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Home My WebLink About218-105DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2161050 Well Name/No. TRADING BAY UNIT M-35LI MD 16490 TVD 9844 Completion Date REQUIRED INFORMATION Mud Log 140'.".0�� Operator HILCORP ALASKA LLC Completion Status P&A Samples DATA INFORMATION List of Logs Obtained: GR/MR/NEU/POR/DEN, Mudlogs MD & TVD Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No ED C 30232 Digital Data ED C 30232 Digital Data ED C 30232 Digital Data ED C 30232 Digital Data ED C 30232 Digital Data ED C 30232 Digital Data ED C 30232 Digital Data ED C 30232 Digital Data ED C 30232 Digital Data ED C 30232 Digital Data ED C 30232 Digital Data ED C 30232 Digital Data Current Status P&A API No. 50-733-20680-60-00 UIC No Directional Survey Yes ✓ (from Master Well Data/Logs) Interval OH Start Stop CH Received_ Comments 430 16490 1/11/2019 Electronic Data Set, Filename: Hilcorp_Alaska_Steelhead_M- 35L1_LAS_FE_MEM.las 430 16490 1/11/2019 Electronic Data Set, Filename: Hilcorp_Alaska_Steelhead_M- 35L1_LAS_FE_RLT.las 435 16495 1/11/2019 Electronic Data Set, Filename: Hilcorp_Steelhead_M-351-1 _VSS-DEPTH_Mem- RLT.Ias 1/11/2019 Electronic File: Hilcorp_Alaska_Steelhead_M- 35L1_2MD_FE_MEM.ogm 1/11/2019 Electronic File: Hilcorp_Alaska_Steelhead_M- 351-1_2TVD_FE_MEM.cgm 1/11/2019 Electronic File: Hilcorp_Alaska_Steelhead_M- 35L1_5MD_FE_ME M.cgm 1/11/2019 Electronic File: Hiloorp_Alaska_Steelhead_M- 35L1_5TVD_FE_MEM.cgm 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead_M- 35L1_2MD_FE_RLT.cgm 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead_M- 35L1_2TVD_FE_RLT.cgm 1/11/2019 Electronic File: Hilcorp Alaska_ Steelhead_M- 35L1_5MD_FE_RLT.cgm 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead_M- 35L1_5TVD_FE_RLT.cgm 1/11/2019 Electronic File: Hilcorp Alaska_ Steelhead_M- 35L1 _VSS_DE PTH_MEM.cgm AOGCC Page 1 of 18 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/2512019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M -35L1 Operator HILCORP ALASKA LLC API No. 50-733-20680-60-00 MD 16490 TVD 9844 Completion Date Completion Status P&A Current Status P&A UIC No ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN10.cgm ED C 30232 Digital Data 1/11/2019 Electronic File: Hiloorp Alaska_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN11.cgm ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN12.cgm ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN13.cgm ED C 30232 Digital Data 1/11/2019 Electronic File: Hiloorp Alaska_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN14.cgm ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN15.cgm ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead M- 35L1_VSS_TIME_RLT-MEM_RUN16.cgm ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead M- 35L1_VSS_TIME_RLT-MEM_RUN17.cgm ED C 30232 Digital Data 1/11/2019 Electronic File: 9231090—BHI—Mud Resistivity Report.xls ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Alaska_Steelhead_M- 351-1_2MD_FE_MEM.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Alaska_Steelhead_M- 351-1 _2TVD_FE_MEM.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Alaska_Steelhead_M- 35L1_5MD_FE_MEM.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Alaska_Steelhead_M- 35L1_5TVD_FE_MEM.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 35L1_2MD_FE_RLT.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 351-1_2TVD_FE_RLT.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 351-1_51VID_FE_RLT.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 35L1_5TVD_FE_RLT.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead_M- 35L1_VSS_DEPTH _MEM.pdf AOGCC Page 2 of 18 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M-3511 Operator HILCORP ALASKA LLC API No. 50-733-20680-60-00 MD 16490 TVD 9844 Completion Date Completion Status P&A Current Status P&A UIC No ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN10.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN11.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN 12.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN 13.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN 14.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN15.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN16.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN17.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: M-351-1_Final Survey.csv ED C 30232 Digital Data 1/11/2019 Electronic File: M-351-1_Final Survey.pdf ED C 30232 Digital Data 1/11/2019 Electronic File: M-351-1_Final Survey.bct ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Maska_Steelhead_M- 351-1_21vID_FE_MEM.1if ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Alaska_Steelhead_M- 35L1_2TVD_FE_MEM.Of ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Alaska_Sleelhead_M- 351-1_5M0_FE_MEM.tif ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Alaska_Steelhead_M- 35L 1_5TVD_FE_ME M.tif ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 351-1_21VID_FE_RL7.1if ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 35L1_2TVD_FE_RLT.tif ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 351-1_51VID FE RLT.tif ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp_Steelhead_M- 35L1 5TVD FE RLT.tif AOGCC Page 3 of 18 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M-351-1 Operator HILCORP ALASKA LLC API No. 50-733-20680-60-00 MD 16490 TVD 9844 Completion Date Completion Status P&A Current Status P&A UIC No ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead_M- 35L1_VSS_DEPTH_MEM.tif ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp Alaska _Steelhead_M- 351-1 VSS TIME RLT-MEM RUN10.tif ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN11.tif ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp Alaska_ Steelhead_M- 35L1 _VSS_TI ME_RLT-MEM_RU N 12.tif ED C 30232 Digital Data 1/11/2019 Electronic File: Hiloorp Alaska_Steelhead_M- 35L 1 _VSS_TI ME_RLT-MEM_RUN 13.tif ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead_M- 35L 1 _VSS_TI ME_RLT-MEM_RUN 14.tif ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead_M- 35L 1_VSS_TI ME_RLT-MEM_RUN 15.tif ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead_M- 35L 1_VSS_TI ME_RLT-MEM_RUN 16.tif ED C 30232 Digital Data 1/11/2019 Electronic File: Hilcorp Alaska_Steelhead_M- 35L1_VSS_TIME_RLT-MEM_RUN17.tif Log C 30232 Log Header Scans 0 0 2181050 TRADING BAY UNIT M-351-1 LOG HEADERS ED C 30264 Digital Data 1 16590 1/17/2019 Electronic Data Set, Filename: M-351-1.1as ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M -35L1 Daily Report #01 October 1, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M -35L1 Daily Report #02 October 2, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #03 October 3, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #04 October 4, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #05 October 5, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #06 October 6, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #07 October 7, 2018.pdf AOGCC Page 4 of 18 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M-351-1 Operator HILCORP ALASKA LLC API No. 50-733-20680.60-00 MD 16490 TVD 9844 Completion Date Completion Status P&A Current Status P&A UIC No ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #08 October 8, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #09 October 9, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #10 October 10, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #11 October 11, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #12 October 12, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #13 October 13, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #14 October 14, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M -35L1 Daily Report #15 October 15, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M -35L1 Daily Report #16 October 16, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #17 October 17, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M -35L1 Daily Report #18 October 18, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M -35L1 Daily Report#19 October 19, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report#20 October 20, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #21 October 21, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M -35L1 Daily Report #22 October 22, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #23 October 23, 2018.pdf . ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #24 October 24, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M -35L1 Daily Report #25 October 25, 2018.pdf AOGCC Page 5 of 18 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M-3511 Operator HILCORP ALASKA LLC API No. 50-733-20680-60-00 MD 16490 TVD 9844 Completion Date Completion Status PSA Current Status P&A UIC No ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #26 October 26, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #27 October 27, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #28 October 28, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #29 October 29, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #30 October 30, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #31 October 31, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #32 November 1, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #33 November 2, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #34 November 3, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #35 November 4, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #36 November 5, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #37 November 6, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #38 November 7, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #39 November 8, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #40 November 11, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #40 November 9, 2018.pdf ED C 30264 Digital Data - 1/17/2019 Electronic File: Canrig M-351-1 Daily Report #41 November 10, 2018.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M-35L1.dbf ED C 30264 Digital Data 1/17/2019 Electronic File: m-3511,hdr AOGCC Page 6 of 18 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M-351-1 Operator HILCORP ALASKA LLC API No. 50-733.20680.60-00 MD 16490 TVD 9844 Completion Date Completion Status P&A Current Status P&A UIC No ED C 30264 Digital Data 1/17/2019 Electronic File: M-35L1.mdx ED C 30264 Digital Data 1/17/2019 Electronic File: m-3511r.dbf ED C 30264 Digital Data 1/17/2019 Electronic File: m-3511r.mdx ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1_SCL.DBF ED C 30264 Digital Data 1/17/2019 Electronic File: M-35L1_SCL.MDX ED C 30264 Digital Data 1/17/2019 Electronic File: M-35L1_tvd.dbf ED C 30264 Digital Data 1/17/2019 Electronic File: M-35L1_tvd.mdx ED C 30264 Digital Data 1/17/2019 Electronic File: Hilcorp M-351-1 Final Well �— Repo ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - 5in Drilling Dynamics Log MD.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - 5in Drilling Dynamics Log TVD.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - Sin Formation Log MD.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - 5in Formation Log TVD.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - 5in Gas Ratio Log MD.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - 5in Gas Ratio Log TVD.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M -35L1 - 5in LWD Combo Log MD.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - 5in LWD Combo Log TVD.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - Drilling Dynamics Log MD.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - Drilling Dynamics Log TVD.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - Formation Log MD.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - Formation Log TVD.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - Gas Ratio Log MD.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - Gas Ratio Log TVD.pdf AOGCC Page 7 of 18 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 212512019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M-3511 Operator HILCORP ALASKA LLC API No. 50-733-20680-60-00 MD 16490 TVD 9844 Completion Date Completion Status P&A Current Status P&A UIC No ED C 30264 Digital Data 1/17/2019 Electronic File: M -35L1 - LWD Combo Log MD.