 Mud Record Contractor: Halliburton Baroid Date Depth MD TVD MW (ppg) VIS (s/Qt) PV YP Gels FL (cc) FC Sols (%) OIW Ratio Sd (%) ASG AgNO3 CaCl2 (ppbl) Lime (ppb) ENVIROMUL 6/5/2017 7,340 4,870 8.90 72 22 13 10/23/27 4.0 3/0 8.3 80.6/19.4 - 2.973 1.5 14.03 9.32 6/6/2017 7,340 4,870 8.95 110 23 18 14/29/33 4.0 3/0 9.3 80.9/19.1 - 2.816 1.5 14.03 8.81 6/7/2017 8,129 5,225 8.85 67 22 12 10/29/33 3.6 3/0 7.9 80.1/19.9 - 2.993 1.5 14.03 8.81 6/8/2017 9,924 7,220 9.00 57 20 12 9/22/25 3.6 3/0 8.3 81.1/18.9 3.137 1.5 13.54 8.03 6/9/2017 11,072 8,371 8.95 55 19 11 10/20/22 3.6 3/0 8.0 82.2/17.8 0.01 3.099 1.7 14.51 10.23 6/10/2017 11,072 8,371 8.95 63 20 11 8/18/20 3.6 3/0 8.1 83.3/16.7 0.01 3.110 1.6 15.49 8.81 6/11/2017 11,250 8,545 9.00 68 21 12 8/22/26 3.6 3/0 7.2 82.4/17.6 0.01 3.436 1.7 19.85 7.38 6/12/2017 12,153 9,046 9.00 62 23 11 8/23/26 3.4 3/0 8.6 84.4/15.6 0.01 3.039 1.9 19.85 10.88 6/13/2017 12,424 9,423 9.05 77 23 1 11 1 11/24/27 3.4 1 3/0 1 8.6 1 83.8/16/2 0.01 1 3.099 1.8 19.85 9.84 6/14/2017 12,658 9,423 9.00 62 22 1 14 1 9/21/23 3.4 1 3/0 1 8.0 83.3/16.7 0.01 3.132 1.8 22.76 9.19 6/15/2017 13,021 9,632 9.00 1 63 23 11 9/20/23 3.4 0/3 8.0 84.4/15/6 0.01 3.165 1.8 22.76 6.86 6/16/2017 13,272 9,682 9.05 1 68 24 13 10/22/25 3.4 0/3 8.7 84.4/15.6 0.01 3.119 1.7 17.91 9.97 6/17/2017 13,272 9,682 9.05 82 24 12 10/23/26 3.4 0/3 8.7 84.4/15.6 0.01 3.119 1.7 17.91 9.97 6/18/2017 13,272 9,682 9.05 97 25 12 9/21/23 3.8 0/3 9.3 85.4/14.6 0.01 3.082 1.9 16.94 12.56 6/19/2017 13,424 9,690 9.05 89 25 13 9/24/37 3.6 0/3 8.7 84.9/15.1 0.01 3.133 1.8 16.94 10.10 6/20/2017 13,880 9,700 9.05 68 29 15 12/26/30 3.6 0/3 9.2 84.3/15.7 0.01 2.998 2.0 16.94 7.38 6/21/2017 13,922 9,702 9.05 90 26 14 11/26/30 2.8 0/3 9.7 83.6/16.4 0.01 2.895 1 1.9 14.03 9.45 6/22/2017 13,922 9,702 9.05 90 31 16 15/29/34 2.8 0/3 10.2 1 84.1/15.9 1 0.01 2.790 1 1.9 15.97 1 6.73 6/23/2017 15,003 9,851 9.05 76 29 1 16 1 14/26/28 3.8 1 0/3 9.7 83.6/16.4 0.01 2.889 1.8 15.00 8.68 6/24/2017 15,472 9,851 9.10 68 28 12 9/20/22 3.8 1 0/3 10.2 83.0/17.0 0.01 2.843 1.7 14.03 8.03 6/25/2017 15,472 9,851 9.25 68 25 12 11/22/24 3.8 0/3 10.7 83.4/16.6 0.01 2.913 1.9 15.97 8.16 6/26/2017 15,472 9,851 9.30 85 27 12 9/20/22 3.8 0/3 10.2 83.0/17.0 0.10 3.082 1.5 13.06 5.44 6/27/2017 15,472 9,851 9.35 103 28 12 9/20/23 4.2 0/3 10.9 82.9/17.1 0.10 3.032 1.4 12.09 4.92 6/28/2017 15,472 9,851 9.40 128 28 13 10/22/26 4.2 0/3 10.7 82.9/17.1 0.10 3.082 1.8 14.51 5.44 6/29/2017 15,472 9,851 9.40 123 30 14 10/20/24 4.2 0/3 10.2 83.0/17.0 0.10 3.197 1.7 14.03 5.96 6/30/2017 15,472 9,851 9.45 151 30 14 10/21/23 4.0 0/3 10.4 82.9/17.1 0.10 3.197 1.7 14.03 5.57 7/1/2017 15,472 9,851 9.45 102 29 15 10/22!24 4.0 0/3 10.7 82.9/17.1 0.10 3.200 1.6 13.54 5.57 Abbreviations: MW = Mud Weight Gels = Gel Strength Sols = Solids pH = Acidity VIS = Funnel Viscosity FL = Water or Filtrate Loss Sd = Sand content Cl = Chlorides PV = Plastic Viscosity FC = Filter Cake MBT = Methylene Blue Ca = Hardness Calcium YP = Yield Point O/W = Oil to Water ratio Alk, Pm = Alkalinity, Mud nr = Not Recorded _ _ _ _1'G 39 4.4 Drillina Proaress 7,000 8,000 9,000 10,000 11,000 12,000 13,000 14,000 15,000 16,000 J — TBU M-06RD Days Vs. Depth 011 011 011 011 011 S1 011 011 011 011 011 011 011 011 011 011 011 011 011 011 011 011 b\b\'L b\1\'L b\�\'L \41' b\1o\1' ro\11\'L (0\11\,L �0\14\ �o\1p\1" �o\14T �o\ .\V 0\11\'L �0\1$\V 6�,Y4V �0\10\V b�,ti4V 4V\p 6�,13\v `o\,tit.\V �o\11\1" (o\ry4V 40 CANRIG 5 SHOW REPORTS TBU M-06RD CANRIG 41 CA RIG Ureiurcc Tt'.e�'oi urr 1. ro. Hydrocarbon Show Report # Operator: Hilcorp Alaska, LLC Well: TBU M-06RD API Number 50-733-20585-01 -00 Field: McArthur River Field Date: 6/12/2017 Rig: Steelhead 51 Time: 12:20 PM County: Kenai Borough I End State: Alaska11660' MD 11760' MD Country: USA 8922' TVD 9009' TVD Averages Pixler Plot Before During After Maximum ROP (f ph) 65 ft/hr 80 ft/hr 101 ft/hr 212 ft/hr i0000 WOB 11 klbs 15 klbs 20 klbs 26 klbs RPM 144 rpm 138 rpm 138 rpm 157 rpm low PP 2712 psi 2696 psi 2705 Psi 2754 psi Mud Weight 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal o ,00 Chloride Total Gas 40 22 29 47 0 C1 m 8,326 4,401 6,815 11,479 C2 m 154 106 111 406 1 2 3 4 01= c,x9 C„G< CIMS C3 m 77 76 44 173 C4 m 43 50 31 100 C5 m 6 14 8 37 Lithology Conglomerate Sand (11730'-11860') = overall light to medium olive gray to light olive brown; dominantly milky, sub -transparent to transparent, white to off white individual grains, scattered light to medium green; trace scattered red to red -orange; dominantly upper coarse to lower coarse, scattered upper medium to occasionally sub -granular sized fragments; very poorly to poorly sorted; dominantly very angular to angular, rare sub -angular to sub -rounded; dominantly low to very low sphericity, scattered irregular; unconsolidated; quartz framework with rare dark lithics; light to medium green fragments have cryptocrystalline, chert -like texture; petroleum odor masked by oil based mud; moderately fast yellow streaming fluorescence; dull yellow moderately weak cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderately dull yellow residual cut fluorescence; hydrocarbon indicators possibly masked by oil based mud. Cuttings Anal sis Odor Inone Fluorescence Cut Fluorescence Residual Cut Stain Amount Distribution Intensity Color 20% Type Color slow Amount Color minor Amount Color minor patchyIntensity weak ft. brn to straw brown mod/wk yellow Residual Fluorescence Cut el/wht Intesity Color weak -mod Colo rl straw -brown dull yellow Oil Show Rating 0.8 Free Oil in Mud masked by oil base mud Comments Report by: Allen Ode aard / Garnet Knopp CANRIG DRILLIAc TECH\nLL y LTD HydrocarbonShow Report # 2 Operator: Hilcorp Alaska, LLC Well: TBU M-06RD API Number 50-733-20585-01 -00 Field: McArthur River Field Date: 6/13/2017 Rig: Steelhead 51 Time: 3:36 AM County: Kenai Borough De th Start End State: Country: Alaska USA 12000' MD 12350' MD 9199' TVD 9410' TVD Averages Pixler Plot Before During After Maximum ROP (fph) 126 fUhr 84 ft/hr 31 ft/hr 383 ft/hr 10000 WOB 20 klbs 20 klbs 21 klbs 66 kibs RPM 151 rpm 142 rm 144 rm 181 rpm 10w PP 2802 psi 2761 psi 2978 psi 3004 psi Mud Weight 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal E loo Chloride 10 Total Gas 46 32 17 64 C1 m 8,896 5,657 3,024 11,991 C2 m 798 658 198 11449 , 3 3 4 CM 0110: C14. C'. C3 m 387 248 67 782 C4 m 168 119 40 313 CS m 60 49 19 119 Lithology Sand / Conglomerate (12220'-12310') = light olive gray to light olive brown sand, quartz dominant, with lesser cream to tan colored feldspar and very minor black lithics; upper fine to lower very coarse grained with some granule sized grains; poor to fair sorting; sub -angular to rounded; low clay content; occasional sub- angular fragments of coal and gray/ black laminated tuffaceous siltstone; some consolidated sandstone clusters showing moderate yellow streaming fluorescence; weak yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; dull yellow residual cut fluorescence. Cuttings Anal sis Odor Ino,ne Fluorescence Cut Fluorescence Residual Cut Stain Amount Amount minor Distribution Color brown Intensity Cut Color Color I straw -brown 20% Type Intensity Color streaming Amount minor Color ft. brn to straw clusters moderate moderate light Residual Fluorescence el/wht yellow Intesity Color weak dull yellow Oil Show Rating 0.6 Free Oil in Mud masked by oil base mud Comments Report by: Allen Ode aard / Garnet Knopp CANRIG Hydrocarbon Show Report # 3 Operator: Hilcorp Alaska, LLC Well: TBU M-06RD API Number 50-733-20585-01 -00 Field: McArthur River Field Date: 6/14/2017 Rig: Steelhead 51 Time: 3:36 AM County: Kenai Borough De th Start End State: Alaska 12425' MD 12525' MD Country: USA 9449' TVD 9496' TVD Averages Pixler Plot Before During After Maximum ROP (f ph) 28 ft/hr 72 ft/hr 93 ft/hr 215 ft/hr 0000 WOB 22 klbs 17 klbs 16 klbs 30 klbs it RPM 148 rpm 103 rpm 92 rpm 170 rpm low PP 2940 psi 2971 psi 2931 psi 3072 psi E Mud Weight 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal Chloride 10 Total Gas 20 20 28 37 C1 m) 3,360 3,780 5,937 7,752 C2 m 445 231 239 512 0,� 0,�3 0„0< 01x6 C3 m 99 56 109 145 C4 m 59 20 4f 55 CS m 27 0 6 27 Lithology Sand / Tuffaceous Sandstone (12400'- 12490') = light olive gray to medium gray, abundant in clear to blue quartz and tan feldspar with minor black lithic grains; upper fine to upper coarse grained to some conglomerate grains; fair sorting; sub -angular to rounded; with occasional consolidated sandstone clusters; minor sub -angular fragments of tuffaceous siltstone and coal; clusters show moderate light yellow streaming fluorescence and dull cut fluorescence. Cuttings Anal sis Odor Inone Fluorescence Cut Fluorescence Residual Cut Stain Amount Amount y. minor Distribution Color brown Intensity Cut Color Color I straw -brown 20% Type Intensity Color streamin Amount Color minor clusters moderate ft. brn to straw weak light Residual Fluorescence el/wht yellow Intesity Color weak dull yellow Oil Show Rating 0.6 Free Oil in Mud masked by oil base mud Comments Report by: Allen Ode aard / Garnet Knopp CANRIG 1) u,,; 7"ecrv�-uurz:r Ln,. Hydrocarbon Show Report # 4 Operator: Hilcorp Alaska, LLC Well: TBU M-06RD API Number 50-733-20585-01-00 Field: McArthur River Field Date: 6/15/2017 Rig: Steelhead 51 Time: 4:30 AM County: Kenai Borough De th Start End State: Alaska 12680' MD 12770' MD Country: USA 9551' TVD 9576' TVD Averages Pixler Plot Before During After Maximum ROP (f h) 55 ft/hr 75 ft/hr 107 ft/hr 134 ft/hr +0000 WOB 21 klbs 22 klbs 20 klbs 31 klbs RPM 98 rpm 97 rpm 95 rpm 149 rpm +ow PP 2925 psi 2884 psi 2906 psi 2965 psi Mud Weight 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal E ,00 Chloride m Total Gas 23 23 27 46 C7 m 4,046 3,913 5,500 8,436 C2 m) 493 385 361 841 1 2 3 4 CM2 ccm3 01� CIM5 C3 m 110 128 103 275 C4 m) 52 72 46 185 C5 m 6 26 10 88 Lithology Sand / Tuffaceous Sandstone (12640'- 12740') = pale yellowish brown to dark gray sand, quartz - dominant; with lesser milky white and pink feldspar and black lithics; upper fine to very coarse grained with abundant conglomerate grains; poor to fair sorting with larger clasts predominantly quartz; sub- angular to sub -rounded; minor sub -angular fragments of tuffaceous siltstone and claystone; occasional consolidated sandstone clusters showing mild yellow streaming fluorescence and dull cut fluorescence and residual stain. Cuttings Anal sis Odor Inone Fluorescence Cut Fluorescence Residual Cut Stain Amount Amount minor Distribution Color brown Intensity Cut Color Color I straw -brown 20% Type I streamin_g Intensity weak Color light yellow Amount minor Color ft. brn to straw clusters weak Residual Fluorescence el/wht Intesity Color weak dull yellow Oil Show Rating 0.4 Free Oil in Mud Imasked by oil base mud Comments Report by: Allen Ode aard / Garnet Knopp CANRIG 1)......, T,,,,,, ,;, Ln.. Hydrocarbon Show Report # 5 Operator: Hilcorp Alaska, LLC Well: TBU M-06RD API Number 50-733-20585-01-00 Field: McArthur River Field Date: 6/15/2017 Rig: Steelhead 51 Time: 10:42 AM County: Kenai Borough Depth Start jEnd State: Alaska12790' MD 12870' MD Country: USA 9581' TVD 9603' TVD Averages Pixler Plot Before During After Maximum ROP (f h) 107 ft/hr 79 ft/hr 25 ft/hr 148 ft/hr lowo WOB 20 klbs 21 klbs 9 kilos 33 klbs RPM 95 rpm 106 rpm 128 rpm 146 rpm loon PP 2905 psi 2874 psi 2725 psi 2944 psi E 100 Mud Weight 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs! al 9.0 lbs/gal Chloride 10 Total Gas 27 53 18 115 C1 (ppm) 5,430 10,109 3,217 23,278 C2 m 383 640 134 1,539 1 1 2 3 4 C,= <,M cl� c,x, C3 m 104 395 64 973 C4 m) 47 168 39 394 C5 m 11 55 11 120 Lithology Conglomerate Sandstone / Conglomerate Sand / Tuffaceous Sandstone (12740'-12880') = very light gray; clast size pebble to very coarse upper to coarse lower; angular bit impacted fragments to sub - rounded; very poor to moderate developed sphericity; moderate sorting; polished to chip texture; mature nature; non to very weak siliceous cement; unconsolidated; dominant grain support; slight visible clay matrix; composed of predominantly quartz with some lithic fragments; fair to good porosity and permeability; moderate yellow streaming fluorescence; weak yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; dull yellow residual cut fluorescence. Cuttings Anal sis Odor Inone Fluorescence Cut Fluorescence Residual Cut Stain Amount Distribution Intensity Color 35%, Type Intensity Color streamin Amount minor Color ft. brn to straw Amountminor Color clusters moderate brown weak ellow Residual Fluorescence Cut ellow Intesity Colorlyellow weak Color straw -brown Oil Show Rating 10.9 Free Oil it Imasked by oil base mud Comments Report by: Allen Ode aard / Garnet Knepp CAM ,IG Hydrocarbon Show Report # 6 Operator: Hilcorp Alaska, LLC Well: TBU M-06RD API Number 50-733-20585-01 -00 Field: McArthur River Field Date: 6/16/2017 Rig: Steelhead 51 Time: 13:13:00 PM County: Kenai Borough Depth istart End State: Alaska 13030' MD 13270' MD Country: USA I 9645' TVD 9685' TVD Averages Pixler Plot Before During After Maximum ROP (fph) 33 ft/hr 60 ft/hr 81 ft/hr 132 ft/hr 10 N WOB 22 klbs 20 klbs 16 klbs 29 klbs RPM 108 rm 118 rm 142 rm 141 rpm 10w PP 2941 psi 2893 psi 3105 psi 2953 psi Mud Weight 9.0 lbs/gal 9.0 lbs/gal 9.1 lbs al 9.1 lbs/gal E 100 Chloride 10 Total Gas 17 24 40 53 C1 m) 2,939 4,411 8,436 10,304 C2 m 218 279 287 712 2 3 4 C= 0M= 0144 0+� C3 m 58 120 134 350 C4 m 28 56 50 148 CS m 4 20 11 61 Lithology Tuffaceous Sandstone / Tuffaceous Siltstone (13120'-13240') = light olive gray to medium gray quartz rich sandstones; grain size is upper very fine to lower coarse; angular to sub -rounded; low to moderate sphericity; well to moderate sorting; sandstone nodules contain a volcanic ash that is white to bluish white in color and clumpy / soft texture; sample contains some black lithics, lower coarse to upper coarse in size, sub -rounded to rounded, with moderate sphericity; tuffaceous siltstone is light gray to medium gray, quartz rich, lower very fine in size, very well sorted, firmly friable, sub -angular to rounded massive cuttings; good to moderate yellow streaming fluorescence; yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderate yellow residual cut fluorescence. Cuttings Anal sis Odor Inone Fluorescence Cut Fluorescence Residual Cut Stain Amount Distribution Intensity Color ht brown 40% Type Intensity Color streamin Amount minor Color ft. brn to straw Amount Color minor clusters mod -high brown moderate yellow Residual Fluorescence Cut yellow Intesity Color moderate Color dark straw-li ellow Oil Show Rating0.9 Free Oil in Mud masked by oil base mud Comments Report by: Allen Ode aard / Garnet Knepp CANRIG DXILLIM1f. TEIHNOL(1fY LT11. Hydrocarbon Show Report # 7 Operator: Hilcorp Alaska, LLC Well: TBU M-06RD API Number 50-733-20585-01-00 Field: McArthur River Field Date: 6/20/2017 Rig: Steelhead 51 Time: 14:51:00 PM County: Kenai Borough De th Start I End State: Alaska 13605' MD 13740' MD Country: USA 9722' TVD 9736' TVD Averages Pixler Plot Before During After Maximum ROP f h 108 ft/hr 113 ft/hr 68 ft/hr 406 ft/hr 1ama WOB 15 klbs 15 klbs 9 klbs 44 klbs RPM 157 rpm 139 rpm 145 rpm 172 rpm low PP 2999 psi 2978 psi 3029 psi 3066 psi E 100 Mud Weight 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal Chloride tU Total Gas 33 18 10 52 C1 m 7,352 3,532 1,808 10,396 C2 m 284 146 27 597 1 2 3 0 G1103 CIX3 =» CMS C3 m 113 85 22 323 C4 m 34 38 15 139 C5 m - 7 - 43 Lithology Tuffaceous Siltstone / Volcanic Ash (13,540'-13,700') = tuffaceous siltstn It gry to med gry; qtz rich, Iwr VF grained, v well sorted, firmly friable, ang to subang to rnded massives; volcanic ash is It olive gray - med olive gray, cly szd particulates, v well sorted, pulverulent tenacity, smth text, laminae structure; blk lithics, Iwr to upper med in size, subang to subrded, low sphericity; dominant coal seam shows at 13,590', gryish blk to blk, ang to subang, poorly sorted, conch fract, dense tenacity, dull luster; qtz sd nodules, It brn tan to med brn tan in color, subrded to rded, upper med to upper coarse in size, well to mod sorted, mod to high sphericity, silica cement; sands are It olive gray to med olive gray, unconsol, poorly sorted, Iwr fine to Iwr med in size, ang to subrded; common to scattered ylw to ylw-grn light sample fluorescence; good to mod ylw stream fluorescence; ylw cut fluorescence; dk straw to It brn vis cut; faint brn to med straw residual cut ring; mod y1w residual cut fluorescence. Cuttings Anal sis Odor Inone Fluorescence Cut Fluorescence Residual Cut Stain Amount Distribution Intensity Color i ht brown 20%30% Typestreamin Intensity Color Amount Color minor Amount Color minor clusters mod -high brown -straw brown