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - LWD Combo Log TVD.pdf ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - 5in Drilling Dynamics Log MD.tif ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - 5in Drilling Dynamics Log TVD.tif ED C 30264 Digital Data 1/17/2019 Electronic File: M -35L1 - Sin Formation Log MD.tif ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - 5in Formation Log TVDAlf ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - 5in Gas Ratio Log MOM ED C 30264 Digital Data 1/17/2019 Electronic File: M -35L1 - 5in Gas Ratio Log TVDV ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - 5in LWD Combo Log MD.tif ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - Sin LWD Combo Log TVD.tif ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - Drilling Dynamics Log MD.tif ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - Drilling Dynamics Log TVD.tif ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - Formation Log MD.tif ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - Formation Log TVD.tif ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - Gas Ratio Log MD.tif ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - Gas Ratio Log TVD.tif ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - LWD Combo Log MD.tif ED C 30264 Digital Data 1/17/2019 Electronic File: M-351-1 - LWD Combo Log TVD.tif ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 09690'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 09720'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 09750'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 09766'.jpg AOGCC Page 8 of 18 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181050 Well NamelNo. TRADING BAY UNIT M -35L1 MD 16490 ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED C C C C C C C C C C C C C C C C C C C C C C C C C C C C TVD 9844 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data Completion Date Operator HILCORP ALASKA LLC Completion Status P&A API No. 50-733-20680-60-00 Current Status P&A UIC No 1/17/2019 Electronic File: TBU M-351-1 09780'.jpg 1/17/2019 Electronic File: TBU M -35L1 09810'.jpg 1/17/2019 Electronic File: TBU M-351-1 09840'.jpg 1/17/2019 Electronic File: TBU M-351-1 09870'.jpg 1/17/2019 Electronic File: TBU M-351-1 09900'.jpg 1/17/2019 Electronic File: TBU M-351-1 09930'.jpg 1/17/2019 Electronic File: TBU M-351-1 09960'.jpg 1/17/2019 Electronic File: TBU M-351-1 09990'.jpg 1/17/2019 Electronic File: TBU M-351-1 10020'.jpg 1/17/2019 Electronic File: TBU M-351-1 10050'.jpg 1/17/2019 Electronic File: TBU M-351-1 10080'.jpg 1/17/2019 Electronic File: TBU M-351-1 10110'.jpg 1/17/2019 Electronic File: TBU M-351-1 10140'.jpg 1/17/2019 Electronic File: TBU M-351-1 10170'.jpg 1/17/2019 Electronic File: TBU M-351-1 10200'.jpg 1/17/2019 Electronic File: TBU M-351-1 10230'.jpg 1/17/2019 Electronic File: TBU M-351-1 10260'.jpg 1/17/2019 Electronic File: TBU M-351-1 10290'.jpg 1/17/2019 Electronic File: TBU M-351-1 10320'.jpg 1/17/2019 Electronic File: TBU M-351-1 10350'.jpg 1/17/2019 Electronic File: TBU M-351-1 10380'.jpg 1/17/2019 Electronic File: TBU M-351-1 10410'.jpg 1/17/2019 Electronic File: TBU M-351-1 10440'.jpg 1/17/2019 Electronic File: TBU M-351-1 10470'.jpg 1/17/2019 Electronic File: TBU M-351-1 10500'.jpg 1/17/2019 Electronic File: TBU M-351-1 10530'.jpg 1/17/2019 Electronic File: TBU M-351-1 10560'.jpg 1/17/2019 Electronic File: TBU M-351-1 10590'.jpg 1/17/2019 Electronic File: TBU M -35L1 10620'.jpg AOGCC - Page 9 of 18 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M-351-1 Operator HILCORP ALASKA LLC API No. 50-733-20680-60-00 MD 16490 TVD 9844 Completion Date Completion Status P&A Current Status P&A UIC No ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 10650'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 10680'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 10710'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 10740'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 10770'.jpg j ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 10800'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 10830'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 10860'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 10890'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 10920'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 10950'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 10980'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 11010'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 11040'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 11070'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 11100'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 11130'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 11160'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 11190'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 11220'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 11250'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 11280'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 11310'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 11340'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 11370'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 11400'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 11430'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 11460'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 11483'.jpg AOGCC Page 10 of 18 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M-351-1 Operator HILCORP ALASKA LLC MD 16490 TVD 9844 Completion Date ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data I ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data I ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data Completion Status P&A API No. 50-733-20680-60-00 Current Status P&A UIC No 1/17/2019 Electronic File: TBU M-351-1 11490'.jpg 1/17/2019 Electronic File: TBU M-351-1 11520'.jpg 1/17/2019 Electronic File: TBU M-351-1 11550'.jpg 1/17/2019 Electronic File: TBU M-351-1 11580'.jpg 1/17/2019 Electronic File: TBU M-351-1 11610'.jpg 1/17/2019 Electronic File: TBU M-351-1 11640'.jpg 1/17/2019 Electronic File: TBU M-351-1 11670'.jpg 1/17/2019 Electronic File: TBU M-351-1 11700'.jpg 1/17/2019 Electronic File: TBU M-351-1 11730'.jpg 1/17/2019 Electronic File: TBU M-351-1 11760'.jpg 1/17/2019 Electronic File: TBU M-351-1 11790'.jpg 1/17/2019 Electronic File: TBU M-351-1 11820'.jpg 1/17/2019 Electronic File: TBU M-351-1 11850'.jpg 1/17/2019 Electronic File: TBU M -35L1 11880'.jpg 1/17/2019 Electronic File: TBU M -35L1 11910'.jpg 1/17/2019 Electronic File: TBU M-351-1 11940'.jpg 1/17/2019 Electronic File: TBU M-351-1 11970'.jpg 1/17/2019 Electronic File: TBU M-351-1 12000'.jpg 1/17/2019 Electronic File: TBU M-351-1 12030'.jpg 1/17/2019 Electronic File: TBU M-351-1 12060'.jpg 1/17/2019 Electronic File: TBU M-351-1 12090'.jpg 1/17/2019 Electronic File: TBU M-351-1 12120'.jpg 1/17/2019 Electronic File: TBU M-351-1 12150'.jpg 1/17/2019 Electronic File: TBU M-351-1 12180'.jpg 1/17/2019 Electronic File: TBU M-351-1 12210'.jpg 1/17/2019 Electronic File: TBU M-351-1 12240' (2).jpg 1/17/2019 Electronic File: TBU M-351-1 12240'(3) 10% hcl.jpg 1/17/2019 Electronic File: TBU M-351-1 12240'.jpg AOGCC Page 1 I of 18 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M -35L1 Operator HILCORP ALASKA LLC API No. 50-733-20680-60-00 MD 16490 TVD 9844 Completion Date Completion Status P&A Current Status P&A UIC No ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12270'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12300'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12330'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12360'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12390'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12420'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12450.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12480'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12510'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12540'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12570'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 12600'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12630'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12660'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12690'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12720'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12750'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 12780'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12810'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12840'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12870'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12900'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 12930'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 12960%jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 12990'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13020'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13050'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 13080'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13110'.jpg AOGCC Page 12 of 18 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M -35L1 Operator HILCORP ALASKA LLC API No. 50-733.20680-60.00 MD 16490 - TVD 9844 Completion Date Completion Status P&A Current Status P&A UIC No ED C 30264 Digital Data 1 /1 712 01 9 Electronic File: TBU M-351-1 13140'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13170'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13200'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351.1 13230'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13260'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13290'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13320'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13350'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13380'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13410'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13440'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13470'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13500'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13530'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13560'.jpg ED I C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13590'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13620'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 13650'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 13680'.jpg -- ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 13710'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13728'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13740'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13770'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-35LI 13800'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 13830'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 13860'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 13890'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13920'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13950'.jpg AOGCC Page 13 of 18 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M -35L1 Operator HILCORP ALASKA LLC API No. 50-733-20680-60-00 MD 16490 TVD 9844 Completion Date Completion Status PRA Current Status P&A UIC No ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 13980'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14010'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14040'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14070'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14100'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14130'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14160'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14168'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14190'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14220'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14250'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14263'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14280'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14310'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14340'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14370'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14400'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14425'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14460'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14490'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14520'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14550'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14580'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14610'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14640'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14670'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14700'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14730'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14760'.jpg AOGCC Page 14 of 18 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M -35L1 MD 16490 TVD 9844 Completion Date Operator HILCORP ALASKA LLC Completion Status P&A Current Status P&A API No. 50-733-20680-60-00 UIC No ED C 30264 Digital Data 1/1712019 Electronic File: TBU M-351-1 14770'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14790'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14820'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14850'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14880'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14910'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14940'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 14970'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 15000'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 15030'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 15060'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 15090'.jpg ED C 30264 Digital Data 1 /1 712 01 9 Electronic File: TBU M-351-1 15120'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 15150'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 15180'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351.1 15210'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 15240'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 15270'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 15300'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 15330'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 15360'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 15390'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 15420'.jpg _ ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 15450'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M -35L1 15480'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 15510'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 15540'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 15570'.jpg ED C 30264 Digital Data 1/17/2019 Electronic File: TBU M-351-1 15600'.jpg AOGCC Page IS of 18 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M-3511 MD ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED ED 16490 C C C C C C C C C C C C C C C C C C C C C C C C C C C C C AOGCC TVD 9844 Completion Date 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data 30264 Digital Data Operator HILCORP ALASKA LLC Completion Status P&A Current Status P&A Page 16 of 18 API No. 50-733.20680-60-00 UIC No 1/17/2019 Electronic File: TBU M-351-1 15630'.jpg 1/17/2019 Electronic File: TBU M-351-1 15660'.jpg 1/17/2019 Electronic File: TBU M-351-1 15690'.jpg 1/17/2019 Electronic File: TBU M-351-1 15720'.jpg 1/17/2019 Electronic File: TBU M-351-1 15750'.jpg 1/17/2019 Electronic File: TBU M-351-1 15780'.jpg 1/17/2019 Electronic File: TBU M-351-1 15810'.jpg 1/17/2019 Electronic File: TBU M-351-1 15840'.jpg 1/17/2019 Electronic File: TBU M-351-1 15850'.jpg 1/17/2019 Electronic File: TBU M-351-1 15870'.jpg 1/17/2019 Electronic File: TBU M-351-1 15900'.jpg 1/17/2019 Electronic File: TBU M-351-1 15930'.jpg 1/17/2019 Electronic File: TBU M-351-1 15960'.jpg 1/17/2019 Electronic File: TBU M-351-1 15990'.jpg 1/17/2019 Electronic File: TBU M-351-1 16020'.jpg 1/17/2019 Electronic File: TBU M-351-1 16050'.jpg 1/17/2019 Electronic File: TBU M-351.1 16070'.jpg 1/17/2019 Electronic File: TBU M-351-1 16075'.jpg 1/17/2019 Electronic File: TBU M-351.1 16080'.jpg 1/17/2019 Electronic File: TBU M-351-1 16110'.jpg 1/17/2019 Electronic File: TBU M-351-1 16140'.jpg 1/17/2019 Electronic File: TBU M-351-1 16170'.jpg 1/17/2019 Electronic File: TBU M-351-1 16200'.jpg 1/17/2019 Electronic File: TBU M-351-1 16230'.jpg 1/17/2019 Electronic File: TBU M-351-1 16260'.jpg 1/17/2019 Electronic File: TBU M-351-1 16290'.jpg 1/17/2019 Electronic File: TBU M-351-1 16320'.jpg 1/17/2019 Electronic File: TBU M-351-1 16350'.jpg 1/17/2019 Electronic File: TBU M-351-1 16360'.jpg Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M -35L1 MD 16490 TVD 9844 Completion Date ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data ED C 30264 Digital Data Log C 30264 Log Header Scans Well Cores/Samples Information: Name Cuttings INFORMATION RECEIVED Completion Report Y� Production Test Information �YU1 N� Geologic Markers/Tops (Y I Interval Start Stop 9670 16490 Operator HILCORP ALASKA LLC API No. 50-733-20680-60-00 Completion Status P&A Current Status P&A UIC No 1/17/2019 Electronic File: TBU M -35L1 16380'.jpg 1/17/2019 Electronic File: TBU M-351-1 16410'.jpg 1/1712019 Electronic File: TBU M-351-1 16440'.jpg 1/1712019 Electronic File: TBU M-351-1 16454'.jpg 1/17/2019 Electronic File: TBU M-351-1 16470'.jpg 1/17/2019 Electronic File: TBU M-351-1 16490'.jpg 1/17/2019 Electronic File: Show Report 1 M-3511 9810- 9850.pdf 1/17/2019 Electronic File: Show Report 2 M-351-1 10201- 10941.pdf 1/17/2019 Electronic File: Show Report 3 M-3511 11542- 11584.pdf 1/17/2019 Electronic File: Show Report 4 M-3511 12072- 12281.pdf 1/17/2019 Electronic File: Show Report 5 M-351-1 12696- 13273.pdf 1/17/2019 Electronic File: Show Report 6 M-351-1 13512- 14033.pdf 1/17/2019 Electronic File: Show Report 7 M-3511 15656- 16075.pdf 0 0 2181050 TRADING BAY UNIT M-351-1 LOG HEADERS Sample Set Sent Received Number Comments 11/21/2018 1679 Directional / Inclination Data (D Mud Logs, Image Files, Digital Data NA Core Chips Y ICA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Core Photographs Y/ A Daily Operations Summary Cuttings Samples NA Laboratory Analyses Y NA AOGCC Page 17 of 18 Monday, February 25. 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181050 Well Name/No. TRADING BAY UNIT M-351-1 Operator HILCORP ALASKA LLC MD 16490 TVD 9844 Completion Date COMPLIANCE HISTORY Completion Date: Release Date: 8/29/2018 Description Date Comments Compliance Reviewed By: Completion Status P&A Comments Current Status P&A Date: API No. 50.733-20680.60.00 UIC No AOGCC Page 18 of 18 Monday, February 25, 2019 DATE: 1/16/2019 218105 Debra Oudean Hilcorp Alaska, LLC 3 0 2 6 4 AK_GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DRILLING DYNAMICS LOG FORMATION LOG GAS RATIO LOG LWD COMBO LOG DRILLING DYNAMICS LOG CD: NABORS �. Final Well Report �. LAS Data �. Log PDFs �. Log TIFFS 1/16/201910:35 A... Sample Photography �,. Show Reports �. Daily Reports �. DML Data Please acknowledge receipt by RECEIVED JAN 17 2019 AOGCC 11/25/2018 2:47 PM File folder 12/19/2018 10:09 ... File folder 12/18/2018 4:38 PM File folder 1/16/201910:28 A... File folder 1/16/201910:35 A... File folder 1/16/2019 10:38 A... File folder 1/16/201910:38 A... File folder 1/16/201910:38 A... File folder and returning one copy of this transmittal or FAX to 907 777.8510 Received By: (4 o` n }^ A Date: 0I I ISI IxI f DATE 1/10/2019 Debra Oudean Hilcorp Alaska, LLC GeoTech II 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 CD: FINAL BAKER HUGHES DATA GR / MPR / NEUTRON POROSITY / BULK DENSITY DRILLING DYNAMICS GR ASCII Data 1/9/2019 3:23 PM File folder CGM 1/9/2019 3:26 PM File folder Mud Resistivity Report 1/9/2019 3:15 PM File folder PDF Logs 1/9/2019 3:16 PM file folder Survey Data 1/9/2019 3:16 PM File folder TIFF 1/9/2019 3:20 PM File folder RECEIVED JAN 1 1 2019 AOGCC Please include current contact information if different from above. 2 18 105 30232 Please acknowledge receipt by signing and reAurning one copy of this transmittal or FAX to 907 777.8510 Received By: / j /// / X/ \ / I Date: L 4-n � STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑� Suspended❑ 20AAC 25.105 20A C 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: _ 0 1b. Well Class: Development 2 I Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Abend.: 11/12/2018 14. Permit to Drill Number/ Sundry: 218-105 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 r1_ 7. Date Spudded: pl--' October 2, 2018 15. API Number: 50-733-20680-60-00 ' 4a. Location of Well (Governmental Section): Surface: 1144' FNL, 558' FWL, Sec 33, T9N, R13W, SM, AK Top of Productive Interval: N/A Total Depth: 276' FSL, 1503' FEL, Sec 32, T9N, R1 3W, SM, AK 8. Date TO Reached: October 25, 2018 '� 16. Well Name and Number: TBU M-351_1 9. Ref Elevations: KB: 160' • GL:N/A BF:80' • 17. Field / Pool(s): McArthur River Field West Foreland Oil Pool - 10. Plug Back Depth MDTrVD: • 9,670' MD / 8,736' TVD 18. Property Designation: • ADL018730 / ADL017594 ' 41b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x-3]p�132� V( 72— y22499356 • Zone- 4 ' TPI: x- Z11"5 �' y agyq��,SH-" Zone- Total Depth: x- Q4eW "^6 y- 2 451 Zone- 4 11. Total Depth MD/TVD: • 16,490' MD / 9,844' TVD • 19. DNR Approval Number: N/A 12. SSSV Depth MDrrVD: N/A 20. Thickness of Permafrost MDfrVD: N/A 5. Directional or Inclination Survey: Yes : (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 183' (ft MSL) 21. Re-drill/Lateral To Window MD/TVD: 9,670' MD / 8,736' TVD 22. Logs Obtained: List all logs mn and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR / MPR / NEUTRON POROSITY / BULK DENSITY MD / FORMATION LOG MD TVD 5IN & 21N / GAS RATIO LOG MD TVD 5 IN & 21N / LWD COMBO LOG MD TVD / DRILLING DYNAMICS MD 51N & 21N MD TVD L 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED N/A 24. Open to production or injection? Yes ❑ No If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): DATE I f ke- ( VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDrrVD) N/A N/A N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: I lCalculated 124 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 n /� qCO)) INS) 9N PAGE 2 REMITS MG SAN „ 1 !`'19 SubmtOIGI AL on v 1 0 28. CORE DATA Conventional Core(s): Yes ❑ No ❑Q Sidewall Cores: Yes ❑ No ❑✓ . If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base N/A N/A Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval N/A N/A information, including reports, per 20 AAC 25.071. G1 9,640' 8,710' G2 9,707' 8,768' G5 9,895' 8,924' Coal 59 10,129' 9,086' HK2 10,199' 9,128' HK3 10,506' 9,269' HK4 10,956' 9,382' Coal 60 11,307' 9,464' HK5 11,394 9,485' HK6 12,052' 9,638' Coal 61 12,458' 9,730' HK7 12,566' 9,749' West Foreland 13,455' 9,821' - Formation at total depth: West Foreland 31. List of Attachments: Wellbore Schematic, Daily Drilling Reports, Definitive Directional Surveys 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: Monty Myers Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: Cdjfl er hilcor .com Authorized 1 ' / / Contact Phone: 777-8389 Mate: Signature: 26 `O INSTRUCTIONS General: This for 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-Altemating-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 612017 Submit ORIGINAL Only Schwartz, Guy L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Friday, November 9, 2018 9:54 AM To: Schwartz, Guy L (DOA) Subject: PTD 218-105 (M-351-1 Liner Failure) G uy, While attempting to run our 7" liner in the upper lateral of M-35 (named M-351-1) we were unable to pass 11,466'. At this point our pipe became plugged and we were unable to circulate, so the decision was made to POOH to inspect the liner and make a clean out run with a bit and drill pipe. When we got out of the hole with our liner we had discovered that we had twisted off the 7" liner in the body of the pipe leaving 118' of fish in the hole. After discussing with the asset team about options to fish or mill the remaining piece of casing in the hole, it was determined to be too risky to the well. With the seal bore diverter in place we have a restricted ID to pass through that limits us on what size of tools can be run. The decision has been made to abandon the upper lateral (M -35L1) using a tieback assembly across the window. We will run a set of bullet seals, 3 joints of 7" liner, and a 7"X9-5/8" packer above the window to isolate the lateral. This will completely seal us off from the lateral. Please advise if you are ok with this plan. Thank you! Monty M Myers Drilling Manager 907.538.1168 (c) 907.777.8431(0) H Coro Alaska, JUL( RKB to MSL = 160', RKB to Seafloor = 345' @417' q 34" a 28 2 Cement to surface 13 -3/8 - TOC @ 2,590'Per CBL ES -ICP Stage Tool @ 6,398' Did not close cement barrier only LTP®9,5/4 CASING DETAIL �o 17 V/I Scab Llne Size Wt M35 _1 Wndow Conn ID Across L1 Btm 34" x 28" 9670' 7' Conductor 27.5" Window to 97'd 488' 13-3/8" 68 L-80 BTL 12.415" Surf 2,505' 9-5/8" ML2xP Harte" L-80 BTC 8.681" Surf 10,595' @0,719' 26 L-80 DWC/C-SC 6.276" "See note on M-3611' TOC @ 7" 26 L-80 DWC/C 6.276" 11,000' 15,335' 9/28/2018 10,174' 9,149' TUBING DETAIL .. x 3-1/2" 9.2 L-80 l W F3 WF -1 WF1 F .1 PBTD: 15,250' TD: 15,375' Max Hole Angle 92° @ 15,374' SCHEMATIC Well: M-35 / M-351_1 I PTD: 217-119/218-105 API: 50-733-20680-00-00 L1: 50-733-20680-60-00 Last Completed: 11/21/18 *** M -35L1 note -M-35L1 was successfully drilled to TD @16,490' MD/9,844' TVD. During casing running operations, a fish (118' of casing/cementing jewelry) was left in hole. Decision was made to abandon further attempts at saving wellbore. The M -35L1 window is now covered by 7" tieback/scab liner from 9,574' MD to 9,719' MD. Fish in hole is -11,348'- 11,466' MD. *** Updated By: CID 12/26/2018 CASING DETAIL JEWELRY DETAIL No Size Wt Grade Conn ID Top Btm 34" x 28" 75' Conductor 27.5" Surf 488' 13-3/8" 68 L-80 BTL 12.415" Surf 2,505' 9-5/8" 47 L-80 BTC 8.681" Surf 10,595' 7" (tie back) 26 L-80 DWC/C-SC 6.276" 9,574' 9,719' 7" 26 L-80 DWC/C 6.276" 9,719' 15,335' 9/28/2018 10,174' 9,149' TUBING DETAIL 4.000" Discharge, Bolt -On 3-1/2" 9.2 L-80 MT 2.992" Surf 9,484' 2-7/8" 6.5 1_-80 8 round EUE 2.441" 9,484' 10,174' *** M -35L1 note -M-35L1 was successfully drilled to TD @16,490' MD/9,844' TVD. During casing running operations, a fish (118' of casing/cementing jewelry) was left in hole. Decision was made to abandon further attempts at saving wellbore. The M -35L1 window is now covered by 7" tieback/scab liner from 9,574' MD to 9,719' MD. Fish in hole is -11,348'- 11,466' MD. *** Updated By: CID 12/26/2018 PERFORATION DATA JEWELRY DETAIL No Depth MD Depth TVD ID OD Item HIM (TVD) 75' 75' Date Status Tbg Hanger - SMB-22-ESP-4CCL-EN, 13-5/85M x 4 Y: EUE 8rd lift & Susp, w/4" type H BPV profile, ported for BIW penetrator 1 463' 463' 2.813" 5.030" TRSV- Halliburton NE 2 486' 486' 2.940" 8.310" Packer-D&L Oil Tools Twin Seal Hydroset 11 w/WFTvent valve 9,841' 9,484' 8,572' 2.441" 4.280" Crossover 3 10,142' 9,124' 2.310" 3.220" %-nipple-2.31" Profile 9/28/2018 10,174' 9,149' N/A 4.000" Discharge, Bolt -On 10,174' 9,148' N/A 4.000" Ported Pressure Sub 10,175' 9,150' N/A 4.000" Pumps (x3) -Summit 400 Series 111 stage SF2700AR 10,241' 9,201' N/A 4.000" Intake-w/Screen 4 10,242' 9,201' N/A 4.000" Seals (x2) -Tandem BPBSL 10,258' 9,214' N/A 4.563" Motors (x2) -Summit 340HP/3055V/77A(UT 160HP/1438V&LT 180HP/1617V) 10,305' 9,250' N/A' 4.560" Gauge (Zenith)/ Centralizer/ Anode --Note-9-5/8" Straight Hole Pump Tangent Section 9,450'to 9,600'; 7" Straight Hole Pump Tangent Section 10,116' to 10,306' *** M -35L1 note -M-35L1 was successfully drilled to TD @16,490' MD/9,844' TVD. During casing running operations, a fish (118' of casing/cementing jewelry) was left in hole. Decision was made to abandon further attempts at saving wellbore. The M -35L1 window is now covered by 7" tieback/scab liner from 9,574' MD to 9,719' MD. Fish in hole is -11,348'- 11,466' MD. *** Updated By: CID 12/26/2018 PERFORATION DATA Zone Top (MD) Stm (MD) Top (TVD) HIM (TVD) Feet SPF Date Status WF -1 11,015' 11,955' 9,678' 9,826' 940' 6 9/28/2018 Open WF -1 11,982' 14,624' 9,827' 9,841' 2,642' 6 9/28/2018 Open WF -1 14,692 15,224' 9,839' 9,823' 532' 6 9/28/2018 Open *** M -35L1 note -M-35L1 was successfully drilled to TD @16,490' MD/9,844' TVD. During casing running operations, a fish (118' of casing/cementing jewelry) was left in hole. Decision was made to abandon further attempts at saving wellbore. The M -35L1 window is now covered by 7" tieback/scab liner from 9,574' MD to 9,719' MD. Fish in hole is -11,348'- 11,466' MD. *** Updated By: CID 12/26/2018 U Well Name: MRF M-351-1 Field: McArthur River Field County/State: CIO, Alaska r (LAT/LONG): avation (RKB): API#: 50-733-20680-60-00 Spud Date: 10/3/2018 Job Name: 1812535 M -35L1 Drilling Contractor Rig 51 AFE #' 1812535 AFE $: $5,703,520 Hilcorp Energy Company Composite Report Op$ Summary 11. 