moderate ellow Residual Fluorescence Cut yellow Intesity Color moderate Color dark straw -11 ellow Oil Show Rating0.4-0.6 Free Oil in Mud masked by oil base mud Comments Report by: Allen Ode aard / Garnet Kropp CANRIG Diw.i.is,; Tec wuoi.nrs L, ,, Hydrocarbon Show Report # 8 Operator: Hilcorp Alaska, LLC Well: TBU M-06RD API Number 50-733-20585-01-00 Field: McArthur River Field Date: 6/23/2017 Rig: Steelhead 51 Time: 16:34:00 PM County: Kenai Borough De th Start End State: Alaska 13820' MD 14710' MD Country: USA 9743' TVD 9819' TVD Averages Pixler Plot Before During After Maximum ROP (f h) 64 ft/hr 126 ft/hr 114 ft/hr 303 ft/hr lOMO WOB 28 klbs 12 klbs 8 klbs 66 klbs RPM 124 rpm 101 rpm 96 rpm 160 rpm +ow PP 3014 psi 3292 psi 3423 psi 3652 psi Mud Weight 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal E Chloride Total Gas 25 27 12 72 10 C1 m) 5,168 5,557 1,905 15,862 id it PROD i �Clrll FE C2 m 172 258 46 727 1 z s , cl= cuts cls' c,�, C3 m 110 139 46 456 C4 m) 56 70 37 222 CS m 13 25 19 72 Lithology Sand / Tuffaceous Sandstone (14480' - 14600') = overall light brown to light olive gray, light olive brown; milky, transparent, light gray and trace light green individual grains; upper fine to lower medium grained; dominantly quartz framework with rare micas and dark lithics; tuffaceous sandstone has a white mushy clayey matrix, which also contains trace to 10% off-white ash; friable to very friable to soft; crumbly tenacity; sub -angular to sub -rounded to rounded; moderate to moderately low sphericity; fair to poor sorting; non- calcareous; petroleum odor masked by oil based mud; even moderately bright yellow sample fluorescence; whitish yellow cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based mud. Cuttings Anal sis Odor Inone Fluorescence Cut Fluorescence Residual Cut Stain Amount Amount minor Distribution Color brown Intensity Cut Color Color dark straw -light brown 20%40%Type Intensity Color cut Amount minor Color light brown clusters moderate moderate wht- Iw Residual Fluorescence yellow Intesity Color mod -hi h bri ht yellow Oil Show Rating 0.4-0.7 Free Oil in Mud masked by oil base mud Comments Report by: Allen Ode aard / Garnet Knopp CAI�IRIG ua�� � �.,; n.,,,..�n �„. coo. Hydrocarbon Show Report # 9 Operator: Hilcorp Alaska, LLC Well: TBU M-06RD API Number 50-733-20585-01-00 Field: McArthur River Field Date: 6/24/2017 Rig: Steelhead 51 Time: 10:35 PM County: Kenai Borough De th Start End State: Alaska 14795' MD 15472' MD Country: USA 9827' TVD 9911' TVD Averages Pixler Plot Before During After Maximum ROP (f h) 160 ft/hr 148 ft/hr - 601 ft/hr 10000 WOB 14 klbs 13 klbs - 17 klbs RPM 97 rpm 102 rpm - 114 rpm 1000 PP 3509 psi 3416 psi - 3632 psi Mud Weight 9.1 lbs/gal 9.1 lbs/gal - 9.1 lbs/gal E 100 Chloride Total Gas 45 27 49 10 — C1 m 9,516 4,899 9,809 C2 m 498 544 - 1,050 1 2 3 4 0i� 0,a4 m,ae C3 m 274 149 - 389 C4 m 127 67 384 C5 m 50 26 160 Lithology Sand (15240'-15340') = light olive gray to medium gray sand dominated by clear to smoky quartz with minor dusky brown and black lithics and varying levels of clayey matrix; lower medium to upper coarse grained, with a few conglomerate quartz clasts; subangular to rounded; moderate sphericity; semi - consolidated sandstone clusters of same mineralogy; minor firm subangular dark gray fragments of tuffaceous siltstone and soft, light gray tuffaceous claystone; moderate whitish yellow streaming and cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based mud. Cuttings Anal sis Odor Inone Fluorescence Cut Fluorescence Residual Cut Stain Amount Amount trace Distribution Color brown Intensity Cut Color ColorldarkLtraw-li ht brown 25%50% Type Intensity Color streamin Amount Color minor clusters moderate I brown -straw moderate Iw-wht Residual Fluorescence yellow Intesity Color mod -hi h bri ht Iw Oil Show Rating0.4-1.0 Free Oil in Mud masked by oil base mud Comments Ended at TD. Report by: Allen Ode aard / Garnet Knopp 6 DAILY REPORTS TBU M-06RD CANRIG CK Hilcorp Alaska LLC Trading Bay Unit DAILY WELLSITE REPORT TBU M-06RD CCANRIG REPORT FOR S. Hauck / H. Soule DATE June 04,2017 DEPTH PRESENT OPERATION RIHw/whipstock TIME 23:55:53 YESTERDAY 0 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SO OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY RIH with junk basket, POOH with junk basket, Rerun junk basket until clean, Make up Whipstock BHA, Perform SUMMARY shallow hole test, Make up rest of BHA and RIH w/ whipstock. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2625 REPORT BY M. Skiles Hilcorp Alaska LLC MacArthur River DAILY WELLSITE REPORT TBU M-06RD CC 4NRIG REPORT FOR S. Hauck / H. Soule DATE Jun 05, 2017 DEPTH 7340' PRESENT OPERATION POOH TIME 23:48:11 YESTERDAY 7280' 24 HOUR FOOTAGE 60' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 81/2" Mill 13346364 7279 7340' 61' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 36.0 @ 7327' 0.1 @ 7293' 10.0 2.44340 FT/HR SURFACE TORQUE 17013 @ 7318' 12939 @ 7281' 15158.3 14594.54590 AMPS WEIGHT ON BIT 21 @ 7331' 1 @ 7281' 12.5 1.95631 KLBS ROTARY RPM 103 @ 7281' 87 @ 7293' 96.1 97.15456 RPM PUMP PRESSURE 2522 @ 7337' 1321 @ 7286' 1640.2 2502.06982 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SO OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 13 @ 732T 1 @ 7293' 5.0 TRIP GAS CUTTING GAS 0 @ 7340' 0 @ 7340' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 3403 @ 7327' 139 @ 7280' 1016.7 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 7340' 0 @ 7340' 0.0 AVG PROPANE (C-3) 0 @ 7340' 0 @ 7340' 0.0 CURRENT 1.3 BUTANE (C-4) 0 @ 7340' 0 @ 7340' 0.0 CURRENT BACKGROUND/AVG 1.3 PENTANE (C-5) 0 @ 7340' 0 @ 7340' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY Tuffaceous siltstone, Tuffaceous claystone, Claystone DAILY ACTIVITY RIH w/ whipstock, Clean/Prep pits for OBM, Swap over to OBM, Mill window from 7279' to 7340', Preform FIT SUMMARY test to 12.68 ppg EMW, POOH. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2625 REPORT BY M. Skiles Hilcorp Alaska LLC MacArthur River DAILY WELLSITE REPORT TBU M-06RD CANR'G REPORT FOR E. Harness / H. Soule DATE Jun 06, 2017 DEPTH 7340' PRESENT OPERATION RIH TIME 23:48:11 YESTERDAY 7340' 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/6" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8 1/2" HDBS MMD75DC 12896068 7X12 7340' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 7340' TO TOOLS Rotary Steerable + MWD/RWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY POOH, L/D milling assembly, Test BOPS, P/U BHA, RIH CANRIG PERSONNEL ON BOARD 2 DAILY COST $2625 REPORT BY M. Skiles Hilcorp Alaska LLC McArthur River Unit DAILY WELLSITE REPORT TBU M-06RD i/w ©,�v■`fy'J�� w �I/ Y -. \IG REPORT FOR E. Harness / H. Soule DATE Jun 07, 2017 DEPTH 8230' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 7340' 24 HOUR FOOTAGE 890' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7722.42' 40.17° 15.20° 5171.83' 7813.13' 38.34° 9.69° 5242.09' SURVEYDATA 7901.85' 36.21° 7.09° 5312.69' 7999.01' 30.03° 5.08° 5394.02' 8095.5' 26.03° 4.33° 5479.18' BITINFORMATION INTERVAL CONDITION REASON NO, SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 81/2" HDBS MMD75DC 12896068 7X12 7340' 890' 9:32 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 1002.1 @ 8143 1.4 @ 7414 135.1 131.01 FT/HR SURFACETORQUE 21806 @ 7354 0 @ 8135 17017.4 18308.56 AMPS WEIGHT ON BIT 73 @ 8136 0 @ 8113 13.4 20.55 KLBS ROTARY RPM 157 @ 8124 0 @ 8135 129.9 142.23 RPM PUMP PRESSURE 2502 @ 7340 0 @ 7960 2146.3 2211.47 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL - FC SOL SO OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 7340' TO TOOLS Rotary Steerable +MWD/LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 250 @ 7549 3 @ 8093 39.7 TRIP GAS n/a CUTTING GAS 0 @ 8230 0 @ 8230 0.0 WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) 65423 @ 7433 374 @ 8094 10079.3 CONNECTION GAS HIGH – ETHANE (C-2) 33 @ 7903 8 @ 8173 0.4 AVG – PROPANE (C-3) 0 @ 8230 0 @ 8230 0.0 URRENT– CURRENT– BUTANE(C-4) 0 BUTANE(C4) @ 8230 0 @ 8230 0.0 CURRENT BACKGROUND/AVG 25u/15u PENTANE (C-5) 0 @ 8230 0 @ 8230 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY Sand 60%, Tuffaceous Siltstone 20%, Tuffaceous Sandstone 10%, Tuffaceous Claystone 10% DAILY ACTIVITY SUMMARY RIH to window, circulate & condition mud, drill ahead from 7340' to 