10/1/2018 Finish testin BOPS. Test all BOPS to 250 low and 3500 high. Had one fail pass due to air in system when we tested the blind rams.;RD test equip and blow do ail the Iines.;Sewice the rig and TD.;Monitor well and it's static POH V 3242' and it started flowing over the DP.;Circ bottoms up to get it back in balance.;POH to baker setting tool. Tool looked good. Break and LD tool.;Drain stack and set test plug for a safety plug. LD 14 stds of 3 12 DP out of derrick.;Pull test plug and set wear ring.;PU MWD orienting BHA #15. RIH one stand and shallow hole test MWD.;RIH with MWD orienting BHA #15 to 6995'.;Continue RIH with BHA #15 to 9707'.;Break circulation at 350 GPM/400 psi. Tag up at 9732'. Snap in and determined tool face of 76 R. Snap out. P/U 270, S/O 210.;Circulate STS at 350 GPM/480 psi. High gas at bottoms up 90 units.;POOH with BHA #15 to 3500'.;Daily fluid loss dawn hole: 0 bbls. Total fluid loss down hole: 112 bbls OA = 200 psi IA = 14 psi Metals: 392 lbs. 10/2/2018 POOH with BHA #15 to Baker tools. Break do tools and put MWD in mouse hole for next run.;PU whipstock running assem. Scribe tools from anchor and PU whipstock. While adjusting anchor hand noticed a loose connection above that had came torqued from town. Tighten loose connection and check the other onnections. Had to scribe the tools again and adjust the anchor to 56° from high side.;PU last 3 magnets and XOs . Run 6 stds of HWDP and 1 std of 5".;MU TO V\ and test MWD. tested good. Continue RIH w/ whipstock to 5600'.;Continue RIH w/ whipstock f/ 5600' V 9632'.;Establish circulation obtain parameters, orient J whipstock 45° R Slack off V 9732', P/U 10k over to verify latch, slack off orientation showed 20' R Slack off shear Whipstock w/ 40k down weight,;Displace Diesel 1 " w/ OBM.;Mill Window 9670' TOW V 9682' 450 gpm 1775 psi 80 rpm 5-10k tq;Daily fluid loss down hole:0 bbls. W Total fluid loss down hole: 0 bible OA = 200 psi IA= 12 psi Metals: 90 lbs. 10/32018 Mill window f/ 9682't/ 9687' BOW. 450 GPM, 1700 Psi. 100 RPM, 5 to 10k TQ, WOB 5k. Avg ROP 1.6 FPH.;Drill formation f/ 9687't/ 970T. 450 GPM,1700 Psi, 5 to 10k TO, 100 RPM, WOB 14k. Avg ROP 4.4 FPH.;Work mills through window to dress window. Stand back one stand. Circ until mud wt was balanced at 9.25 ppg.;Perform FIT to 12.5 ppg. Good test. Blow on lines and pump dry Iob.;POH f/ 9663't/ 8550'. Layed do and replaced 10jts with worn out hard bands.;Continue POH f/ 8550't/ 735' Changing out Its with bad hard band 12 jts total.;Stand Back and L/D Window Milling BHA, Gauge mills lower mill 1/8 under but upper mill in gauge 186 Ibis of medal off three magnets.;M/U Mud Motor BHA #3 upload MWD, change bend in motor 111, M/U bit RIH PIU flex collars and HWDP RIH V 1980'.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 0 bbls OA = 200 psi IA= 12 psi 10/4/2018 RIH w/ mudmotor V 1980' V 9669'. Fill pipe and get up wt 288k On wt 220k. Shut pump down and slid through windowto bottom at 9707' with no issues. Bring pumps on and get good me reading.;Slide drill 8 1/2" hole V 9707't(9751' and rotary drill to 9766. 440 GPM, 2270 psi. 45 RPM, 6 to 9k TO, 54 units gas high.;Circ bottoms up, get SPRs, and pump dry job.;Pull up through window with very slight overpulls when tools came through. Continue POH f/ 9669 V 4350'. Swapped out 4Its that had worn out hardbands.;Continue POH f/ 4350'V 776' ;Stand back and L/D BHA as per DD/MWO, change out BPA under floor.;M/U BHA #4 Rotary Steerable Assy. upload MWD, Load sources RIH w/ BHA Shallow test tools @ 359.;RIH f/ 350' P/U singles off the deck V 2052'.;Daily fluid loss down hole: 0 bbls. Total fluid loss dawn hole: 0 bbls OA = 200 psi [A= 14 psi 10/5/2018 RIH PU the last of the 72 Its. Count DP on deck Numerous times and we have 1 extra jt.;POH to HWDP check pipe count. Had 72 Its. so drillers count was good.;RIH f/ 167' [BHA] V3500' and fill pipe. Continue RIH installing and changing out worn rotating rubbers to 7009. Fill pipe and RIH to 9600'. Fill pipe.;Circ working rate up to 5.5 BPM while cutting and slipping drilling line. Service rig.;RIH to top of window and circ down through window to 9762'. 466 gpm, 2100 psi.;Wash and ream f/ 9762'V 9769. Directional drill 812" hole f/ 9766'11 9830' PUW/SOW/ROT 275/205/220 530 gpm 2500 psi 130 RPM 7-9k tq on bottom 10.1 ECD Avg ROP 10.6 fph.;Directional drill 8 12" hole f/ 9830' V 9971' PUW/SOW/ROT 275210/225 530 gpm 2500 psi 130 RPM 7-9k tq on bottom 10.1 ECD Avg ROP 23.5 fph.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 0 bbls Distance to plan 2.05' below 3' Left 17' of separation OA = 200 psi [A= 13 psi 1 0/612 01 8 Directional drill 81/2" hole V 9971' V 10,080'. Up W270, Dn wt 210, Rt W 220, 536 GPM, 2460 Psi, 130 to 150 RPM. 9 to 1 Ok TO, MW 9.25, ECD 10.1, Max gas 108 units, Avg ROP 18.2 FPH.;Made connection and power loss to blowers on the TD. Stood the std back to get off bottom. Turned breakers for blowers back on and everything was good. Made connection again.;Directional drill 81/2" hole It 10,080'V 10,108'. Up wt 270, Dn wt 210, Rt wt 220, 526 GPM, 2370 Psi, 130 to 150 RPM. 9 to 10k TO, MW 9.25, ECD 10.05, Max gas 59 units, Avg ROP 28 FPH.;Directional drill 812" hole f/ 10,108'V 10,274'. Up wt 270, Dn wt 210, Rt wt 220, 537 GPM, 2500 Psi, 130 to 150 RPM. 9 to 10k TO, MW 9.25, ECD 10.02, Max gas 59 units, Avg ROP 27.6 FPH.;Direcfional drill 8112" hole f/ 10,274't/ 10,415' Up wt 275 Dn wt 212, Rt wt 225, 537 GPM, 2500 Psi, 130 to 150 RPM. 9 to 10k TO, MW 9.25, ECD 10.02, Max gas 96 units, Avg ROP 23.5 FPH Pump tandem sweep around @ 10275' no increase in cuttings when sweep back.;Directional drill 812" hole f/ 10,415' V 10,577' Up wt 275 Dn wt 212, Rt wt 225, 537 GPM, 2500 Psi, 130 to 150 RPM. 9 to 10k TO, MW 9.25, ECD 10.02, Max gas 141 units, Avg ROP FPH ;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 0 bbls Distance to plan .11' below 5.88' Left 150' of separation OA = 200 psi IA = 16 psi Metals: 460 lbs. 10/72018 Directional drill 812" hole f/ 10,57T V 10,743' Up wt 280 Dn wt 208, Rt wt 225, 535 GPM, 2500 Psi, 130 to 150 RPM. 9 to 11 k TO, WOB 25k, MW 9.25, ECD 10.0, Max gas 85 units, Avg ROP 25.4 FPH, Pump tandem sweep and it came back on time with no increase in cuttings.;Check flow. Get SPR. Short trip In top of window on elevators. Had a few slight over pulls starting at 10,207'. Pulled through window slow again with slight over pulls. Up wt 295, Dn wt 222 w/ no pump.;Had electrician working on mud pump assignment issues. Went through all pump assignment and didn't find any issues. Replaced light bulbs in consul. Service rig and TD. Tied some wires back on the TD that still could have been rubbed by the ODS air tugger.;RIH to 10,650 with no issues and wash last std to bottom.;Direcdonal drill 8 1/2" hole f/ 10,743' V 10,805' Up wt 280 Dn wt 208, Rt W 225, 500 to 535 GPM, 2300 to 2500 Psi, 130 to 150 RPM. 10 to 11 k TQ, WOB 18 to 25k, MW 9.25, ECD 10.0, Max gas 94 units, Avg ROP 20.6 FPH.;Directional drill 812" hole It 10,805' V 10,910' Up wt 280 Dn wt 208, Rt wt 223, 530 to 535 GPM, 2300 to 2500 Psi, 130 to 150 RPM. 10 to 11 k TO, WOB 18 to 25k, MW 9.25, ECD 10.1, Max gas 71 units, Avg ROP 17.5 FPH.;Directional drill 8 12" hole V 10,910' V 11,000' Up wt 280 Dn wt 208, Rt wt 223, 530 to 535 GPM, 2300 to 2500 Psi, 130 to 150 RPM. 10 to 11 k TO, WOB 18 to 25k, MW 9.25, ECD 10.1, Max gas units, Avg ROP 15 FPH, #1 Mud Pump Down V 25 min, Switch in pump room accidentally tripped.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 0 bbls Distance to plan .001' Above 2.2' Left 328' of separation OA = 200 psi IA= 18 psi Metals: 474 lbs. 10/8/2018 Directional drill 812" hole V 11,000' V 11,095' Up wt 280 Dn W 208, Rt W 223, 500 to 530 GPM, 2250 to 2500 Psi, 130 to 150 RPM. 10 to Ilk TQ, WOB 20 to 30k, MW 9.25, ECD 10, Max gas units 65, Avg ROP 15.8 FPH.;Directional drill 8 12" hole f/ 11,095' V 11,199' Up wt 282 Dn wt 210, Rt wt 225, 505 to 530 GPM, 2350 to 2560 Psi, 130 to 155 RPM. 10 to l l k TQ, WOB 20 to 35k, MW 9.25, ECD 10.1, Max gas units 67, Avg ROP 17.3 FPH.;Directional drill 812" hole f/ 11.199't] 11,304' Up wt 285 Dn wt 208, Rt W 223, 505 to 530 GPM, 2350 to 2560 Psi, 130 to 170 RPM. 10 to Ilk TO, WOB 20 to 35k, MW 9.25, ECD 10.1, Max gas units 80, Avg ROP 17.5 FPH Pump tandem sweep no increase in cuttings on retum.;Direcbonal drill 812" hole f/ 11,304' V 11,430' Up wt 288 Dn wt 210, Rl W 228, 505 to 530 GPM, 2350 to 2560 Psi, 130 to 160 RPM. 10 to 11 k TQ, WOB 20 to 35k, MW 9.25, ECD 10.1, Max gas 84 units , Avg ROP 21 FPH ;Daily fluid loss down hole: 0 bbis. Total fluid loss down hole: 0 bbls Distance to plan .34' Below 1.07' Right 353' of separation OA = 210 psi IA = 19 psi Ann ih, 10/92018 Directional drill 8112" hole V 11,430' V 11,483' Up wt 290 Dn wt 205, Rt wt 225, 509 to 530 GPM, 2400 to 2590 Psi, 130 to 160 RPM. 10 to 11 k TO, WOB 20 to 38k, MW 9.25, ECD 10.1, Max gas 55 units, Avg ROP 15 FPH. Circ bottoms up while drilling slow.;Finish circ bottoms up and get SPR. Up wt 310k, Dn wt 225k.;POH on elevators to 9611'. At 101 80'we had slight overpulls. at 10,156' to 10,140' we pulled uptight twice w/ 70k over and the third time it pulled right through. Pulled through window with 2 to 4k overpull.;Pump dry job and adjust wrap on service Ioop.;POOH V 9611' V 167'.;Stand back BHA Unload sources, Break Bit, Download MWD.;MN new bit, upload MWD, load sources, RIH V 64U shallow test tools 450 gpm 1000 psi.;RIH f/ 640' V 9526' filling pipe every 2500'.;Service rig and top drive while circulating 450 gpm 1900 psi.;RIH V 9526' Vl1409.;Get parameters wash and ream to bottom @ 11,483'.;Directicnal drill 8 1/2" hole f/ 11,483' V 11,491' Up wt 290 Dn wt 205, Rt wt 230, 509 GPM, 2600 Psi, 140 RPM. 10 to 11 k TQ, WOB 20k, MW 9.25, ECD 10,1, Max gas 120 units , Avg ROP 5.3 FPH.;Daily fluid loss down hole: 0 obis. Total fluid loss down hole: 0 bbls Distanceto plan .47' Below .84' Right OA = 200 psi IA =10 psi 1 0/1 012 01 8 Directional drill 8112" hole f/ 11,491't/ 11,593' Up wt 288 Dn wt 205, Rt wt 230,534 GPM, 2850 Psi, 140 RPM. 10 to 12k TO, WOB 23 - 26k, MW 9.25, ECD 10.05, Max gas 62 units, Avg ROP 17 FPH.;Directional drill 812" hole f/ 11,593' V 11,692 wt 288 Dn wt 208, Rt wt 228, 523 GPM, 2720 Psi, 125 RPM. 11 to 13k TO, WOB 22 - 26k, MW 9.25, ECD 10.05, Max gas 55 units , Avg ROP 16.5 FPH.;Directional drill 8 1/2" hole f/ 11,692 V 11,814' Up wt 290 Dn wt 208, Rt wt 225,526 GPM, 2735 Psi, 125 RPM. 11 to 12k TO, WOB 24 - 26k, MW 9.25, ECD 10.05, Max gas 61 units , Avg ROP 20.3 FPH.;Directional drill 812' hole f/ 111,814Y 11,932' Up wt 290 Dn wt 210. Rt wt 230,534 GPM, 2850 Psi, 140 RPM. 10 to 12k TO, WOB 23 - 26k, MW 9.25, ECD 10.05, Max gas 67 units, Avg ROP 19.6FPH.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 0 bbls Distance to plan 1.02' Below 3.56' Right OA = 200 psi IA = 18 psi 10/1112018 Directional drill 8 12" hole f/ 11,932'ti 12,071' Up wt 290 On wt 208, Rt wt 228,526 GPM, 2890 Psi, 125 RPM. 12 to 13k TO, WOB 23 - 26k, MW 9.25, ECD 10.19, Max gas 93 units, Avg ROP 23.1 FPH.;Direcbonal drill 8 12" hole f/ 12,071' V 12,244' Up wt 290 On wt 210, Rt wt 235, 523 GPM, 2800 Psi, 125 RPM. 10 to 12k TO, WOB 24k, MW 9.25, ECD 10.14, Max gas 100 units , Avg ROP 28.8FPH.;Directional drill 81/2" hole it 12,244' V 12,333' Up wt 290 Dn wt 210. Rt wt 235, 523 GPM, 2800 Psi, 125 RPM. 10 to 12k TO, WOB 24k, MW 9.25, ECD 10.14, Max gas 62 units, Avg ROP 14.83 FPH.;Directional drill 81/2" hole f/ 12,333' V 12,375' Up wt 300 On wt 220, Rt wt 235, 523 GPM, 2800 Psi, 125 RPM. 10 to 12k TO, WOB 24k, MW 9.25, ECD 10.14, Max gas 62 units , Avg ROP 10.5 FPH Pump tandem sweep 10% increase in cuftings.;Short trip f/ 12375' V 11390' No hole issues, RIH V12355'.;Wash and ream f/ 12355'V 12379.;Directional drill 1/2" hole f/ 12,375' V 12,380' Up wt 300 Dn wt 220, Rtwt 235, 523 GPM, 2800 Psi, 125 RPM. 1D to 12k TO, WOB 24k, MW 9.25, ECD 10.14, Max gas 62 units, Avg ROP 10 FPH.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 0 bbls Distance to plan .41' Below 1.80' Left OA = 210 psi IA = 22 psi Metals: 507 lbs. 1011212018 Directional drill 812" hole f/ 12,380't/ 12,510 Up wt 292 Dn wt 202, Rt wt 232, 530 GPM, 2990 Psi, 125 RPM. 12 to 13k TO, WOB 24 -30k, MW 9.25, ECD 10.14, Max gas 58 units , Avg ROP 21.6 FPH.;Directional drill 812" hole V 12,510' V 12,731 Up wt 295Dn wt 205, Rt wt 235, 525 GPM, 2990 Psi,125 RPM. 10 to 12k TO, WOB 24 -26k, MW 9.25, ECD 10. 1, Max gas 100 units , Avg ROP 36.8 FPH.;Directional drill 81/2" hole f/ 12,731' V 12,892' PUW/SOW/ROT,315,202,234, 515 GPM, 2990 Psi, 125 RPM. 10 to 12k TO, WOB 24 -26k, MW 9.25, ECD 10.1, Max gas 58 units , Avg ROP 26.8 FPH.;Directional drill 8 1/2" hole 1/ 12,892' V 13,121' PUW/SOW/ROT,310,200,231, 525 GPM, 2950 Psi, 125 RPM. 10 to 12k TO, WOB 14 -26k, MW 9.25, ECD 10.26, Max gas 86 units , Avg ROP 38.2 FPH.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 0 bbls Distance to plan .84' Above 4.11' Left OA = 210 psi IA = 22 psi 10/13/2018 Continue Directional drill 8 12" hole f/ 13,121't/ 13,301' PUW/SOW/ROT,305,200,225, 515 GPM, 2980 Psi, 165 RPM. 12 to 14k TO, WOB 15 -29k, MW 9.25, ECD 10.27, Max gas 69 units, Avg ROP 36.0 FPH.;preform clean up cycle by Pumping tandem sweeps 40 bbl low vis low weight 8.8 ppg w/ walnut flag fallow by 35 bbls weighted (10.6 ppg high vis =400 fv) while drilling @ 13,212' on time w/+200% increase in cuttings. Circ clean while pumping , rotating and reciprocating at max rate.;Short trip, Pooh on elevators f/ 13,301' V 12, 277' with no issue monitor static well reboot canrig rig watch server and false fire alarm in camp rih on elevators kelly up fill pipe and wash last stand to btm @b 13, 301' make connection survey and do Iink.;Launch tandem sweeps and resume Directional drilling 812" hole f/ 13,301' V 13,364' PUW/SOW/ROT,310,208,228, 535 GPM, 2950 Psi, 165 RPM. 12 to 13k TO, WOB 15 -k, MW 9.25, ECD 10.27, Max gas 43 units , Avg ROP 18 FPH. sweeps back on time w/ 150% increase in cuttings.;Directional drilling 81 /2" hole f/ 13,364' V 13,491' PUW/SOW/ROT,320,210,230, 535 GPM, 2950 Psi, 150 RPM. 12 to 13k TO, WOB 15 -k, MW 9.25, ECD 10.27, Max gas 36 units, Avg ROP 21.6 FPH. pump sweep @13380' back on time w/ 25% increase in cuttings.;Directional drilling 812" hole f/ 13,491't/ 13,714' PUW/SOW/ROT,320,215,230, 535 GPM, 2950 Psi, 150RPM. 12 to 14k TO, WOB 15 -k, MW 9.25, ECD 10.35, Max gas 71 units, Avg ROP 37.1 FPH. pump sweep @ 13682'.