8230'@ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4520 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Unit DAILY WELLSITE REPORT TBU M-06RD CMRIG REPORT FOR E. Harness / H. Soule DATE Jun 08, 2017 DEPTH 9940' PRESENT OPERATION Dulling Ahead TIME 23:59 YESTERDAY 8230' 24 HOUR FOOTAGE 1710' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9521.29' 12.69° 356.31' 6854.66' 9616.49' 12.22° 352.85° 6947.62' SURVEY DATA 9711.14' 12.75° 2.19° 7040.05' 9807.53' 14.74° 2.53" 7133.67' 9899.15' 15.42° 358.71° 7222.14' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 81/2" HDBS MMD75DC 12896068 7X12 7340' 2600' 21:54 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 614.5 @ 8803 0.5 @ 9681 170.9 73.60 FT/HR SURFACE TORQUE 25850 @ 9875 0 @ 9658 20845.0 21684.61 AMPS WEIGHT ON BIT 92 @ 9842 0 @ 8666 16.0 6.77 KLBS ROTARY RPM 159 @ 8282 0 @ 9842 147.1 147.45 RPM PUMP PRESSURE 2440 @ 9833 0 @ 9841 2243.8 2284.86 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL - FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 7340'TO TOOLS Rotary Steerable + MWD/LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 306 @ 9600 2 @ 9658 50.8 TRIP GAS — CUTTING GAS 0 @ 9940 0 @ 9940 0.0 WIPER GAS — CHROMATOGRAPHY(ppm) SURVEY — METHANE (C-1) 83126 @ 9602 445 @ 9010 13155.2 CONNECTION GAS HIGH — ETHANE (C-2) 276 @ 9860 6 @ 9787 17.4 AVG — PROPANE (C-3) 43 @ 9827 2 @ 9671 2.7 CURRENT— BUTANE (C-4) 0 @ 9940 0 @ 9940 0.0 CURRENT BACKGROUND/AVG 17u/12u PENTANE (C-5) 0 @ 9940 0 @ 9940 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY Sand 40%, Tuffaceous Siltstone 20%, Tuffaceous Claystone 20%, Tuffaceous Sandstone 10%, Conglomerate 10 DAILY ACTIVITY SUMMARY Drill ahead from 8230' to 9940'@ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4520 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Unit DAILY WELLSITE REPORT TBU M-06RD CAN■yf'�J�. \IG REPORT FOR E. Harness / H. Soule DATE Jun 09, 2017 DEPTH 11072' PRESENT OPERATION Pulling out of Hole TIME 23:59 YESTERDAY 9940' 24 HOUR FOOTAGE 1132' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10659.78' 9.05" 335.79° 7963.48' 10752.30' 5.87° 315.50° 8055.22' SURVEY DATA 10847.20' 6.25° 283.27° 8148.62' 10943.65' 8.24° 263.31° 8245.31' 11037.22' 8.56° 237.91° 8337.91' BIT INFORMATION INTERVAL CONDITION REASON NO, SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/BIC PULLED 1 81/2" HDBS MMD75DC 12896068 7X12 7340' 3793' 35:12 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 1674.1 @ 10973 1.0 @ 10496 124.7 35.52 FT/HR SURFACE TORQUE 28493 @ 11037 17891 @ 11064 22663.0 22450.30 AMPS WEIGHT ON BIT 33 @ 10885 2.0 @ 10838 16.9 19.24 KLBS ROTARY RPM 173 @ 11018 84 @ 10510 149.2 150.79 RPM PUMP PRESSURE 2576 @ 11031 1606 @ 10718 2334.9 2513.92 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL_ FCSOL SO OIL MBL pH Ca- CCI MWD SUMMARY INTERVAL 7279' TO 11072' TOOLS Rotary Steerable + MWD/LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 443 @ 10382 2 @ 10015 61.3 TRIP GAS -- CUTTING GAS 0 @ 11072 0 @ 11072 0.0 WIPER GAS -- CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) 120933 @ 10382 1380 @ 10017 15984.8 CONNECTION GAS HIGH -- ETHANE (C-2) 510 @ 11013 3 @ 10410 47.8 AVG -- PROPANE (C-3) 106 @ 10693 2 @ 10219 10.3 CURRENT 10u BUTANE (C-4) 5 @ 10171 3 @ 10152 0.1 CURRENT BACKGROUND/AVG 12u/10u PENTANE (C-5) 0 @ 11072 0 @ 11072 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY Tuffaceous Sandstone 50%, Tuffaceous Siltstone 30%, Sand 20% @ 11050' DAILY ACTIVITY SUMMARY Drilled ahead to 11072', Circ bottoms up, Prep for bit trip. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4520 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD /w CANRI Lrw� V REPORT FOR E. Harness / H. Soule DATE Jun 10, 2017 DEPTH 11072' PRESENT OPERATION Servicing BHA TIME 23:59 YESTERDAY 11072' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10659.78' 9.05° 335.79° 7963.48' 10752.30' 5.87° 315.50° 8055.22' SURVEY DATA 10847.20' 6.25° 283.27° 8149.62' 10943.65' 8.24° 263.31° 8245.31' 11037.22' 8.56° 237.91° 8337.91' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 81/2" HDBS MMD75DC 12896068 7X12 7279' 11072' 3793' 3512 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL - FC SOL SD OIL MBL pH Ca. CCI MWD SUMMARY INTERVAL 7279' TO 11072' TOOLS Rotary Steerable +LWD/MWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Pulled out of hole to surface, replacing bit R servicing BHA @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4520 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD ��'(G REPORT FOR E. Harness / H. Soule DATE Jun 11, 2017 DEPTH 11316' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 11072' 24 HOUR FOOTAGE 244' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10752.30' 5.87° 315.50° 8055.22' 10847.20' 6.25° 283.27° 8149.62' SURVEY DATA 10943.65' 8.24° 263.31° 8245.31' 11037.22' 8.56° 237.91° 8337.91' 11134.00' 12.46° 218.57° 8433.07' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 81/2" HDBS MMD75DC 12896069 7X12 11072' 244' 326 1 8 1/2" HDBS MMD75DC 12896068 7X12 7279' 11072' 3793' 35:12 1 -4 -BT -S -X -1 -NO -PR low ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 240.0 @ 11074 2.2 @ 11108 81.8 104.54 FT/HR SURFACE TORQUE 22795 @ 11267 0 @ 11264 18931.3 19146.41 AMPS WEIGHT ON BIT 65 @ 11170 2 @ 11075 18.2 11.47 KLBS ROTARY RPM 158 @ 11208 0 @ 11264 145.4 143.91 RPM PUMP PRESSURE 2875 @ 11122 -4 @ 11073 2775.9 2783.29 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL_ FCSOL SO OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 11072' TO TOOLS Rotary Stainable +LWD/MWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 160 @ 11309 12 @ 11266 44.4 TRIP GAS 601 u CUTTING GAS 0 @ 11316 0 @ 11316 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY - METHANE (C-1) 44008 @ 11309 1786 @ 11140 11442.7 CONNECTION GAS HIGH - ETHANE (C-2) 148 @ 11179 1 @ 11227 7.4 AVG - PROPANE (C-3) 25 @ 11116 3 @ 11108 4.2 CURRENT 49u BUTANE (C-4) 0 @ 11316 0 @ 11316 0.0 CURRENT BACKGROUND/AVG 3u/49u PENTANE (C-5) 0 @ 11316 0 @ 11316 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY Sand 40%, Tuffaceous Sandstone 20%, Tuffaceous Siltstone 20%, Coal 10%, Tuffaceous Claystone 10 DAILY ACTIVITY SUMMARY Ran in hole to bottom w/ new drillbit and serviced BHA, circulated, drilled ahead; drilling ahead at 11316'@ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4520 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD CANRIG REPORT FOR E. Harness / H. Soule DATE Jun 12, 2017 DEPTH 12310' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 11316' 24 HOUR FOOTAGE 994' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11799.05' 32.36 200.24 9043.02' 11892.09' 38.09 198.08 9119.00' SURVEY DATA 11986.67' 44.07 199.31 9190.26' 12081.44' 50.47 200.19 9254.53' 12175.61' 53.62 199.46 9312.45' BITMFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 81/2" HDBS MMD75DC 12896069 7X12 11072' 1238' 1829 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 382.7 @ 12025 1.3 @ 12260 88.7 26.19 FT/HR SURFACE TORQUE 26519 @ 11988 0 @ 12224 21480.4 22056.02 AMPS WEIGHT ON BIT 66 @ 12030 1 @ 11676 16.8 20.65 KLBS ROTARY RPM 181 @ 12306 0 @ 12224 140.6 176.01 RPM PUMP PRESSURE 2915 @ 12144 0 @ 12224 2757.9 2765.66 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 11072' TO TOOLS Rotary Steerable + LWD/MWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 510 @ 11338 11 @ 11750 43.4 TRIP GAS - CUTTING GAS 0 @ 12310 0 @ 12310 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE (C-1) 135377 @ 11339 1507 @ 11810 9708.7 CONNECTION GAS HIGH - ETHANE (C-2) 1510 @ 11914 7 @ 11357 339.3 AVG - PROPANE (C-3) 871 @ 11914 3 @ 11357 158.9 CURRENT 24 BUTANE (C-4) 349 @ 11982 3 @ 11393 76.4 CURRENT BACKGROUND/AVG 3u/24u PENTANE (CS) 104 @ 11997 1 @ 11957 24.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Hemlock PRESENT LITHOLOGY Sand 50%, Conglomerate 20%, Tuffaceous Sandstone 10%, Tuffaceous Siltstone 10%, Tuffaceous Claystone 10% DAILY ACTIVITY SUMMARY Drilled ahead from 11316'to 12310'@ reporttime. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4520 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT f TBU M-06RD Y _C�,`^Y' �/f RI V REPORT FOR E. Harness / H. Soule DATE Jun 13, 2017 DEPTH 12424' PRESENT OPERATION Replacing bit/Servicing BHA TIME 23:59 YESTERDAY 12310' 24 HOUR FOOTAGE 114' CASING INFORMATION 9 518" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11986.67' 44.07° 199.31° 9190.26' 12081.44' 50.47° 200.19° 9254.53' SURVEY DATA 12175.61' 53.62° 199.46° 9312.45' 12272.50' 56.51" 197.96° 9367.93' 12367.27' 57.54° 197.31° 9419.51' BITINFORMATION INTERVAL CONDITION REASON NO, SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8 1/2" HDBS MMD75DC 12896069 7X12 11072' 12424' 1352' 2241 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 105.7 @ 12323 1.4 @ 12356 39.5 22.06 FT/HR SURFACE TORQUE 24530 @ 12329 18234 @ 12424 22391.5 18234.63 AMPS WEIGHT ON BIT 24 @ 12420 3 @ 12324 20.7 23.66 KLBS ROTARY RPM 173 @ 12409 123 @ 12350 148.0 154.61 RPM PUMP PRESSURE 3096 @ 12396 2137 @ 12319 2934.6 3008.62 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL_ FC SOL SO OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 11072' TO 12424' TOOLS Rotary Steerable + LWD/MWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 45 @ 12398 9 @ 12375 21.9 TRIP GAS - CUTTING GAS 0 @ 12424 0 @ 12424 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE (C-1) 10096 @ 12398 1408 @ 12375 3760.5 CONNECTION GAS HIGH - ETHANE (C-2) 798 @ 12341 67 @ 12403 411.8 AVG- PROPANE (C-3) 188 @ 12384 33 @ 12403 108.7 CURRENT Ou BUTANE (C-4) 104 @ 12389 27 @ 12375 61.8 CURRENT BACKGROUND/AVG -10u PENTANE (C-5) 57 @ 12417 4 @ 12371- 30.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Hemlock PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drilled ahead from 12310'to 12424'. Pulled out of hole for new bit due to low ROP. At surface at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD ��IV REPORT FOR E. Harness / H. Soule DATE Jun 14, 2017 DEPTH 12658' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 12424' 24 HOUR FOOTAGE 234' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12175.61' 53.62° 199.46° 9312.45' 12272.50' 56.51° 197.96° 9367.93' SURVEY DATA 12367.27' 57.54° 197.31° 9419.51' 12462.23' 60.91° 199.57° 9468.09' 12552.72' 65.85° 197.48° 9508.63' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 81/2" HDBS MMD75DC 12920423 7X12 12424' 234' 4:12 2 81/2" HDBS MMD75DC 12896069 7X12 11072' 12424' 1352' 22:41 8-4-RO-C-X-I-Wr-PR Low ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 242.6 @ 12594 1.2 @ 12490 98.3 1.78 FT/HR SURFACETORQUE 28274 @ 12486 0 @ 12493 23579.0 21686.38 AMPS WEIGHT ON BIT 45 @ 12589 1 @ 12497 18.7 21.58 KLBS ROTARY RPM 169 @ 12425 0 @ 12493 98.0 107.61 RPM PUMP PRESSURE 3071 @ 12430 0 @ 12589 2938.5 2920.27 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL - FC SOL SO OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 12424' TO TOOLS Geo -Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 84 @ 12587 5 @ 12471 29.9 TRIP GAS 372u CUTTING GAS 0 @ 12658 0 @ 12658 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY - METHANE (C-1) 17836 @ 12587 475 @ 12470 5951.6 CONNECTION GAS HIGH - ETHANE (C-2) 863 @ 12587 9 @ 12443 298.4 AVG - PROPANE (C-3) 511 @ 12587 4 @ 12443 128.6 CURRENT 24u BUTANE (C-4) 226 @ 12588 2 @ 12494 52.5 CURRENT BACKGROUND/AVG 3u/24u PENTANE (C-5) 69 @ 12588 2 @ 12596 12.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Hemlock PRESENT LITHOLOGY Sand 70%, Tuffaceous Sandstone 10%, Tuffaceous Siltstone 10%, Tuffaceous Claystone 10 DAILY ACTIVITY Ran in hole to bottom, washing/reaming the last Few stands. Resumed drilling according to plan. Drilling ahead at 12658'@ report SUMMARY time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD ��I� REPORT FOR E. Harness / H. Soule DATE Jun 15, 2017 DEPTH 13037' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 12658' 24 HOUR FOOTAGE 379' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12552.72' 65.85° 197.48° 9508.63' 12649.66' 72.45° 193.41° 9543.12' SURVEY DATA 12744.77' 75.76° 192.88° 9569.17' 12839.74' 74.87° 191.59° 9594.84' 12932.66' 73.92° 192.33° 9619.84' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 81/2' HDBS MMD75DC 12920423 7X12 12424' 613' 1556 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 406.2 @ 12968 0.5 @ 12970 59.6 14.76 FT/HR SURFACE TORQUE 28639 @ 12860 0 @ 12874 23354.7 18121.98 AMPS WEIGHT ON BIT 131 @ 12968 5 @ 12877 20.0 23.36 KLBS ROTARY RPM 149 @ 12719 0 @ 12968 107.2 123.37 RPM PUMP PRESSURE 2989 @ 12952 0 @ 12876 2868.5 2905.08 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 12424' TO TOOLS Geo-Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 115 @ 12819 6 @ 12752 26.0 TRIP GAS - CUTTING GAS 0 @ 13037 0 @ 13037 0.0 WIPER GAS 82u CHROMATOGRAPHY (ppm) SURVEY- METHANE (C-1) 23278 @ 12820 651 @ 12752 4764.0 CONNECTION GAS HIGH - ETHANE (C-2) 1539 @ 12820 10 @ 12963 319.3 AVG - PROPANE (C-3) 972 @ 12820 8 @ 12969 144.1 CURRENT 10u BUTANE (C-4) 393 @ 12821 0 @ 12779 68.4 CURRENT BACKGROUND/AVG 3u/10u PENTANE (C5) 120 @ 12823 0 @ 12779 20.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Hemlock PRESENT LITHOLOGY Sand 60%, Tuffaceous Siltstone 20%, Tuffaceous Claystone 20% DAILY ACTIVITY Drilled ahead from 12658'to 12878'. Wiper trip to 11020'. Ran in hole back to bottom and resumed drilling. Drilling ahead at 13037' SUMMARY @report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD CANRIG REPORT FOR E. Harness / H. Soule DATE Jun 16, 2017 DEPTH 13272' PRESENT OPERATION Pulling out of hole TIME 23:59 YESTERDAY 13037' 24 HOUR FOOTAGE 235' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12839.74' 74.87 191.59 9594.84' 12832.66' 73.92 192.33 9619.84' SURVEY DATA 13029.17' 75.39 193.62 9645.38' 13123.84' 79.82 195.47 9665.70' 13218.65' 84.45 198.32 9678.67' BITINFORNIATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TIB/C PULLED 3 81/2" HDBS MMD75DC 12920423 7X12 12424' 13272' 848' 22:27 Low ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 132.0 @ 13164 0.7 @ 13197 61.1 1.47 FT/HR SURFACETORQUE 27366 @ 13165 18023 @ 13055 23473.4 18667.64 AMPS WEIGHT ON BIT 28 @ 13250 6 @ 13252 20.3 17.69 KLBS ROTARY RPM 141 @ 13226 96 @ 13198 118.5 116.65 RPM PUMPPRESSURE 2952 @ 13168 2418 @ 13171 2905.9 2934.25 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL_ FC SOL SO OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 12424' TO 13272' TOOLS Geo -Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 53 @ 13184 8 @ 13066 24.7 TRIP GAS - CUTTING GAS 0 @ 13272 0 @ 13272 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY - METHANE (C-1) 10303 @ 13184 1512 @ 13160 4494.5 CONNECTION GAS HIGH - ETHANE (C-2) 711 @ 13187 36 @ 13229 281.8 AVG - PROPANE (C-3) 349 @ 13184 21 @ 13229 121.9 CURRENTiu BUTANE (C-4) 147 @ 13186 17 @ 13133 57.6 CURRENT BACKGROUND/AVG 3u/1u PENTANE (CS) 60 @ 13184 1 @ 13142 21.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY DAILY ACTIVFFY Drilled ahead to 13272'. Low penetration rate. Circulated bottoms up then began pulling out of hole. Pulling out of hole at 5084' @ SUMMARY report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field TBU M-06RD DAILY WELLSITE REPORT ���� REPORT FOR E. Harness / H. Soule DATE Jun 17, 2017 DEPTH 13272' PRESENT OPERATION Testing BOP TIME 23:59 YESTERDAY 13272' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12839.74' 74.87° 191.59° 9594.84' 12932.66' 73.92° 192.33° 9619.84' SURVEY DATA 13029.17' 75.39° 193.62° 9645.38' 13123.84' 79.82° 195.47° 9665.70' 13218.65' 84.45° 198.32° 9678.67' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 81/2" HDBS MMD75DC 12920423 7X12 12424' 13272' 848' 2227 i -2 -CT -N -X -I -WT -PR Low ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACETORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMPPRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL - FC SOL SO OIL MBL pH Ca- CCI MWD SUMMARY INTERVAL 12424' TO 13272' TOOLS Geo -Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT Ou BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG Ou/Ou PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Pulled out of hole to surface, laid down BHA. Testing BOP @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD �'� REPORT FOR E. Harness / H. Soule DATE Jun 18, 2017 DEPTH 13272' PRESENT OPERATION Running in hole TIME 23:59 YESTERDAY 13272' 24 HOUR FOOTAGE 0' CASING INFORMATION 95/8"@7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO, SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 81/2" Varel V711PDGlHRU 4009435 4X12,4X11 13272' 0' 00:00 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 13272' TO TOOLS