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 0 bbls Distance to plan .43' Above .84' Left OA = 210 psi IA = 26 psi Metals: daily =13 lbs. total =531 lbs. 10/14/2018 Directorial drilling 8 12" hole f/ 13,491'V 13,714' PUWISOW/ROT,310,21,228, 528 GPM, 2980 Psi, 150, RPM. 12 to 14k TO, WOB 15 -29k, MW 9.25, ECD 10.26, Max gas 56 units, Avg ROP 7.0 FPH. pump sweep @ 13682'sweeps back on time w/ 150% increase in cutfings.;Discuss NBI build issue w/ town. Dn link and retract ribs Pump, rotate and reciprocate at max rate and circ clean flow chk ok w/ slight seepage rack back one std once pumps shut do wash pipe packing failed.;chg out wash pipe packing and test same by back reaming and pumping out one std (ok).;Pooh on elevators V 12, 200' with no issues just few 30k over bobbles. Kelly up pump tandem sweeps around at max rate while rotating and reciprocating pipe full std sweep back on time w/ 125% increase in cutfings.;Resume pooh on elevators w/ two areas of 70k over pulls work through both on elevators 10,438' - 10,400' 8 10,357'- 10,336' and no over pulls while pulling tools through window and into csg V 9609.;Monitor static well w/ just seepage losses while servicing rig. Service ,clean and inspect TDS , service dwk, crown and blocks.;Continue Pooh inspectmg NRP and dp hard bands, Stand back BHA V 384'.;Unload sources download, MWD, break bit, UD BHA components, Pull wear ring.;M/U BHA #6 Upload MWD, load sources RIH C/O jts w/ worn hard band V 2182'.;Daily fluid loss down hole: 8 bbls. Total fluid loss down hole: 8 bbls Distance to plan .49' Above .09' Left OA = 210 psi IA = 25 psi Metals: daily = 4 lbs. total = 535 lbs. 10/15/2018 Continue RIH shallow hole test tools @ 1119 @ 430 gpm @ 825 psi C/O 6jts of dp w/ wom hard band V 3883' inspect mp #1 valves and seats chg out valve and seats on pod #3.;Kelly fill pipe warm mud 422 gpm @ 970 psi.;Build 5" test jt and hang off drilling assy on test plug and r/up test equipment purge air and shell test ok.;Waft on chopper w/ state man screen do shakers to 170 mesh continue inspecting MP fluid ends.;Start Test#1 as per regulations while waiting on chopper w/ state man State man Mr. Austin McLeod on board just past noon platform orientation and safety meeting review test chart and resume testing bope (CMV #10 failed mech changed out guts).;RIH 113883' V 9618' changing out jts with worn hard bands.;Circulate and condition mud warming system, staging pumps to drilling rate 540 gpm 2400 psi.;RIH f/ 9618' V 12,292' work through fight spot with pumps and rotary @ 10247', continue adjusting super sliders as per W WT rep.;Circulate and condition mud stage pumps V 550 gpm 2900 psi hole unloading and large chunks of coal back to surface on and before bottoms up.;Daily fluid loss down hole:0 bbls. Total fluid loss down hole: 8 bbls Distance to plan .49' Above .09' Left OA = 200 psi IA = 15 psi 10/16/2018 Resume RIOH V 12,278' V 13,329' working through tight spots on elevators. Unable to pass 13, 329 Kelly up fill pipe work, wash & ream work and through pack-off issues V tag at 13, 708' (20' high) from btm count pipe chk and re-chk pipe tally s. Rack back std;and take chk shot survey w/ bit depth @ 13,678' and confirmed same as last run. Discuss issue w/ town.;Circulate and condition mud while reciprocating pipe at 550 GPM/2900 psi. 70 RPM/13 K torque.P/U 310, S/O 220.;Direefional drilling 812" hole f/ 13,728' V 13,8401. PUW/SOW/ROT,315,220,231, 530 GPM/2772' psi, 152, RPM. 13 tc 14k TQ, WOB 15-22k, MW 9.3, ECD 10.3, Max gas 24 units, Avg ROP 22.4 FPH. Pump tandem sweeps @ 13682' while drilling. Sweeps back on time w/150% increase in cuttings.;Directional drilling 8 1/2" hole f/ 13,840' V 14,080'. PUW/SOW/ROT,315,220,231, 550 GPM2950 psi, 150, RPM. 13 to 14k TQ, WOB 15 -22k, MW 9.3, ECD 10.3, Max gas 38 units, Avg ROP 40.0 FPH.;Directional drilling 812" hole f/ 14,080' V 14,165'. PUW/SOW/ROT,315,220,231, 550 GPW2950 psi, 150, RPM. 13 tc 14k TQ, WOB 15 -22k, MW 9.3, ECD 10.3, Max gas 45 units, Avg ROP 28.3 FPH. Pump tandem sweeps @ 14,100' while drilling. Sweeps back on time w/ 50% increase in cuttings.;While picking up for survey at 14,165' pipe became stuck. Jar two licks to free pipe. No pack off issues. Lost swab in MP #1. Work pipe while C/O swab.;Directional drilling 81/2" hole f/ 14,165' V 14,190'. PUW/SOW/ROT,315,220,231, 550 GPM/2950 psi, 150, RPM. 13 to 14k TQ, WOB 15 -221k, MW 9.3, ECD 10.4, Max gas 45 units, Avg ROP 25.0 FPH.;Daily fluid loss down hole: 10 bbls, Total fluid loss down hole: 18 bbls Distance to plan .87' Above, 3.15 Right OA = 200 psi ]A= 15 psi Metals: daily = 16 lbs. total = 551 lbs. 10/172018 Directional drilling 81/2" hole f/ 14,190' V 14,252'. PUW/SOW/ROT,315,220,231, 550 GPM/2950 psi, 150, RPM. 13 to 14k TQ, WOB 15 -22k, MW 9.3, ECD 10.4, Max gas 24 units , Avg ROP 31.0 FPH.;Work pipe and trouble shoot directional tools BCPM sync issue ( unable to keep tools sync) was able to send down link and retract ribs.;Udn single pump tandem sweeps at max rate rotating and reciprocating full std sweeps back 13BBL late w/ 125 % increase in cuttings p/up single.;Back ream ooh f/ 14,252' to 966U @ 1800-2400 FPH rotating 165-185 rpm 530-550 gpm. Except 25' when Spiro torque enter window and on whip stock face just pump . W/ break backs @ 13,584', 13,515, 13,505, 12,945', 12,633', 12,441', 11285' inspecting hard band and NRP's.;Pump tandem sweeps at 550 GPM2400 psi while rotating and reciprocating pipe at 60 RPM. Sweeps came back on time with no increase in cuttings.;Monitor well on trip tank while servicing rig. Change out saver sub. Install new bolts on TDS guard.;RIH on elevators to 9900'. Wash and ream through coals from 91 10,270'. (unable to work through) 500 GPM/2300 psi. 160 RPM/12.5 torque. Had coal coming over shakers.;Circulate and clean hole at 520 GPM2400 psi while working pipe. 200% increase in cuttings of coal over shakers. 150 RPM/12.5 torque.;RIH on elevators from 10,270'to 14,192' with the exception of having to W/R 10,708' -10,770', 11,223' - 11,250, 11,857'-11,870'.;Drill ahead from 14,252'to 14,264'. Troubleshoot directional tool issues.; Daily fluid loss down hole: 10 bbls. Total fluid loss down hole: 18 bbls Distance to plan .87' Above, 3.15 Right OA = 200 psi IA = 15 psi 10/18/2018 Udn single pump tandem sweeps at max rate rotating and reciprocating full std. Sweeps back 20 BBL late w/ 100 % increase in cuttings.;Confinue circ. and rotating and reciprocating full std and weight up V 9.5+ ppg @ 550 gpm @ 3050 psi and 150 RPM.;POOH on double and on elevators. Work thru tight spots 13,945' wipe X2 , 13865'-13865' wipe x3,13,558- 13628'wipe twice 13,618'- 13,60T wipe once @ 12152 unable pass. Kelly up & and work thru pack-off while staging up pump rate. POOH hole on elevators V tight 10,606- 10 576';and 10,438'V 10,431 up. Stage up pump rate and GPM. Rotate and reciprocate full stand. Circulate bottoms up. Shakers loaded up w/ super fines. Build and pump tandem sweeps coming back on time with no increase in cuttings.;POOH from 10,430'to 9615'. Had to back ream through coal 10,180' to 10,140' due to 100 K over pulls.;Slip and cut 153' of drill line. Service rig. Monitor well and establish static loss rate of < 1 BPH.;Calibrate block height. Pump dry job. POOH with BHA#6. Begin pulling sources.;Daily fluid loss down hole: 35 bbls. Total fluid loss down hole: 93 bbls Distance to plan: OA = 200 psi IA = 15 psi 10/19/2018 Work BHA #6. Pull source. Download MWD. Break bit. No wear and in gauge. Plan to RR same bit.;Wait on weather (high winds unable load directional tools at dock ). Monitor well on trip tank w/ no losses. Set wear ring. Change out drillers rig watch screen Replace hose on ST-80. Work on drillers camera monitor switch. Shut do trip tank and monitor losses w/ static hole static hole w/just;seepage losses. Service TDS, Block, DWK. and house cleaning.;Offload work boat.;Pick up BHA #7 directional drilling assembly. Upload MWD. Shallow hole test.;RIH with BHA #7 to 5230'. Circulate and warm mud.;Daily fluid loss down hole: 19 bbls. Total fluid loss down hole: 112 bbls Distance to plan: OA = 200 psi IA = 15 psi 10/2012018 Continue circulate and warm mud.;Resume RIH with BHA #7 from 5330'to 9,646' just above window.;Kelly up fill pipe break circulation and adjust service loop while circulating bottoms/up warming mud.;Exit window with no issues RICH on elevators V 10,211'.;Unable pass W/ up to 50k down weight. Kelly up and unable to wash past ( packing -off ). Ream stage up pump rote and work thru pack off issues f/ 10,211' V 10,309.;Continue RIH on elevators f/ 10,309 V 12,620' taking down weight. Work once and continue V 12,764'. Fill pipe brk circ. Wash do full std V 12, 858'. Continue RIOH on elevators V 14,182'. Kelly up fill pipe stage up to drilling rate while reaming to bottom @ 14252'.;Directional drill 8 112" hole f/ 14,252' V 14„550'. PUW/SOW/ROT,315,220,231, 550 GPM2950 psi, 150, RPM. 15 to 16 k TQ. WOB 15 -22k, MW 9.6, ECD 10.8. Max gas 58 units, Avg ROP 33.1 FPH.;Pump tandem sweeps @ 14,398' while drilling. Sweeps back 45 bbls late with 50% increase in cuttings.;Directional drill 8 1/2” hole f/ 14,550' V 14,.750'. PUW/SOW/ROT,315,190228, 550 GPM/2950 psi, 150, RPM. 15 to 16 k TQ, WOB 15 -22k, MW 9.6, ECD 10.7. Max gas 24 units, Avg ROP 33.3 FPH. Pump tandem sweeps @ 14,660' while drilling. Sweeps back 45 bli late with 50% increase in cutfings.;Daily fluid loss down hole: 11 bbls. Total fluid loss down hole: 123 bbls Distance to plan: 0.47 Below, 4.98 Left OA = 200 psi [A= 15 psi Metals: daily = 416s, total = 570 lbs. 10/2112018 Directional drill 81/2" hole f/ 14,750' U 14,782. PUW/SOWIROT,315,195,225, 550 GPM/2950 psi, 150, RPM. 15 to 16 k TO, WOB 15 -22k, MW 9.6, ECD 10.7. Max gas 23 units, Avg ROP 32 FPH. ;Observed gradual 120 psi drop in pump pressure while drilling and Verified against Mwd turbine rpms shut do rotary std back std and test surface equipment (ok).;Pump out at 8 BPM 1100 psi. Work through pack off issues and had back ream f/ 13,492'- 13,425'. Able to work through with up to 70k over pulls and just washing with no pack offs U f/ 13,400' 13,383' The rest way to shoe just had some 30k bobbles and no packoffs.;Pump through window and into casing w/ no issues. Continue pumping out of hole looking for washout. Located washout at 4685in slip area. Photos in o-drive. This would place washout at 10,09T in open hole. Change out joint. Test MWD. Clean rig floor.;RIH with BHA #7 from 4686 to above window at 9640'.;Circulate and warm mud. Check MWD.;RIOH with BHA #7 on on elevators to 10,070'. Wash and ream to 10,115'. Continue RIOH on elevators to 13,950'. Wash and ream as needed from 13,950'to 14,750'.;Daily fluid loss down hole: 12 bbls. Total fluid loss down hole: 135 bbis Distance to plan: 0.47 Below, 4.98 Left OA = 200 psi IA = 15 psi 10/22/2018 Continue ream to bottom and stage up pump rale. Well unloading cuttings. Screen down to get to drilling rate f/ 14,722'to 14,782'.;Directional drill 812" hole f/ 14,782' U 14,978'. PUW/SOW/ROT,315,192,230, 530 GPM/3000 psi, 175, RPM. 15 to 16 k TO, WOB 15 -22k, MW 9.6, ECD 10.8. Max gas 20 units, Avg ROP 21.8 FPH. Pump tandem sweeps @ 14,855' while drilling. Sweeps back 50 bbls late with 125% increase in cuttings.;Pump tandem sweeps @ 14,950' while drilling. Sweeps back 55 bbis late with 150 % increase in cuttings.;Directional drill 812" hole f/ 14,978't(15,180' PUW/SOW/ROT,315,195,225, 550 GPM/2950 psi, 175, RPM. 15 to 16 k TO, WOB 15 -22k, MW 9.6, ECD 10.8. Max gas 23 units, Avg ROP 33.7 FPH. Pump tandem sweeps @ 15,050' while drilling. Sweeps back 60 bbls late with 125% increase in cuttings.;Pump tandem sweeps @ 15,140' while drilling. Sweeps back 65 bbls late with 75% increase in cuttings.;Directional drill 8 112" hole f/ 15,180' /15,340' PUW/SOW/ROT,315,195,225, 550 GPM/2950 psi, 175, RPM. 15 to 16 k TO, WOB 15 -22k, MW 9.6, ECD 10.8. Max gas 30 units, Avg ROP 26.7 FPH. Pump tandem sweeps @ 15,230' while drilling. Sweeps back 75 bbls late with 125% increase in cultings.;Directional drill 8 1/2" hole f/ 15,340' t/15,535' PUW/SOW/ROT,315,195,225, 550 GPM/2950 psi, 175, RPM. 15 to 16 k TO. WOB 15 -22k, MW 9.6, ECD 10.8. Max gas 32 units , Avg ROP 32.5 FPH. Pump tandem sweeps @ 15,230' while drilling. Sweeps back 75 bbls late with 125% increase in cuttings.;Pump tandem sweeps @ 15,321' while drilling. Sweeps back 81 bbls late with 75% increase in cuttings. Pump tandem sweeps @ 15,420' while drilling. Sweeps back 81 bbis late with 100% increase in cuftings.;Daily fluid loss down hole: 13 bbls. Total fluid loss down hole: 148 bbis Distance to plan: 10.2 Above, 3.66 Left (we have a revised Geological plan as per GEO ) OA = 200 psi IA = 15 psi Metals: daily =10 lbs. total =580 lbs. 10232018 Directional drill 8 1/2" hole f/ 15,535' /15,563' PUW/SOW/ROT,317,190,230, 533 GPM/2950 psi, 175, RPM. 15 to 16 k TQ, WOB 12k, MW 9.6, ECD 10.8, Max gas 20 units, Avg ROP 32.0 FPH. Pump tandem sweeps @ 15,518' while drilling. Sweeps back 75 blas late with 125% increase in cuttings.;As soon as sweeps cleaned up POOH f/ 15, 583' t/ 14,567' back reaming at max rate (530 GPM wl no pack off issues. Started off 175 RPM had slow due to tools taking hits and torque stalls). RIH to btm @ 15,583' pumping at 530 gpm and reaming 100-160 rpm attempting to keep tool hit down ;Directional drill 8 12" hole It 15,583' 1/15,795' PUW/SOWIROT,315,195,220, 550 GPM/3000 psi, 170, RPM. 15 to 16 k TO, WOB 15 -22k, MW 9.6, ECD 10.8. Max gas 32 units , Avg ROP 32.6 FPH. Pump tandem sweeps @ 15,610' while drilling. Sweeps back 85 bbls late with 150% increase in cuttings.;Directional drill 8 1/2" hole f/ 15,795' 1/15,976' PUW/SOW/ROT,320,185,226, 533 GPM/3020 psi, 170, RPM. 15 to 16 k TO, WOB 15 -22k, MW 9.6, ECD 10.9. Max gas 61 units, Avg ROP 30.2 FPH. Pump tandem sweeps @ 15,710' while drilling. Sweeps back 85 blas late with 75% increase in cut ings.;Pump tandem sweeps @ 15,892' while drilling. Sweeps back 110 bbls late with 75% increase in cuttings.;Directionaa drill 8 1/2" hole f/ 15,9761/16,080' PUW/SOW/ROT,320,185,226, 533 GPM/3020 psi,170, RPM. 15 to 16 k TO, WOB 15 -22k, MW 9.6, ECD 10.9. Max gas 35 units, Avg ROP 18.9 FPH.;Troubleshoot MWD sync issues. Working stuck pipe at 15,998'. Circulating at full drilling rate.;Daily fluid loss down hole: 30 blas. Total fluid loss down hole: 178 bbis Distance to plan: 10.2 