Geo-Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY- METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (G-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT Ou BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u10u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Completed BOP testing. Troubleshot new directional BHA and began run back in hole. Running in hole at 6560' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD CANRIG REPORT FOR E. Harness / H. Soule DATE Jun 19, 2017 DEPTH 13424' PRESENT OPERATION Wiper Trip TIME 23:59 YESTERDAY 13272' 24 HOUR FOOTAGE 152' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 13322.14' 83.39° 198.79° 9689.63' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 81/2" Varel V711PDG1 HRU 4009435 4X12,4X11 13272' 152' 0327 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 130.4 @ 13296 1.1 @ 13370 64.1 75.21 FT/HR SURFACE TORQUE 27262 @ 13405 17859 @ 13370 23252.3 19484.37 AMPS WEIGHT ON BIT 48 @ 13412 8 @ 13364 21.7 48.02 KLBS ROTARY RPM 173 @ 13301 69 @ 13350 121.5 123.64 RPM PUMP PRESSURE 3201 @ 13274 2451 @ 13321 3070.8 3042.97 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL - FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 13272' TO TOOLS Geo -Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 56 @ 13293 11 @ 13358 26.3 TRIP GAS 400u CUTTING GAS 0 @ 13424 0 @ 13424 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY - METHANE (C-1) 12000 @ 13294 1877 @ 13356 5260.4 CONNECTION GAS HIGH - ETHANE (C-2) 574 @ 13296 23 @ 13391 160.4 AVG - PROPANE (C-3) 257 @ 13295 16 @ 13358 84.4 CURRENT 3u BUTANE (C-4) 96 @ 13296 4 @ 13315 351 CURRENT BACKGROUND/AVG 3u/3u PENTANE (C-5) 33 @ 13296 5 @ 13283 8.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY DAILY ACTIVITY Ran back in hole to bottom with new bit & BHA. Resumed drilling from 13272' to 13424'. Began wiper trip to 11070' to rearrange position SUMMARY of torque reducers. Running back to bottom @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD CANR'G REPORT FOR E. Harness / H. Soule DATE Jun 20, 2017 DEPTH 13890' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 13424' 24 HOUR FOOTAGE 466' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13416.39' 82.92° 198.11° 9700.86' 13511.09' 83.67° 198.13° 9711.92' SURVEY DATA 13606.39' 83.10° 199.58° 9722.89' 13701.97' 84.92° 198.41° 9732.87' 13796.67' 65.08° 197.70° 9741.12' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 81/2" Varel V711 PDG1HRU 4009435 4X12,4X11 13272' 618' 11:54 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 233 @ 13632 1.2 @ 13628 98.6 44.50 FT/HR SURFACE TORQUE 29959 @ 13680 18112 @ 13704 25684.9 22020.04 AMPS WEIGHT ON BIT 48 @ 13424 2 @ 13648 16.9 33.54 KLBS ROTARY RPM 172 @ 13681 71 @ 13461 140.0 117.41 RPM PUMP PRESSURE 3318 @ 13861 2313 @ 13494 3020.5 3082.95 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL_ FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 13272' TO TOOLS Geo -Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 72 @ 13822 5 @ 13890 19.4 TRIP GAS - CUTTING GAS 0 @ 13890 0 @ 13890 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY - METHANE (C-1) 15862 @ 13622 358 @ 13889 3818.0 CONNECTION GAS HIGH - ETHANE (C-2) 727 @ 13822 16 @ 13451 142.8 AVG - PROPANE (C-3) 455 @ 13822 7 @ 13454 79.4 CURRENT 5u BUTANE (C-4) 222 @ 13822 0 @ 13548 36.3 CURRENT BACKGROUND/AVG 3u/5u PENTANE (C-5) 71 @ 13822 5 @ 13608 9.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY Sand 60%, Tuffaceous Siltstone 20%, Tuffaceous Claystone 20% DAILY ACTIVITY SUMMARY Ran in hole back to bottom. Drilled ahead from 13424'. Drilling ahead at 13890'@ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD (G CMRIG REPORT FOR E. Harness / H. Soule DATE Jun 21, 2017 DEPTH 13922' PRESENT OPERATION Replacing BHA TIME 23:59 YESTERDAY 13890' 24 HOUR FOOTAGE 32' CASING INFORMATION 9 5/e" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 81/2" Varel V711 PDGiHRU 4009435 4X12,4X11 13272' 13922' 650' 13:39 Low ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 208.1 @ 13901 0.2 @ 13893 55.3 14.16 FT/HR SURFACE TORQUE 23971 @ 13909 15429 @ 13922 22877.0 15429.61 AMPS WEIGHT ON BIT 65 @ 13922 8 @ 13917 33.4 65.96 KLBS ROTARY RPM 139 @ 13895 0 @ 13922 114.6 0.20 RPM PUMP PRESSURE 3108 @ 13892 2382 @ 13909 2610.0 2509.54 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL - FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 13272' TO 13922' TOOLS Geo -Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 8 @ 13899 4 @ 13922 7.1 TRIP GAS - CUTTING GAS 0 @ 13922 0 @ 13922 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY - METHANE (C-1) 709 @ 13900 206 @ 13922 493.3 CONNECTION GAS HIGH - ETHANE (C-2) 94 @ 13900 16 @ 13922 49.1 AVG - PROPANE (C-3) 44 @ 13900 8 @ 13922 23.6 CURRENT Ou BUTANE (C-4) 34 @ 13904 4 @ 13911 17.5 CURRENT BACKGROUND/AVG 3u/Ou PENTANE (C-5) 19 @ 13904 11 @ 13905 1.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY DAILY ACTIVITY Drilled Ahead to 13922'. Low ROP and sticking on bottom. Broke free and pulled out of hole to surface. At surface replacing BHA @ SUMMARY report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD ��' (G REPORT FOR E. Harness / H. Soule DATE Jun 21, 2017 DEPTH 13922' PRESENT OPERATION Replacing BHA TIME 23:59 YESTERDAY 13890' 24 HOUR FOOTAGE 32' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 13796.67' 85.08° 197.70° 9741.12' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 81/2" Varel V711 PDG1 HRU 4009435 4X12, 4X11 13272' 13922' 650' 13:39 Low ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 208.1 @ 13901 0.2 @ 13893 55.3 14.16 FT/HR SURFACETORQUE 23971 @ 13909 15429 @ 13922 22877.0 15429.61 AMPS WEIGHT ON BIT 65 @ 13922 8 @ 13917 33.4 65.96 KLBS ROTARY RPM 139 @ 13895 0 @ 13922 114.6 0.20 RPM PUMP PRESSURE 3108 @ 13892 2382 @ 13909 2610.0 2509.54 PSI DRILLING MUD REPORT DEPTH 13890 MW 9.05 VIS 70 PV 27 YP 19 FL 3.6 Gels 12/25/27 CL- - FC 0/3 SOL 9.0 SD 0.01 OIL 81.5/18.5 MBL - pH - Ca+ 13.06 CCI MWD SUMMARY INTERVAL 13272' TO 13922' TOOLS Geo-Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 8 @ 13899 4 @ 13922 7.1 TRIP GAS - CUTTING GAS 0 @ 13922 0 @ 13922 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE (C-1) 709 @ 13900 206 @ 13922 493.3 CONNECTION GAS HIGH - ETHANE (C-2) 94 @ 13900 16 @ 13922 49.1 AVG - PROPANE (C-3) 44 @ 13900 8 @ 13922 23.6 CURRENT Ou BUTANE (C-4) 34 @ 13904 4 @ 13911 17.5 CURRENT BACKGROUND/AVG 3u/Ou PENTANE (C-5) 19 @ 13904 11 @ 13905 1.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY Sand 60%, Tuffaceous Sandstone 10%, Conglomerate Sand 10%, Tuffaceous Siltstone 10%, Carbonaceous Shale 10% @ 13,920' DAILY ACTIVITY Drilled Ahead to 13922'. Low ROP and sticking on bottom. Broke free and pulled out of hole to surface. At surface replacing BHA @ SUMMARY report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD CMRIG REPORT FOR S. Hauck IA. Lundale DATE Jun 22, 2017 DEPTH 13922' PRESENT OPERATION Running In Hole TIME 23:59 YESTERDAY 13922' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13416.39' 82.92° 198.11° 9700.86' 13511.09' 83.67° 198.13° 9711.92' SURVEY DATA 13606.39' 83.10° 199.58° 9722.89' 13701.97' 84.92° 198.41° 9732.87' 13796.67' 85.08° 197.70° 9741.12' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 81/2" HDBS MM75D 12670051 5X14 13922' 0' 00:00 4 81/2" Varel V711PDGlHRU 4009435 012,011 13272' 13922' 650' 1339 4 -2 -BT -C -X -1 -CT -PR Low ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION N/A @ N/A N/A @ N/A N/A - FT/HR SURFACETORQUE N/A @ N/A N/A @ N/A N/A - AMPS WEIGHT ON BIT N/A @ N/A N/A @ N/A N/A - KLBS ROTARY RPM N/A @ N/A N/A @ N/A N/A - RPM PUMP PRESSURE N/A @ N/A N/A @ N/A N/A - PSI DRILLING MUD REPORT DEPTH 13922' MW 9.05 VIS 90 PV 26 YP 14 FL 2.8 Gels 11/26/30 CL- - FC 0/3 SOL 9.7 SO 0 OIL 83.6/16.4 MBL - pH - Ca+ 14.03 CCI MWD SUMMARY INTERVAL 13922' TO TOOLS SperryDrill Motor w/ 1.22° bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS N/A @ N/A N/A @ N/A N/A TRIP GAS 94u CUTTING GAS N/A @ N/A N/A @ N/A N/A WIPER GAS 132u CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) N/A @ N/A N/A @ N/A N/A CONNECTION GAS HIGH - ETHANE (C-2) N/A @ N/A N/A @ N/A N/A AVG - PROPANE (C-3) N/A @ N/A N/A @ N/A N/A CURRENT 8u BUTANE (C-4) N/A @ N/A N/A @ N/A N/A CURRENT BACKGROUND/AVG 3u/8u PENTANE (C-5) N/A @ N/A N/A @ N/A N/A HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2 PRESENT LITHOLOGY Sand 60%, Tuffaceous Sandstone 10%, Conglomerate Sand 10%, Tuffaceous Siltstone 10%, Carbonaceous Shale 10% @ 13920' DAILY ACTIVITY Replaced bit & BHA, changing from rotary steerable to mutlmotor with 1.22° bend. Ran back in hole. Worked tight spot @ 13500 - SUMMARY 13600. RIH at 13709' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD ////////r►►►► /\/I�� �R' V REPORT FOR S. Hauck / A. Lundale DATE Jun 23, 2017 DEPTH 15003' PRESENT OPERATION Dulling Ahead TIME 23:59 YESTERDAY 13922' 24 HOUR FOOTAGE 1081' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 14581.70' 85.56° 196.56° 9809.28' 14676.75' 85.31° 195.87° 9816.85' SURVEY DATA 14771.50' 85.01° 195.68° 9824.84' 14867.10' 84.45° 194.62° 9833.62' 14964.56' 83.51° 194.61° 9843.84' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 81/2" HDBS MM75D 12670051 5X14 13922' 1081' 0918 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 210.1 @ 14760 2.5 @ 14295 133.6 147.60 FT/HR SURFACE TORQUE 24204 @ 14992 0 @ 14908 14339.0 23507.34 AMPS WEIGHT ON BIT 100 @ 14908 0 @ 13931 10.8 15.41 KLBS ROTARY RPM 106 @ 14388 0 @ 13922 97.9 96.87 RPM PUMP PRESSURE 3651 @ 13984 21 @ 14908 3364.2 3570.33 PSI DRILLING MUD REPORT DEPTH 13922' MW 9.05 VIS 90 PV 31 YP 16 FL 2.8 Gels 15/29/34 CL- - FC 0/3 SOL 10.2 SD 0 OIL 84.1/15.9 MBL - pH - Ca+ 15.97 CCI MWD SUMMARY INTERVAL 13922' TO TOOLS SperryDrill Motor w/ 1.22° bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 61 @ 14130 4 @ 13922 27.5 TRIP GAS - CUTTING GAS 0 @ 15003 0 @ 15003 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY- METHANE (C-1) 13570 @ 14131 206 @ 13922 5538.6 CONNECTION GAS HIGH - ETHANE (C-2) 936 @ 14988 16 @ 13922 307.0 AVG - PROPANE (C-3) 390 @ 14508 8 @ 13922 140.3 CURRENT 8u BUTANE (C-4) 188 @ 14508 4 @ 14034 70.0 CURRENT BACKGROUND/AVG 3U/28u PENTANE (CS) 67 @ 14509 2 @ 14061 26.7 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2/3 PRESENT LITHOLOGY Sand 40%, Tuffaceous Sandstone 30%, Conglomerate 10%, Tuffaceous Siltstone 10%, Tuffaceous Claystone 10% DAILY ACTIVITY Completed RIH to 13922' and resumed drilling @ 01:40. Drilled ahead from 13922'to 15003'. Pulled out of hole 10 stands for shortwiper SUMMARY tdp then ran in hole back to 15003'. Resuming drilling ahead right @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD /w ��y�'_�Jr. \'G REPORT FOR S. Hauck / A. Lundale DATE Jun 24, 2017 DEPTH 15472' PRESENT OPERATION Pulling Out Of Hole TIME 23:59 YESTERDAY 15003' 24 HOUR FOOTAGE 469' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15153.04' 82.45° 194.95° 9867.35' 15245.60' 81.96° 194.89° 9879.91' SURVEY DATA 15341.19' 81.77° 194.85° 9893.43' 15435.57' 82.28° 194.45° 9906.53' 15472.00' prof. 82.28° 194.45° 9911.42' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 81/2" HDBS MM75D 12670051 5X14 13922' 15472' 1550' 13:24 TO DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 600.7 @ 15381 2.1 @ 15067 157.3 124.09 FT/HR SURFACE TORQUE 27291 @ 15450 21461 @ 15074 24078.9 23788.83 AMPS WEIGHT ON BIT 17 @ 15085 1 @ 15009 12.9 13.81 KLBS ROTARY RPM 113 @ 15288 84 @ 15012 104.3 100.99 RPM PUMP PRESSURE 3631 @ 15434 2584 @ 15202 3423.8 3513.18 PSI DRILLING MUD REPORT DEPTH 15003' MW 9.05 VIS 76 PV 29 YP 16 FL 3.8 Gels 14/26/28 CL- - FC 0/3 SOL 9.7 SO 0 OIL 83.6/16.4 MBL - pH - Ca+ 15.00 CCI - MWD SUMMARY INTERVAL 13922' TO 15472' TOOLS SperryDrill Motor w/ 1.22° bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 48 @ 15381 7 @ 15115 26.9 TRIP GAS - CUTTING GAS 0 @ 15472 0 @ 15472 0.0 WIPER GAS 42u CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) 9809 @ 15381 1291 @ 15008 4968.1 CONNECTION GAS HIGH - ETHANE (C-2) 1050 @ 15048 111 @ 15006 560.3 AVG - PROPANE (C-3) 388 @ 15381 22 @ 15007 151.2 CURRENT Ou BUTANE (C-4) 164 @ 15439 14 @ 15286 63.4 CURRENT BACKGROUND/AVG 3u/27u PENTANE (C-5) 67 @ 15439 2 @ 15115 22.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2/3 PRESENT LITHOLOGY Sand 30%, Tuffaceous Sandstone 30%, Tuffaceous Siltstone 20%, Conglomerate 10%, Tuffaceous Claystone 10 DAILY ACTIVITY Resumed drilling at 15003' after wiper trip. Dnlled to TO @ 15472'. Circulated bottoms up then began pulling out of hole. Pulling out SUMMARY at 3120'@ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TSU M-06RD //ww ■�y'�� ,/w� �� I V REPORT FOR S. Hauck /A. Lundale DATE Jun 25, 2017 DEPTH 15472' PRESENT OPERATION Cleanout Run TIME 23:59 YESTERDAY 15472' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15153.04' 82.45° 194.95° 9867.35' 15245.60' 81.96° 194.89° 9879.91' SURVEY DATA 15341.19' 81.77° 194.85° 9893.43' 15435.57' 82.28° 194.45° 9906.53' 15472.00' prof. 82.28° 194.45° 9911.42' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5m 8 1/2" HDBS MM75D 12670051 5X14 15472' 15472' 0' 00:02 5 8 1/2" HDBS MM75D 12670051 5X14 13922' 15472' 1550' 13:24 2 -1 -CT -C -X -I -SD -TD TO DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION N/A @ N/A N/A @ N/A N/A N/A FT/HR SURFACE TORQUE N/A @ N/A N/A @ N/A N/A N/A AMPS WEIGHT ON BIT N/A @ N/A N/A @ N/A N/A N/A KLBS ROTARY RPM N/A @ N/A N/A @ N/A N/A N/A RPM PUMP PRESSURE N/A @ N/A N/A @ N/A N/A N/A PSI DRILLING MUD REPORT DEPTH 15472' MW 9.10 VIS 68 PV 28 YP 12 FL 3.8 Gels 9/20/22 CL - FC 0/3 SOL 10.2 SO 0.10 OIL 83.0/17.0 MBL - pH - Ca+ 14.03 CCI - MWD SUMMARY INTERVAL 13922' TO 15472' TOOLS SperryDrill Motorw/1.22°bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS N/A @ N/A N/A @ N/A N/A TRIP GAS 118u CUTTING GAS N/A @ N/A N/A @ N/A N/A WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY - METHANE (C-1) N/A @ N/A N/A @ N/A N/A CONNECTION GAS HIGH - ETHANE (C-2) N/A @ N/A N/A @ N/A N/A AVG - PROPANE (C-3) N/A @ N/A N/A @ N/A N/A CURRENT 7u BUTANE (C4) N/A @ N/A N/A @ N/A N/A CURRENT BACKGROUND/AVG 3u/t0u PENTANE (C-5) N/A @ N/A N/A @ N/A N/A HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2/3 PRESENT LITHOLOGY Sand 30%, Tuffaceous Sandstone 30%, Tuffaceous Siltstone 20%, Conglomerate 10%, Tuffaceous Claystone 10% DAILY ACTIVITY Pulled out of hole, laid down BHA, Ran back in hole w/ cleanout assembly. Slip & cut drill line at the window. Continue RIH to TD. SUMMARY Circulating at TO @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3675 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD � Y�I� REPORT FOR S. Hauck /A. Lundale DATE Jun 26, 2017 DEPTH 15472' PRESENT OPERATION Cleanout Run TIME 23:59 YESTERDAY 15472' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15153.04' 82.45° 194.95° 9867.35' 15245.60' 81.96° 194.89° 9879.91' SURVEY DATA 15341.19' 81.77° 194.85° 9893.43' 15435.57' 82.28° 194.45° 9906.53' 15472.00' prof. 82.28° 194.45` 9911.42' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5rr 81/2" HDBS MM75D 12670051 5X14 15472' 15472' 0' 00:02 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION N/A @ N/A N/A @ N/A N/A N/A FT/HR SURFACETORQUE N/A @ N/A N/A @ N/A N/A N/A AMPS WEIGHT ON BIT N/A @ N/A N/A @ N/A N/A N/A KLBS ROTARY RPM N/A @ N/A N/A @ N/A N/A N/A RPM PUMP PRESSURE N/A @ N/A N/A @ N/A N/A N/A PSI DRILLING MUD REPORT DEPTH 15472' MW 9.25 VIS 68 PV 25 YP 12 FL 3.8 Gels 11/22/24 CL- - FC 0/3 SOL 10.7 SD 0.10 OIL 83.4/16.6 MBL - pH - Ca+ 15.97 CCI - MWD SUMMARY INTERVAL 13922' TO 15472' TOOLS SperryDrill Motor w/ 1.22" bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS N/A @ N/A N/A @ N/A N/A TRIP GAS - CUTTING GAS N/A @ N/A N/A @ N/A N/A WIPER GAS 74u CHROMATOGRAPHY (ppm) SURVEY- METHANE (C-1) N/A @ N/A N/A @ N/A N/A CONNECTION GAS HIGH - ETHANE (C-2) N/A @ N/A N/A @ N/A N/A AVG - PROPANE (C-3) N/A @ N/A N/A @ N/A N/A CURRENT 9u BUTANE (C-4) N/A @ N/A N/A @ N/A N/A CURRENT BACKGROUND/AVG 3u/8u PENTANE (CS) N/A @ N/A N/A @ N/A N/A HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2/3 PRESENT LITHOLOGY Sand 30%, Tuffaceous Sandstone 30%, Tuffaceous Siltstone 20%, Conglomerate 10%, Tuffaceous Claystone 10% DAILY ACTIVITY Circulated bottoms up at TO then pulled out of hole to window, working tight spot @ 12,700'. Ran back in hole to TD. Circulating at SUMMARY TO @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3675 REPORT BY Garnet Knopp Hilcorp Alaska LLC INCLINATION 15153.04' McArthur River Field TBU M-06RD DAILY WELLSITE REPORT C©VwV REPORT FOR S. Hauck / A. Lundale 81.77° 15435.57' DATE Jun 27, 2017 DEPTH 15472' PRESENT OPERATION Running Liner TIME 23:59 YESTERDAY 15472' 194.45° 24 HOUR FOOTAGE 0' LOW CASING INFORMATION 9 5/8" @ 7279' N/A SURVEY DATA BIT INFORMATION NO. SIZE TYPE 5rr 81/2" HDBS