Above, 3.66 Left (we have a revised Geological plan as per GEO ) OA = 200 psi IA = 15 psi Metals: daily= 19 lbs. total = 599 lbs. 1024/2018 Troubleshoot MWD sync issues. Got MWD working again,;Directional drill 8 1/2" hole f/ 16,080' /16,228' PUW/SOW/ROT,316,185,226, 531 GPMI3070 psi, 150 to 175 RPM. 15 to 18 k TQ, WOB 10 k, MW 9.6, ECD 10.9. Max gas 36 units , Avg ROP 26.9 FPH. Pump tandem sweeps @ 16,124' while drilling. Sweeps back 95 bbis late with 100% increase in cuttings.;Started down linking to close the blades on the rotary steerable before backreaming on the connection.;Directional drill 81/2" hole V 16,228't/1 6,342' PUW/SOW/ROT,318,185,226, 531 GPM/3070 psi, 150 to 175 RPM. 15 k TO, WOB 10 / 20 k, MW 9.6, ECD 10.9. Max gas 58 units, Avg ROP 32.5 FPH. Pump tandem sweeps @ 16,270' while drilling. Sweeps back 105 bbls late with 75% increase in cuttings.;Started having issues with MWD signal again. Work pipe and cycle pumps. Got signal back but would seem to loose it again when we run higher WOB.;Directional drill 812" hole f/ 16,342' /16,364' PUW/SOW/ROT,318,185,226, 530 GPW3050 psi, 145 to 155 RPM. 15 to 18 k TO, WOB 12 to 20 k, MW 9.6, ECD 10.8. Max gas 40 units, Avg ROP 14.6 FPH. Having issues with tool failures. Tools would comeback on when" cycled the mud pumps.;Short trip back reaming at 100 RPM, 18k TO, 530 GPM, and 3000 psi f/ 16,364' to 15,420'. Had numerous torque stalls 15,850' to 15,420' but able to work through. No pack-off issues.;Pump tandem sweeps @ 15,420' while while rotating at 100 RPM and reciprocating pipe. 530 GPM/3000 psi. Sweeps back 100 bbis late with 75% increase in cuttings.;RIH on elevators without issue to 16,270'. Wash and ream last stand down to 16.364' at drilling rate. Had minor set downs at 15,970' and 16,070'.;Directional drill 812" hole / 16,364' /16,465' PUW/SOW/ROT,318,185,226, 530 GPM/3050 psi, 145 to 155 RPM. 15 to 18 k TQ, WOB 1610 20 k, MW 9.6, ECD 10.7. Max gas 42 units, Avg ROP 15.4 FPH. Pump tandem sweeps @ 16,365' while drilling. Sweeps back 100 bbls late, 100% increase in cuttings.;Daily fluid loss down hole: 69 bbis. Total fluid loss down hole: 247 bbis Distance to plan: 2.6 Below, 2.97 Left at 16,335'. OA = 200 psi IA = 30 psi Metals: daily =7lbs. total = 606 lbs. 10/25/2018 Directional drill 81/2" hole 1/16,46606,490' PUW/SOW/ROT,318,185,230, 530 GPM/3050 psi, 140 to 155 RPM. 15 to 18 k TO, WOB 8 to 13 k, MW 9.6, ECD 10.7. Max gas 28 units , Avg ROP 25 FPH.;Lost sync on MWD tools. Couldn't gel the tools to sync back up. Discussed with town and decided to call this TD. Work pipe and circ tandem sweep around. Sweep came back 115 bbls late w/ a 175 % increase in cuftings.;POH backreaming f/ 116,490t/ 13,650' at 150 RPM, 530 GPM, and a starting pressure of 3000 psi. Had to break back a few spots where it torqued and stalled at 15,380, 15,029, 14,295', 14,284', & 13,722'. At 14,044' it packed of and hung up. Worked free and had to backream;slow with a reduced pump rate to about 14,020' before we got through where it wasn't trying to packoff again.;Continue back reaming f/13,650' 013,245'. Hung up and packed off but able to work free.;Circulate sweeps while rotating and reciprocating pipe from 13,147' to 13,242'. 150 RPM/14 K torque. 550 GPM/3000 psi. First sweep came back 55 bbls late/150% increase. Second sweep back 55 bible late/75% increase. Continue circulating until clean.;Continue BROOH from 13,147'to 11,286. 150 RPM/13.5 K torque. 540 GPM/2650 psi. Having pack off issues.;Circulate tandem sweep while working pipe from 11,349 to 11,247'.;Daily fluid loss down hole: 28 labls. Total fluid loss down hole: 271 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi IA = 30 psi Metals: daily= 17 lbs. total= 623 lbs. 10!262018 Circulate tandem sweep while working pipe from 11,340' to 11,290'. Sweep came back 5 bbls late w/ a 50% increase in cuttings.;Had to work through a tight spot at 11,288 without rotation. Pulled 60k over to work through. Then went back down through tight area and backreamed up through it to clean it up.;Continue backreaming out of the hole. Stopping rotation when spiral torque stbs, and BHA came through window. (150 RPM, 550 GPM, 2500 psi.];Pump tandem sweep and circ csg clean keeping pipe moving. Getting a lot of small chunks of coal back when we 1 st started circ. Sweep came back on time w/ 25% increase in cuftings.;Monitor well. static. Pump dry job. Install extra safety cable on TO service loop while monitoring well, due to damage noticed in main hanging cable.;POH to BHA Laying down and getting gauge off spiral torque subs to check them for wear. Wear on subs ranged from 114" to 1 112" out of gauge.;Lay down BHA V. Remove nuclear sources. Down load MWD. Clear and clean rig floor.;Pick up BHA #8 clean out assembly.;RIH with BHA #8 to 4800'. Change out joints of DP with worn hard band as necessary. Installing Spiro Torques as per pipe tally.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 271 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,499. OA = 200 psi IA = 35 psi Metals: daily = 7lbs. total = 630 lbs. 1027/2018 RIH with BHA #8 to 9572'. Change out joints of DP with worn hard bands. Also inspecting and changing out bad W WT rotating rubbers. Installing Spiro Torques as per pipe tally.;Circ to shear mud while cutting drilling line. Change out bad bolt on derrick climber counter wt sheave. Service rig.;RIH inspecting and changing out bad rotating rubbers . Set down at 9896 and had to wash and ream through coal to 9900'. Run in to 9965' and had to wash and ream to 10,200' where we lost our washpipe packing. Run in hole to 10236 w/ no pump.;Break out TO and RU head pin to circ. Started circ and union on top of cmt hose started leaking. Shut do pump and tighten union. Circ at 4 BPM & 500 psi while changing washpipe. Change out washpipe and test.;RIH to 10, 360' and set down. Wash and ream to 10,710'. when we 1 at started washing we were getting a lot of coal and cutting back, then it tapered off. RIH with 2 side on elevators and attempted to run 3rd stand but we sat down at 10,903'. Brought on pump and rotary but we packed off.;Work pipe back up 10,898' and stand back a stand. Still had pipe movement but no circulation. Continue BROOH from 10,898' to 10,252' without circulation due to pack-off issues. 75 RPM/15-22 K torque. Attempted to circulate every 30' pulled.;Began circulation at 10 252'. Slowly stage pump rate up to 540 GPM/2100 psi. Rotate and reciprocate at 150 RPM/13 K torque while working full stand from 10,335' to 10, 241'. Hole unloaded at bottoms up with 500% increase in cuttings. Stand back one stand.;Circulate sweep at 550 GPM/2100 psi while working full stand at 150 RPM2100 psi.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 271 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi IA = 35 psi Metals: daily =7lbs. total = 630 lbs. 10/28/2018 Circulate sweep at 550 GPM/2100 psi while working full stand f/ 10,241't] 10,146. Sweep came back 20 bbls late w/ a 50% increase in cuftings.;Backream out of hole f/ 10,146tt 9,840' at 150 RPM 560 GPM 2050 psi. Shut down rotation and pull all the spiral torque stabs and bit through the window, pumping 560 GPM and 1050 psi.;Just before bit came through the window we started getting silver dollar size chunks of coal over the shakers 3" deep. About a 500% increase. This continued for about 50 bbls. Pumped sweep and it came back on time with a 25% increase in cuttings.;Monitor well and it was static. Pump dry job.;POOH to bit, laying down spiral torque stabs.;Pull wear ring. Flush stack. Change out saver sub. Service rig. Inspect top drive.;RIH with BHA #9 clean out assembly to 4469.;RIH with BHA #9 clean out assembly to 9566'.;Drain stack. Blow down lines. Makeup test joint and test plug. Land string on test plug.;Test BOPE. Annular preventer at 2500 H/250 L. All other at 3500 H/250 L. AOGCC (Jim Regg) waived witness on 10-28 at 17:30 hrs.;Daily fluid lass down hole: 0 bbls. Total fluid loss down hole: 271 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi IA = 35 psi Metals: daily= 0lbs. total= 630 lbs. 10/2912018 Test BOPE. Test All BOP equip at 3500 H250 L. AOGCC (Jim Regg) waived witness on 10-28 at 17:30 hrs. Had 2 choke valves that failed. Operated and greased the valves and they passed.;RD test equip and pull test plug with drill string to the rig floor. LD test plug.;Circ and condition mud. Keep increasing rate as mud shears to get backup to drilling rate. Got rate up to 500 gpm.; Wash in hole f/ top of window at 9670' t/ 11,061'. Had to rotate through small coal at 10,084'. Pumping 550 GPM at 2200 PsI.;Wash in hole H 11,061't/12,020'. Encountered pack-offs.;Wash and ream from 12,020'to 12,110' at 75 RPM/12 K torque. 550 GPM2250 psi. Circulate cleanup cycle bringing back 50 % excess cuftings.;Wash in hole f/ 12,110't/15,760'. 550 GPM2300 - 2850 psi. Rotate through 13,450'to 13,500' and 14,640' - 14,660' at 75 RPM113 K torque.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 271 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,499. OA = 200 psi IA = 35 psi Metals: daily =0Its. total =6301bs. 10/30/2018 Wash and ream in hole f/ 15,760't/ TD at 16,490'. 550 GPM/2300 - 2850 psi. 125 RPM/16 K torque. Had to wash the last 300' in at reduced pump rate due to packoff issues. 390 GPM, 1700 Psi, 150 RPM, 16k TO. Pumped sweep at 16,182'. Came back 150 bbls late w/ 10% increase in fine cuftings.;W ork last 25 on the bottom of a stand a couple times and stand the stand back.;Pump tandum sweeps and circ, attempting to stage up flow rate from 390 gpm, 1700 psi, 150 RPM. Working pipe between 16,464' V 16,371'. Having a lot of packoff issues backreaming.;Continue to work pipe stage pumps V 500 gpm 2550 psi 150 rpm Tandem sweep return 135 bbls late with 50% increase in cuftings.;Attempt to POOH on elevators unable pulling 70-8Ok over not breaking free, Attempt to POOH w/ pumps packing off and pulling fight, Begin BROOH w/ 150 RPM 500 gpm V 16464'tt 16275packing off stalling top drive.;Work tight hole packing off and stalling out lower flow rate V 170 gpm 675 psi 150 rpm pulling slow not packing off as much f/ 16275'V 15875'.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 271 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi IA = 40 psi Metals: daily = O lbs. total = 630 lbs. 10/31/2018 Backreaming out of the hole f/15,875 V15,859. Pulling at a reduced rate due to packoffs. Every time we bring the pump rate up to even 3 BPM it would packoff. Got hung up several times and had to break it loose by bleeding pressure off, putting pipe at rotating wt, rotating and lowering pipe fast.;Put 4 bbls of lube in suction pit and continue reaming until lube went out bit. After lube came out of bit everything started getting better. We were able to work the full std f/ 15,800 t/ 15,898' with 16k TO, 160 RPM, 500 GPM, 2,450 psi. Put another 4 bbls lube in suction at 12:30 hrs.;Pump tandem sweep while working the hole stand. 544 GPM, 2815 Psi 16k TO, 160 RPM. Started getting about 100% increase in fine sand 200 bbls before sweep came back. Sweep came back 120 bbls late w/ 150 % increase in cuttings. Circ unfit it cleaned up.;POH 3 more stds on elevators to 15,613'to complete short trip, Pulled good. RIH on elevators back to bottom at 16,490'. Had set downs at 15,643', 16003', 16,205'. PU and went through when we went back down.;Get circ rate up to 544 GPM, 2890 Psi, 160 RPM, 17k TO. Pump another tandum sweep while working the pipe from 16,395' to 16,490'.;Continue rotating and reciprocating pipe while pumping sweep around, 180 bbls late w/ 50% increase in cuttings, continue circulating another bottoms up until clean, spot 200 bbl lube pill outside the pipe.;POOH on elevators 1116490' t/ 13550' observe over pulls start about 14500' but able to work through. unable to work past 13550' pulling 100k over and not breaking free, unable to slack off taking 60- 80k down weight and not breaking free, 15' free pipe movement.;Stage pumps up slowly t/ 540 gpm 160 rpm able to work full stand after pump rate was above 350 gpm, pump tandem sweep hole unloaded 3 times good amount of fines over shakers, 150% increase in cuttings on sweep return, shakers cleaned up.;POOH on elevators V 13550't/ 10120' work throught fight spots @ 10212' 10180' 10150'.;Work through tight spotV 10120't/10065' over pulling look multiple times.;Continue POOH t/ 9645' No issues pulling through window, Establish circ 540 gpm 1980 psi.;Daily fluid loss down hole: 5 bbls. Total fluid loss down hole: 276 bbls Distanceto plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi IA= 45 psi Metals: daily =3lbs. total =633 Iles. 11/1/2018 Pump tandum sweep up in window. Sweep camp back on lime w/ a 10% increase in fines. Pump dry job.;POH Laying on 8 jts of HWDP and the jars. POH to 5038'.;Conlinue POH to last std of DP. Top jt of stand was bent about in the middle. Layed on all jts. Break out spiral torque stbs and bit. Bit was in gage. The spiral stbs wore f/ 7.80 to 7.72, 7.75 to 7.68, 7.20 to 7.03, & 7.15 to 6.95.;Clean and clear floor of tools. Install new hanging line on service loop.;Start to PU BHA for retrieving whipstock. MU hook on jt of HWDP, PU MWD.;Continue M/U Whipstock retrieval tool, upload MWD, shallow test tools, RIH V 1042' ;RIH f/ 1042' U 9616filling pipe every 3000'.;Establish circulation 400 gpm 2500 psi orient tool assembly wash down clean hook slot, P/U Orient 180° to hook whipstock, slack off U 9678' take 5k wt, P/U slowly over pull t/ 50k over observe wt falling off, continue PIU pulling 75k drag weight fell off extra 1 Ok PUW.;POOH w/ whipstock f/ 9678't/ 6266'w/ 1 O extra PUW pulling slow with minimal downward movement.;Daily fluid loss down hole: 5 bbls. Total fluid loss down hole: 276 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi IA = 37 psi Metals: daily =3lbs. total = 633 lbs. 11/2/2018 Continue to POH w/ whipstock with no downward motion.;Clean and LD magnets and Jars. Pull whipstock to rig floor and run holding pin through it. Set it do on the table and release the hook. Lay do hook on jt of HWDP. Install whipstock picking assembly on and pull whipstock out of the hole. Start to LD tools that were below and blew a seal on the TD.;Driller had put wt do on the elevators trying to close unloader and that blew the seals on the Rotating Link Adaptor. Attempt to trouble shoot. Call NOV techs and discuss problem.;Break down and LO tools using air tuggers. Magnet was packed off completely, Debri cup had failed and cuttings had fallen by it so tools had a lot of cuttings on them. recovered 135 Iles of metal off the magnets. Most the metal was from the magnet below the whipstock.;Plug lines to check out which seals are blown. looks like all the seals are blown on the RLA. Have NOV tech arrived on platform a 1730 hrs to assisL;Continue NOV inspection of top drive, don't have the parts on location to fix top drive Ieak.;M/U Baker Clean Out BHA.;Trip in the hole V 62V t/ 9706.;Wash down 400gpm V 9705' V 9803' tag up set 4k down not washing off, discuss options, set down 15k not washing off no increase in pump pressure, wash up V 9700'.