MM75D DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.30 VIS 85 FC 0/3 SOL 10.2 GAS SUMMARY (units) DITCH GAS CUTTING GAS METHANE (C-1) ETHANE (C-2) PROPANE (C-3) BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS INTERVAL DEPTH INCLINATION 15153.04' 82.45° 15245.60' 81.96° 15341.19' 81.77° 15435.57' 82.28° 15472.00' proj. 82.28° LITHOLOGY/REMARKS AZIMUTH VERTICAL DEPTH INTERVAL 9867.35' S/N JETS IN OUT FOOTAGE 12670051 5X14 15472' 15472' 0' 194.45° HIGH LOW REASON N/A @ N/A N/A (9? N/A C/O Run complete N/A @ N/A N/A @ N/A FT/HR N/A @ N/A N/A @ N/A N/A N/A @ N/A N/A @ N/A N/A N/A @ N/A N/A @ N/A DEPTH 15472' PV 27 YP 12 FL SO 0.10 OIL 83.0/17.0 MBL MWD SUMMARY INTERVAL 13922' TO 15472' TOOLS SperryDrill Motor w/ 1.22° bend HIGH LOW AVERAGE N/A @ N/A N/A @ N/A N/A N/A @ N/A N/A @ N/A N/A CHROMATOGRAPHY Ppm) N/A @ N/A N/A @ N/A N/A N/A @ N/A N/A @ N/A N/A N/A @ N/A N/A @ WA N/A N/A @ N/A N/A @ N/A N/A N/A @ N/A N/A @ N/A N/A LITHOLOGY/REMARKS AZIMUTH VERTICAL DEPTH 194.95" 9867.35' 194.89° 9879.91' 194.85° 9893.43' 194.45° 9906.53' 194.45° 9911.42' CONDITION REASON HOURS T/B/C PULLED 00:02 2 -1 -CT -C -X -1 -SD -TD C/O Run complete AVERAGE CURRENTAVG N/A N/A FT/HR N/A N/A AMPS N/A N/A KLBS N/A N/A RPM N/A N/A PSI 3.8 Gels 9/20/22 CL- - - pH - Ca+ 13.06 CCI TRIP GAS - WIPER GAS - SURVEY - CONNECTION GAS HIGH - AVG - CURRENT 2u CURRENT BACKGROUND/AVG 2u/6u GAS DESCRIPTION LITHOLOGY West Foreland 2/3 PRESENT LITHOLOGY Sand 30%, Tuffaceous Sandstone 30%, Tuffaceous Siltstone 20%, Conglomerate 10%, Tuffaceous Claystone 10% DAILY ACTIVITY Pulled out of hole to window, pumped dry job, completed pulling out of hole and laid down BHA/Cleanout assembly. Rig up and run 7" SUMMARY liner. Running 7" liner near 600' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3675 REPORT BY Garnet Knopp Hilcorp Alaska LLC INCLINATION 15153.04' McArthur River Field TBU M-06RD DAILY WELLSITE REPORT ��,wVly'n� r,/�� VIS -, I �YrI REPORT FOR S. Hauck / H. Soule 81.77° 15435.57' DATE Jun 28, 2017 DEPTH 15472' PRESENT OPERATION Running Liner TIME 23:59 YESTERDAY 15472' 15472' 15472' 24 HOUR FOOTAGE 0' CONDITION CASING INFORMATION 9 5/8" @ 7279' HIGH SURVEY DATA BIT INFORMATION NO. SIZE TYPE 5rr 81/2" HDBS MM75D DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.35 VIS 103 FC 0/3 SOL 10.9 GAS SUMMARY (units) DITCH GAS CUTTING GAS METHANE (C-1) ETHANE (C-2) PROPANE (C-3) BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS INTERVAL DEPTH INCLINATION 15153.04' 82.45" 15245.60' 81.96° 15341.19' 81.77° 15435.57' 82.28° 15472.00' prof. 82.28° LITHOLOGY/REMARKS AZIMUTH VERTICAL DEPTH 194.95° INTERVAL 9867.35' 194.89° SIN 9879.91' JETS IN OUT FOOTAGE 12670051 5X14 15472' 15472' 0' CONDITION REASON HIGH T/B/C LOW 00:02 2 -1 -CT -C -X -I -SD -TD C/O Run complete N/A @ N/A N/A @ N/A FT/HR N/A NIA @ NIA N/A @ WA KLBS N/A N/A @ N/A NIA @ N/A PSI N/A @ N/A N/A @ N/A N/A @ N/A N/A @ N/A DEPTH 15472' PV 28 YP 12 FL SO 0.10 OIL 82.9/17.1 MBL MWD SUMMARY INTERVAL 13922' TO 15472' TOOLS Spe"Drill Motor w/ 1.22° bend HIGH LOW AVERAGE N/A @ N/A N/A @ N/A NIA N/A @ N/A N/A @ N/A N/A CHROMATOGRAPHY (ppm) N/A @ N/A N/A @ N/A N/A N/A @ N/A N/A @ N/A N/A N/A @ N/A N/A @ N/A N/A N/A @ NIA N/A @ N/A N/A N/A @ N/A N/A @ NIA N/A LITHOLOGY/REMARKS AZIMUTH VERTICAL DEPTH 194.95° 9867.35' 194.89° 9879.91' 194.85° 9893.43' 194.45° 9906.53' 194.45° 9911.42' CONDITION REASON HOURS T/B/C PULLED 00:02 2 -1 -CT -C -X -I -SD -TD C/O Run complete AVERAGE CURRENTAVG N/A N/A FT/HR N/A N/A AMPS N/A N/A KLBS N/A N/A RPM N/A N/A PSI 4.2 Gels 9/20/23 CL- - - pH - Ca+ 12.09 CCI TRIP GAS 123u WIPER GAS - SURVEY - CONNECTION GAS HIGH - AVG - CURRENT Ou CURRENT BACKGROUND/AVG 2u/2u GAS DESCRIPTION LITHOLOGY West Foreland 2/3 PRESENT LITHOLOGY Sand 30%, Tuffaceous Sandstone 30%, Tuffaceous Siltstone 20%, Conglomerate 10%, Tuffaceous Claystone 10% DAILY ACTIVITY Continued running liner to window. Circulated & conditioned mud, got parameters with drive sub. Continued running liner into open hole to SUMMARY hanger & packer assembly. Makeup hanger & packer assembly as per Baker rep. Continued running liner into open hole on drill pipe from derrick. Currently running in at 9400' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3675 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD CANRIG REPORT FOR S. Hauck / H. Soule DATE Jun 29, 2017 DEPTH 15472' PRESENT OPERATION Pulling Out Of Hole TIME 23:59 YESTERDAY 15472' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15153.04' 82.45° 194.95° 9867.35' 15245.60' 81.96° 194.89° 9879.91' SURVEY DATA 15341.19' 81.77° 194.85° 9893.43' 15435.57' 82.28° 194.45° 9906.53' 15472.00'proj. 82.28° 194.45° 9911.42' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5rr 81/2" HDBSMM75D 12670051 5X14 15472' 15472' 0' 0002 2-1-CT-C-X-I-SD-TD C/O Run complete DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION N/A @ N/A N/A @ N/A N/A N/A FT/HR SURFACE TORQUE N/A @ N/A N/A @ N/A N/A N/A AMPS WEIGHT ON BIT N/A @ N/A N/A @ N/A N/A N/A KLBS ROTARY RPM N/A @ N/A N/A @ N/A N/A N/A RPM PUMP PRESSURE N/A @ N/A N/A @ N/A N/A N/A PSI DRILLING MUD REPORT DEPTH 15472' MW 9.40 VIS 128 PV 28 YP 13 FL 4.2 Gels 10/22/26 CL- - FC 0/3 SOL 10.7 SO 0.10 OIL 82.9/17.1 MBL - pH - Cat 14.51 CCI MWD SUMMARY INTERVAL 13922' TO 15472' TOOLS SperryDrill Motor w/ 1.22" bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS N/A @ N/A N/A @ N/A N/A TRIP GAS 134u CUTTING GAS N/A @ N/A N/A @ N/A N/A WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE (C-1) N/A @ N/A N/A @ N/A N/A CONNECTION GAS HIGH - ETHANE (C-2) N/A @ N/A N/A @ N/A N/A AVG- PROPANE (C-3) N/A @ N/A N/A @ N/A N/A CURRENT Ou BUTANE (C-4) N/A @ N/A N/A @ N/A N/A CURRENT BACKGROUND/AVG 2u/2u PENTANE (C-5) N/A @ N/A N/A @ N/A N/A HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2/3 PRESENT LITHOLOGY Sand 30%, Tuffaceous Sandstone 30%, Tuffaceous Siltstone 20%, Conglomerate 10%, Tuffaceous Claystone 10% DAILY ACTIVITY Continued running liner in open hole to TD, final value TBD. Circulated & conditioned mud for cement job. Rigged up cementers. Pumped SUMMARY cement job. Had trouble setting packer. Circulated 2x bottoms up, washed up coal cuttings. Rig down cementers. Pumped dry job, detached drill pipe from liner top and pulled drill pipe out of hole. Laying down Baker running tool @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3675 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT ��^V CANREPORT TBU M-06RD FOR S. Hauck / H. Soule DATE Jun 30, 2017 DEPTH 15472' PRESENT OPERATION Running In Hole TIME 23:59 YESTERDAY 15472' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @7279' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15153.04' 82.45° 194.95° 9867.35' 15245.60' 81.96° 194.89° 9879.91' SURVEY DATA 15341.19' 81.77° 194.85° 9893.43' 15435.57' 82.28° 194.45° 9906.53' 15472.00' pr0j. 82.28° 194.45° 9911.42' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 6 6" Roller cone (cement cleanout) N/A N/A N/A N/A N/A N/A DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION N/A @ N/A N/A @ N/A N/A N/A FT/HR SURFACETORQUE N/A @ N/A N/A @ N/A N/A N/A AMPS WEIGHT ON BIT N/A @ N/A N/A @ N/A N/A N/A KLBS ROTARY RPM N/A @ N/A N/A @ N/A N/A N/A RPM PUMP PRESSURE N/A @ N/A N/A @ N/A N/A N/A PSI DRILLING MUD REPORT DEPTH 15472' MW 9.45 VIS 151 PV 30 YP 14 FL 4.0 Gels 10/21/23 CL- - FC 0/3 SOL 10.4 SO 0.10 OIL 82.9/17.1 MBL - pH - Ca+ 14.03 CCI - MWD SUMMARY INTERVAL 13922' TO 15472' TOOLS SperryDrill Motor w/ 1.22° bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS N/A @ N/A N/A @ N/A N/A TRIP GAS - CUTTING GAS N/A @ N/A N/A @ N/A N/A WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY - METHANE (C-1) N/A @ N/A N/A @ N/A N/A CONNECTION GAS HIGH - ETHANE (C-2) N/A @ N/A N/A @ N/A N/A AVG - PROPANE (C-3) N/A @ N/A N/A @ N/A N/A CURRENT Ou BUTANE (C-4) N/A @ N/A N/A @ N/A N/A CURRENT BACKGROUND/AVG Ou/Ou PENTANE (CS) N/A @ N/A N/A @ N/A N/A HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2J3 PRESENT LITHOLOGY Sand 30%, Tuffaceous Sandstone 30%, Tuffaceous Siltstone 20%, Conglomerate 10%, Tuffaceous Claystone 10 DAILY ACTIVITY Checked running tool; good. Changed out lower rams to VBR and tested. Picked up casing scraper BHA and singled in on 4" DP to SUMMARY 4172'. P/U second 7" scraper. Running in hole at 4172' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3675 REPORT BY Garnet Knopp