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 276 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi IA = 40 psi 11/32018 Circ bottom up at 9608' and never did see anything come back over the shakers. Pump dryjob.;POH w/ original wellbore clean out assem to jars.;Lay do BHA, LD jars. Clean and LD magnet. LD 4 jts of 3 112 DP, bit sub, both boot baskets, and 6" bit. Got about i Ib of metal off magnet, and fines and coal out of boot baskets.;PU jt of HWDP w/ hook assem and break off hook. LD same. clear floor effects and get it all cleaned up in prep for TD work.;Work on pulling pipe handler off TD. Pulling TO apart to install new seals in the Rotating Link Adaptor.;New seals on platform @ 2000 hrs, found cracked piston ring on RLA assembly, mobilize out of anchorage, dress new seals on RLA.;Wait on Piston ring from anchorage, general housekeeping, clean floor, mix mud, piston ring on platform @ 0130 hrs, Day light savings time gain an extra hour, install piston ring on RLA assembly, install RLA seals and put back together, M/U RLA to top drive, torque and wire tie RLA Assembly.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 276 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi [A= 15 psi 11/4/2018 Finish getting TO put back together. Fill TD w/ gear and hyd oil. Test all TO functions and everything tested good. Finish putting tie wire on all the bolts.;Clean up rig floor and make sure everything used to work on the TO was put away.;PU Ram diverter assem. PU Ram anchor, XO, Tieback seal assem, XO, 3 5 1/2 pups, Seal bore diverter, Running tool, Float sub, MWD, Fitter sub, and 15 jts HWDP. Scribe MWD to anchor. Test MWD. Whipstock will be at 20° right.;RIH wl HWDP and continue RIH w/ DP at 907min to 5800' filling pipe every 3000'.;Continue RIH w/ Ram Diverter Assy. f/ 5800' V 9664'.;Obtain par stage pumps up t/ 1150 psi unable to get pump it high enough to get tool face, orient on locator lug, pull up and verify latch w/ 50k overpull, pressure up V 1500 psi release from Ram Diverter, Establish Circ, get flow rate up U 375 gpm orientation 20" R, Spot hi vis weighted pill.;Slip and cut drilling line 119' service rig.;Drop 2.40 drift POOH f/ 9600' V 576'.;L/D HWDP and BHA Down load MWD.;Daily Fluid loss down hole: 0 bbls. Total fluid loss down hole: 276 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi IA = 35 psi Metals: daily = 0 lbs. total = 633 lbs. 11/5/2018 Finish laying do BHA and clear floor.;Flush stack and then drain stack. Set test plug and change upper rams to T'. RU to test. Test upper rams and annular on T' to 250 low and 3500 psi high. RD test equip.;RU to run 7" liner. Have PJSM w/ everyone involved. MU shoe track and check floats. RIH PU 7" liner V 2900'.;Confinue RIH f/ 7" liner as per Detail U 6741' M/U Liner hanger.;WU Liner hanger as per baker rep.;Circulate pipe volume stage pumps up U 800 psi, Rabbit pipe.;Confinue RIH w/ 7" Liner on 5" DP fl 6824't/ 9663'.;Circulate and condition mud stage pumps U 385 gpm 1200 psi.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 276 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi IA = 35 psi 11/6/2018 Circ and condition mud just above window at 9663'. Get mud sheared and get parameters. 20 RPM=10.5 TO, 30 RPM=10.5 TO, 40 RPM=10.5 TO. Up wt -250, On wt --205, Rt Wt --220. Took parameters at 90 GPM 8 400 Psi. Cir at 405 GPM 1300 psi. Fill csg w/ mud containing new 2% Iube.;Run into open hole with 7" liner. Went right through window with no issues. Tagged up on coal at 991 0'and had to work through several coals to 10,131'. RIH to 10,242' we we sat down.;Wash and ream through tight spot f/ 10,242 V 10, 257', packing off taking weight work through coals with rotary and pumps vary pump rate 2-4 bpm 400- 800 psi 20-40 rpm ;Wash and ream f/ 10257't/ 11310' taking wt packing off 40 RPM 260 gpm 900 psi.;Wash and ream f/ 11310' t/ 11386 working pipe packing off stalling out, pump lube pill and nut plug pill no change in hole conditions, set down 85k work string vary parameters 2-8 bpm 250-1200 psi 40 rpm, Broke through.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 276 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi �1i A = 34 psi Metals: daily =0lbs. total =6331bs.;Daily Fluid loss down hole:0 bbls. I Total Fluid loss down hole: 276 bbls S Distance to plan: 13.64 Below, 3.23 Left at 16,490'. (9 OA = 200 psi IA=34 psi l 11/7/2018 Continue working, washing and reaming 7" liner through tight hole f/ 11, 414't/ 11,466' up wt dry = 320k, do wt = 200k, and rot wt= 230k . 40 rpm @ 17k and 2-7 bpm 450-850 psi.;At this point we lost circ. (appears pipe is plugged) Pooh wet and into csg with no issues f/ 11,466' V 9570' ( also we managed to drop 1-3/4" OD X 48" long DP wiper rubber in hole w/ brass rings on each end ).;Clean floor from wet trip pull bushings clean out flow box looking for drop wiper rubber w/ no Iuck.;Confinue pooh wet w/ 7" liner racking back 5" dip U 9570' V 6743'.;R/U Weatherford tongs and handling equipment.;Break off 7" hanger and stand back.;POOH L/D T' liner f/ 6743' V 2137'.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 276 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi IA = 36 psi Metals: daily =0lbs. total =633 lbs. 11/8/2018 Continue POOH wet L/D T' 29#DWC/C-SC liner f/213TV 118' (found Jt#3 had twisted off leaving 18.29' ofjt#3 + pup + LC + Pup + jt + FC+jt+FC+ shoe = 118.64' in hole ) also noticed that there might be some Spiro welded pipe in mix . see photos in "O" dlnve.;Cold cut btm +- foot of 7" twisted off csg and clear and clean pipe of fill obstruction and OBM. Clear and clean floor from wet trip and csg handling equipment. Discuss options with town and chase plan fwd.;Drain stack found lost stripping rubber intact removed from well, Set test plug, RAJ and change top rams to 3.5 x 6 VBR, R/U and test upper rams and annular t/ 250/3500 psi f/ 5 min each w/ 3.5" and 5" test jts, R/D test equipment.;M/U retrieval BHA as per baker RIH.;RIH w/ BHA on 5" DP V 957T.;Obtain parameters PUW 245 SOW202 Rot 220 2 bpm 370 psi slack off V 9671' locate on diverter assy. set down 40k, over pull 501k verify engaged slack off 40k, over pull 140k to release from latch PLAN 255k, LID pup jts.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 276 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi IA = 36 psi Metals: daily =0lbs. total =633 lbs. 11/9/2018 Continue pooh w/ diverter racking back dp f/ 9665' V surface.;inspect retrieved diverter ok and I/dn blue as per BOT hand ;Clean rig floor, while waiting on crane repair and loading T' on boat , Service rig grease traveling equipment, clean out mouse hole, chg out suction side expansion jt on trip tank #1, chg out hose on at- 80.;RIH w/ 10 stands of OF, L/D 48 stands of 5" DP.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 276 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi IA = 34 psi 11/10/2018 Continue Udn slick extra 5" dp out of derrick w/ MT stack cleaning ID and OD of pipe total I/dn 195jts Continue centrifuging back first batch of 225 bbls OBM f/9.7 V9.0 ppg first pass.;Pooh rack back 10 std 5" slick dip total 5" std in derrick= 114 continue centrifuging back first batch of OSM . Mobe csg/tbg tongs to rig floor. Start Load out Load out 5" dip on boat #1 . Service rig while waiting on crane to work boats.;Finish loading 5" on boat #1 , bring in and off load Boat #2 of 3-1/2" tbg number and strap same. Drain and vac out one rain for rent tank and prep for boat. Continue rig maintenance while waiting on crane to finish working boats. inspect TDS chg out link tilt stop bolt, chg/out and;install new flow meter for dwk spear. R/up Wotco Csg /tbg handing equipment Udn 7" hanger and pups.;R/U Weatherford tongs and RIH 3.5" tubing t 1439' , Rack back 10 stands in derrick V 500', continue RIH w/ 3.5" tubing @ 2979.;Daily fluid loss down hole: 0 bbls. Total fluid Ions down hole: 276 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi IA = 35 psi 11/112018 Continue P/up rabbit and tally rih w/ 3.5" 9.2# L-80 IBT f/ 2970' V 9200' Up/dn = 130k morning tide unable to load boats do to weather, next tide attempt @ 1600 hrs.;Circ and warm mud w/ max coal gas of 105 units 1600 hr call out pushed V 1800 him then called off @ 1700 hrs.;Pooh rack back tbg f/ 9200' V Surface, w/ total 108 stands or 10,138' in derrick , r/dn mud loggers shack, centrifuged back first batch of obm as far as we can now waiting on ISO tanks.;Pull wear ring set test plug Vup test equipment test bope as per regulations 250U3500H psi on 3-12" and 5" test jt witness waived by Mr. Regg w/ AOGCC (broke mud line removed Baker sensors and retested mud line 250-3500 psi ok) chase leak on choke manual grease zert retest good.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 276 bbls Distance to plan: 13.64 Below, 3.23 Left at 16,490'. OA = 200 psi IA = 35 psi 11/1 2J2018 Continue test hope as per regulations 250U3500H psi on 5" and 3-12" test jt w/ no failures other then grease zert leak on shell test. Witness waived by Mr. Regg w/ AOGCC (broke mud line removed Baker sensors and re tested mud line 250-3500 psi ok on chart ) r/dn test eq uipment.;P/u p 7" csg handling equipment. tally and strap bha while waiting on crane to finish working boat.;P/up 7" scab assy = Bot 7" seal easy w/ 3 seal packs and no-go + T' pup jt+ (3) its 7" csg and BOT ZXP prk w/ 1O'tie back extension ( had chg out one jt egged it during m/up ).;Rih w/ 7" scab assy on 5" dip out of derrick filling pipe every 3000't/ 9606'.;Obtain parameters 3 bpm 400 psi PUW 256k SOW 205k, Slack off and engage seals NOGO @ 9734, P/U to ports out 8', establish circ stage pumps V 87 bpm 1080 psi.;Change over hole to heavy diesel 7.4ppg, Pump HI Vs Spacer followed by 731 bbls Heavy diesel @ 8 bpm 1080 ICP 730 FCP.;Drop 1.5" steel ball, pump to seat, slack off 50k pressure up to 2800 psi attempt to release from liner PIU 290k not released, slack off pressure up to 3700 psi attempt to release PIU V 320k not released, continue attempting to release from Iiner.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 276 bbls OA = 200 psi IA= 35 psi Metals: daily = 0 lbs. total = 633 lbs. 11113/2018 Continue Pressure cycles. Bleed off Pressure and pressure up V 4000 psi w/ test pump and P/up V 250k observed pressure drop . finish bleeding off pressure P/u total of 6' and lack off taking weight 4' high (dogs out) and tool release set do V 145k had good indication of pkr set.;P/up and Rotate at 10 rpm @8-9k torque and rotate weight on to confirm weight transfer. observe well (dead) Go to DN wt 150k pump do dp 4.5 bbls V 900 psi observe flow and shut on and lost psi (ball set and or pack gone) p/up space out Leaving top of scab liner Tie back @ 9574.51.;line up and purge air and fluid pack testing system and shut top rams P/T 9-5/8" csg X 7" prk by pumping do dp 8 bbls V 2147 psi > 1806 psi in 30 min on chart. discuss options w/ town Bump pressure back V 2122 psi w/ 1.4 bbls > 1975 psi 30 min on chart bleed off 6.8 bbls.;Discuss results w/ town and send in charts . Udn space out pups.;Cir btm up @ 8 bpm @ 480 psi wl max gas of 31 unit above back ground.;Pooh racking back 5" dip 1119554' V 8629' (Pipe pulling dry, but back side flowing ) monitor well, flowing out of back side @ 3.3 BPH and .8 bbl under cal displacement (crew change).;Confinue pooh more 10 std V 7643' to see if pipe was u-tubing , well still flowing back @ 3.3 bph and over 1 bbl under cal displacement. Rih 20 std V 9600' and still flowing back as same rate.;Took 12 bbls to fill pipe and brk circulation, Circ STS @ 8 BPM @ 600 psi and chk mud weight both ways. mud weight varied 117.4 - 7.9 ppg @ 375 bbls in to circ had brief balance 7.6 ppg in and out and +- 100 bbls before btm/up got high gas of 105 units above back ground.;Find and shut do at slight heavy in DP u-tube . Monitor well w/ slight out balance wl dp heavy.;Pooh f/ 9600' V 8113' starting come wet.;Monitor well slight out balance w/ DP light Pump dryjob Finish pooh V Bha w/ 16 bbis over cal displacement.;lnspect and Von ZXP running tool (dogs marked and pack off rubber gone ).;P/up WOTCO Packer retrieving BHA monitor well on trip tank noticed. 1.7 bbl gain in one hr shut blinds V m/up PRT. Monitor for pressure buildup and crew change.;Pressure built U 90 psi in 30 min , Notify drilling manager and discuss situation while r/up Hose to fill gas buster. Fill same w. 8 this w/ SICP @ 264 psi. Open choke and pressure bled right off w/ no gain, just slight flow @ 2.1 bph starting rate. Monitor rate every 5 min.;For trend for 45 min w/ startof 2.1 BPH flow and high of 9.2 BPH w/ total 2.bbl gain. Discuss situation w/ town.;Finish m/up PRT BHA. RIH w/ BHA to 1340'. Fill pipe (8 bbls to fill). Circulate bottoms up. Continue RIH to 4200' filling pipe every 10 stands.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 276 bbls OA = 200 psi IA = 35 psi Metals: daily =0lbs. total = 633 lbs. 11/14/2018 Continue RIH with WOTCO PRT BHA from 4200'to 9490' . Fill pipe every 10 stands. and 8.5 bbls under calculated displance for trip. up wt 264k & do wt 210k.;Wash down 9490' 119585 (did not see TOL scab) P/up above TOL 9570' and rotate and reciprocate 50 rpm 5-9 k circ STS @ 8 bpm 990 psi chking mud weight in and out . We had 7.7 ppg to 7.7+ ppg going in through out circ. 7.6 ppg V 7.8+ coming out & 127 units gas above back ground.;At 83 bbls into circ.;Shul do pump monitor static well and service rig, grease wash pipe and rig Clean floor of hose for filling gas buster vac out 2nd rain for rent tank . just under one hour well started flow just pencil lead stream (4 min fill vis cup).;Wash in hole f/ 9570' U tag of 9791' (did not see TOL scab) @ 8 bpm @ 990 psi Up/dn/ 260k/ 210 wash on 4' at a time through fill and plup chking for latch V 9835' (thats with in one foot of original set depth ) unable make fwd progress attempt rotate 30 rpm @ 8-91k free torque off.;btm and 11-12k on btm @ 9 BPM @ 1220 psi.;Call and discuss high torque concerns various parameters and attempt to mill packer. Unable to engage packer.;Monitor well while discussing plan twd with town . Well started flowing less than 1 BPH. Circulate bottoms up at 8 BPM/1000 psi with high gas of 65 units (BGG 40 units). Monitor well with <1 BPH flow rate. 7.6 ppg in/out.;POOH with PRT assembly. Calculated fill: 81.7 bbls, actual fill: 94.9 bbls. Recovered 10 lbs metal out of boot baskets and magnets. Mill slightly wom indicating we were on packer. Consult with engineer. Photos in o-drive. Well was static while working BHA.;Make up re-run BHA (PRT assembly) and pick up additional drill collar. RIH to 4000'.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 276 bbls OA = 200 psi IA = 35 psi Metals: daily =13 lbs. total =646 lbs. 11/15/2018 Continue RIH with WOTCO RR -PRT BHA from 4698'to 9520'. filling pipe every 10 std and 4.2 bbis over cal displacement for trip up /on 264/ 210k.;Slip and cut drlg line 128' while circ 3 bpm @ 165 psi and monitoring well w/ no gas and even MW 7.6 ppg and no gain or loss & Even ES. Service rig and tighten SS line on TDS to fix a hyd Ieak.;Continue Circ and up circ rate f/ 3 bpm V 8 bpm @ 980 psi and finish btm/up w/ no gas spikes or uneven MW or out line ES.;Confinue RIH ff 9520' V 9770' and did not see TOL Kelly up Obtain parameters up @ 264k, do @ 210k, rot 220k, 80 rpm 5-1 Ok tq off 9.5 bpm @ 1350 psi wash on and observed grapple going through @ 9835' w/ 6k do wt and continued V 9838' w/ 10k do wt p/up w/ no Iatch.;Slowed pump rate V 6 bpm and re -stab grapple w/ 20k do wt @ 9839' and p/up w/ 20k over put L;MitI on prk w/ WOTCO PRT f/ 9838' V9840' 80 rpm w/ 5-11 k on btm and 5-10k off btm TO and stage up WOB f/ 1-2k V 4-6k @ 8 bpm at 995 psi.;Continue milling on packer with various parameters including dry drilling and spudding down to 20 K. (16" actual footage after figuring WOB). Torque became steady at +-9 K. No significant gains or losses noted. Gas units averaged 55 units.;Release from packer. Circulate bottoms up at 8 BPM/1000 psi. Max gas 60 units. Flow check.;POOH with PRT to BHA. Calculated fill 81.7 bbis, actual fill 97.8 bbls.;Work BHA. Mill 80% worn. Change out mills. Recovered 16 tbs from boot baskets and magnets. Well static while out of hole.;RIH with BHA #2 PRT assembly to 1600'.;Daily fluid loss down hole: 0 bbls. Total fluid loss down hole: 276 tools OA = 200 psi IA = 35 psi Metals: daily = 25 lbs. total = 671 lbs. 11/16/2018 Continue RIH with BHA#2 PRT assembly f/ 1600' V 9809'.;Kelly up obtain Parameters wash do @ 8 bpm @ 1020 psi f/ 9809't/ 9835' slowed pump rate V 6 bpm stabbed grapple stinger through prk V 9840't/ 18k dn. P/up w/ 20k over.;Mill on prk f/ 9839 V 9840' up/dn /rot 264/ 210/ 220k @ 80-125 rpm w/ 6-11 k tq off and 6-12k tq on V 343 bpm 180-1220 psi. Well started taking fluid @ 5 BPH.;packer fell and chase it down hole 3' feet w/ no rotary . Pump out o f hole and work packer to above TOL @ 9553' w/ 20 - 50k over pulls and couple break backs and one jar bump while letting jars bleed.;Circulate bottoms up @ 8 BPM @990 psi W/ 3-6 BPH losses. No change in MW or ES or gas.;Monitor static well 1/2 hr ( well dead ).;Circulate bottoms up @ 6 BPM @ 560 psi w/ even MW. No gas. Stable ES and 7 BPH loss rate.;Flow check static. POOH gently keeping swab and surge to minimum.;Work BHA #2. No fish/packer. Clean boot baskets/magnet. Recovered 16 lbs metal. Hole fill: 84.2 actual, 81.7 calculated. Discuss options with engineer.;Make BHA # 3 (spear assembly). Monitor well out of hole: <.25 BPH loss rate.;RIH with BHA #3 (spear assembly) to 6000'.;Daily fluid loss down hole: 36 bbls. Total fluid loss down hole: 36 bbis OA = 200 psi L4 = 35 psi Metals: daily = 45 tbs. total = 716 tbs. 11/17/2018 Continue Rih w/ bha #3 (short catch spear assembly loaded w/ 4.010" grapple) f/6108' t/9515' up/dn 264/210k.;Continue RIH f/ 9515' t/10,004' saw maybe 3-5k bobble @9829' p/up 30' every std do looking for drag none seen.;Pooh f/ 10,004' starting @ 9945,9906 8k bobble and 20k @990T 2-3k drag 9866' 25k over @ 9829' and bump on to to make sure grapple fully engaged 30k@9844' and bump do keep working OOH w/ multiple over pulls in 10 k incrementst( 100k over bleeding jars at 35k over Last over;pull of 95k was observed @ 9725 continue pulling above liner V 9515'.;Flow check well. Out of balance. Heavy on backside. Drop pump out sub dart. POOH 5 stands. Kelly upon each one due to flowing out of DP V 8948'.;Shear pump out sub @ 1800 psi. Circulate bottoms up. Check for balance. Still out of balance. Circ STS. Flow check out balance on DP heavy w/ even. (Mud weight, no gas above back ground).;Finish POOH from 8948'to BHA. Recovered 11 lbs metal from magnets. Hole fill: calculated 74.1 bbis, actual 84.9 bbls.;Work BHA. Recovered packer fish. Disc was not sheared. Photos in o -drive. Clear rig floor. Lay down 4 3/4" drill collars. Monitor well: .25 BPH loss rate.;Pick up 9 5/8" casing scraper. RIH with same to 6691. Circulate STS at 8 BPM/80 psi. This is the final report on this AFE.;Daily fluid loss down hole: 38 bbis. Total fluid loss down hole: 72 bbls OA = 200 psi IA = 35 psi Metals: daily = 18 tbs. total = 734 lbs. Actual Wellpath Geographic Report - including Position Uncertainty 10,2611 Bat 09' 15 using WeIWtlntacl 51 N 27 I iM Naska SP, Zone 4(5004). US feel Hlcerp Naska, LLC True Cook Inlet, Neska (OXSXore) 0 99999) MCMM1ur River Held 1 d0 West 6TEELHEPD Fall Slat slot #212-12 pdual Datum (RKB) M -35L1 ktual Datum(RKB) M -35L1 Bale -1 M -35L1 awry 160001 10/00]2010 160.001 M-352101 awp a196]O OO MD 160.001 UncarE E 0 001 Miinum c gia 1 10.00 X Magnelic Wrth nM1 is 1638 degrees East of True NoetM1 2g p6° 2 0 se Dai nemeea wA N4c Dem Io B9 n 613]55 54594 21417291 249935635 50°4953.534"N 151°J6'Ofi 9]600 000 000 213654.96 250050690 fi0°50'04 ]J6"N 151 °3fi'1]]2]W 000 000 213649]1 1 29051408 1 60°50'04.803"N 151°]6'10.0189 Start MD End MD Residential Uncertainty Model Led Name I Comment Vanities, 000 2699,00 IGttadl9 Blarddrap g]m or Mull M-35PB1 Gym,0gN GYlo°02030> Mi 241C Son Go 0H GoT5akrp-0 (MapCID-lFRt, SIG) W35PBI-BHGE 07'K MND,-CAeMBA¢516-10559a WSPB1 9fi]000 18490.[0 OH GoTmk(Me JFR1. S)tG) - M-351.1b11GE 0MdfiYMCMMJAc96)0- - M85L1 No Inclination Avers nth TVO No. East Sim East Grid North Latitude Longmme DLS Too,mave Build Rate Tumn Rate dour Sort MajorSomi MmorSrma Vert Semi MinorAzwo C-suments 0.00 0.00 16641 G. -10000 0.00 0.00 2141891 249935635 60'495)5341951'9'06,]159 0.00 16641 0.00 000 0.00 II 0.00 000 0.00 ON 100.00 023 IN41 100.00 -4.0 _ -04 0.05 21492.95 2499358.15 60.45535321 161.36W.]13W 0.23 14108 0.23 - 16641 -0.15 015 0.15 2.30 7841 NO CC 031 1]09] 240 400 0.56 0.12 2141802 2499)55.]8-0.49'5352BN 151'9'51.6129 0.03 12251 -002 4% G.15 I. 026 0.26 - - 2.30 25750 300.000.19 18224 3'0.00 140.9 092 0.15 21417303 249WSSA3 W-49 51525N 151.36'06.711" 064 .16.14 -0G2 1127 0.73 0.35 - GM 2,30 260.59 60000 1 0.03 189.]5 399.99 23999 _IN 0.27 21417313 /49935455 W'46W516N 151.3MCSYO'W 0.65 46,75 ou .1249 - 1.41 041 039 2,30 0190 50000 0.92 14.9 499.98 31.98 3.28 082 2141]345 2499353.05 W-49'53W2N 151-WO51029 0.12 - 459.1 009 56] .2.56 070 044 - 2.31 80.87 90.00 0.3] 12324 Sf9.B0 639.9 -013 1.11 2101]391 2699)5209 9'49'536921 151'36Y1869ZW 060 -1511.01 -055 40.81 -3.16 053 Od9 2.31 ]6.51 60000.21 101.47 69.9] 5399 4.44 158 21417036 249951.8] W'465344N 151-38'05083V/ 0.19 -55.13 GI0 .3177 .3.13 058 053 2.32 0983 90.00 0.29 8279 ]99,9] 61.9] 645 199 214174.79 249935185 W47NASON -151'3090.6]4'9_ 011 -143.36 0,00 - 18.0 -2.93 062 0.57 2.33 6205 No. OG 0.25 7562 883,97 11.97 439 2A5 21417535 2499351.93 60.4953491N 151'36'0311659 005 59.16 - -004 Q17 -2.00 ON 061- 2.34 4,46 10009 0,33 619 99997 839.97 4.57 291 214175.72 2499352.11 W`5953493N 151•MWC55W 0.11 90.59 000 - .14.59 -2.23 11 OW 0.65 2.35 4].12 1100.00 033 7021 1099.97 939V 49] 345 21417636 249935230 W-49'W495N 151s3606.645V 0.10 44970 0DD - 1].18 -1 W I 063 ON 238 40.51 1203.00 O17 1.1] 119997 19997 r 3]B 300 214176.62 2499352.40 60Y95349]N 151'J6'O6.SIM 0.25 71 18 -0.16 48.09 .1.46 ", 076 071 2.38 %35 'J DO 0.33 885 12999] 11399] 25.5] 4.15 2141]69] 2499352.08 W'4P53A99N 151•W9663090.23 91.75 0.16 - 4240 1.11 I On O74 239 28,W __._ _. 140M .00 033 69.15 13999] 1239.9].97 4.1 d95 2141]].52 2499352,06 W470 W1N 151°35'006199 002 - .94 19 5,00 705 - -09 069 ON 243 2399 IWO OO 0.02 358.62 159990 133990 49 6.95 2141]6]9 24993538] 0.4951SION 151'3696.6129r 0,62 4t8 049 ]0.53 2W ON 0.80 - 243 1B.9 1939 3.15 311J2 159950 153990 064 4,2 21417880 . 2499)990 W -49'53510N '38116 242 1970 233 .339 2.38 0.90 -083 2.44 1670 160.0 6.69 329.8] 189953 153953 601 -025 21418.85 2499365.4] WNS3613N 151.36W.6194] 3,36 1049 336 - 685 6.39 091 086 2.46 2497 100.00 825 3229 r VIEW 183970 1895 1541 2141944 2499375,86 W-4953RON151'36986549 176 -0.9 115 - 131 1311 090 0.91 246 339] 2 W00 116 3299 191.42 173747 47.75 1541 214158.29 2499)8080 - Wb9'53.650N 151.9'062259 151 51 1.51 460- 20.59 1 1.00 090 -- 269 - 7].4 21M DO 11.69 32682 195]2 183572 _ 4].)5 -2503 21414885 2499405.]1 9'49'54.0041 "151.99129'9 195 5.14 194 0.96 29.24 1 1.05 101 2.51 539 2110.00 13.39 32864 r 219021 193323 9.5] 420] 21413]5] 249942381 M -4954.189N 151-3507.4671V 220 302 219 2S9223 5015 1.12 108 252 529 2z0GOO 15.38 330.8] 2190.21 20021 028] 4936 - 214125.10 249940510 M-49 51.39M 151'907.910'W 065 3.02 0.51 - 213 52.75 1.10 - 1.14 2.55 24302 230360 15.03 3319 2286.93 212693 1099 41110 211113.91 249948]89 00'4956 81614513696.999 085 2.09 OW 0.13 9.18 113 121 29 26]60 24M GO 16]4 331.1 2393.10 222310 133.01 94.90 210101.30 259959190 W'0Y52.BSTN 45P:19YW Y15W 1.]1 1.20 1l1 01 W74 1.30 1]B 261 279.96 24300 1.91 33130 241114 2251 ]4 _ 14168 79.19 21403]21 _ 249949992 9'49'54.9291 151-35'0831M 3.93 2054 3.93 027 8553 j 1.33 130 _ 2.00 25934 2518.9 1954 330.41 259343 233343 - 165.10 -9118 2149089 249951374 W'49'S5.24IN 151'MC8,66NV 080 - 9790 4,0 -0.13 99.]4 I 1.5] 131 3.9 24193 255521 18.53 3999 8521031 236131 173.32 .9588 2140930 2599531.90 BO'0g55241N 151'1'08 W6'W 0.25 -N.15 -0.9 0)0 104 62 189 13] 3.61 24 30 2630,W 21.9 32889 260800 244080 20064 .1130 2149431 - 249955970 6O'466551 ON 151'9'04049 3.63 -2239 - 3.38 402 12044 "'i 199 157 - 3.61 4807 2733.33 2555 32322 2695.61 2535.81 23166 13533 214043.28 - 249959124 W49'9.815N 151.36'094449 439 48 32 - 4.11 J87 13]01 2.00 - 18] 3.05 35,04 2029.21 28.30 32235 278108 2621.06 268.2] 18163 21401283 249962649 00'49'90156N '.151'36'099659 298 -0009 295 -091 154.53 3.06 235 4.03 31.90 19237 30.96 32142 2863.12 - 2703.12 W3,015 AW51 21395986 249968396 60.469.510N %151'36'10919- 319 585 - 264 4098 17269 6.04 269 - 4.19 3201 311242 r 30.60 321.1870 33 W 6 3021.28 29128 26396 @5435 - 21392802 - 249975640 80'49 .221.N 213959,46 2499704X 9,W9N ',151.M 11 190V81 150 19 260 - 046 192.1] 439 - 3.20 4.35 0,8 151.36'11B45W- 1.51 -19911 - 1.5] 6.11 21252 4.68 - 376 4.51 28.40 3206,04 36.44 32018 317296 . 293296 420.9 .30826 2119466 24999.12 W 4V5]23)N 451'38'12559" 0,25 --n.21 V4 -106 2134 5.96 4,1 4.82 1939 As 330159 36.70 32004 31]626 MO 97 0]0.20 42072 213860 07 249987439 W-49W.185N 151'30'132599 035 Ino _ 046 4031 25402 5.33 5.]] 481 149 _ 0000 _._ 31205 1.]4 325.14 32509] 3009] 513.97 40.62 21302485 - 2499878 96 6O.4V55595N :151'36'13919 959 IN 72 046 510 27085 6," 5.11 490 .H28J - - - 35909 4.9 3254] - 312706 316].9 - 557,nMiss -39.62 213]9301 - 249982299 (OW59.01N 151-36-14 655V216 109.]2 8.52 520 29651 664 - 5.30 5.9 1489 358543 33.21 32075 300596 322597 W2W -021.4 213765.13 24999048 W49WA62N .151-36'15239W 107 11902 -0,W 332 32162 7,19 5,90 539 33636 360011 31,32 33761 350528 332518 &].10 46713 213]2142 29035825 WWOO.90TN 151'3615150'9' 32] 119.9 -1,51 5,32 349,12 7.02 5,90 5.57 33390 3871.19 319 33161 3502.42 3502Q 90]5 48213 213622.69 25000929 W.Woo 338N 151.Ml 6.i38W 2,52 r 118.4 - 6.16 4.22 36268 842 6.15 576 33328 3965.59 30.1] 3424 2&]51 3406,51 638.18 451.60 21MS509 2WO15112 WWO1249N 1151-WISTI 1.52- 95.20 -1.11 4.46 - 58 24 9.4 BA2 595 - 33362 390559 20.9 3025 380.55 W53.32 - 72336 496.10 21369509 250015171 60'401.690N 151.9'167029 302 95.20 -1.33 5.% - 444.27 - 00 870 6.15 - 33449 ME 4050,9 - 29n 3534 3813Z2MB,69 3656,32 87031 -59.91 21364111,37- 25414.]3 W'S09L691N 151'36'189709 295 9714 -017 851 -- 4696] 1060 8.88 833 1566 419.47 - 2970 34A6 39889 136,59 g873Nlow -59,40 2139600 2WO287,31 4'50' 583N 151'36'18.919 265 WAS -0,06 5.51 WAS 1000 7,74 EN 1682 4759,5] 20.47 1016 397956 301952 ONCE 1915] 21361 2WO331.36 50.50 311151'36'189529 301 4.15 - GAS 6.26 55].88 1100 ],W OW 1]]3 4438] - 22.61 WN 408251 - 390251 - 963.59 .01,91 2137W68 29033189 W'504,023N 1S'.1861 OW 312 - WAS G. 6.61 599.54 1155 266 89 19.19 5430.]9 189) 1065 515563 1985.]3 14194 .44,90 71360088 2901]5 9] W'Stl03459N 151'36'186199 ].1J W.d9 G. 6251 643053 1300 8.05 103 48]] 453314 30.4 7161 422188 56019 105114 -0]5.]6 21372296 250041938 6O'4N.891N 15136'163179 282 6389 - 113 5,26 689.27 1243 833 ]21 47T] Paid' 1 03 4717.00 3281 -, 3059 630967 4239,67 113996 432,05 21376682 250054951 60.0 151'36'150,1002 281 5001 1,58 4.39 78757 1327 606 058 31695 4011,37 3595 35.20 - 456015 4W6.17 11 W5 - 40340 213]9854 2500549,90 .194N 60'W1,195N 151'36'14.05302 339 ]306 2.05 4.06 04010 1302 914 )97 348,18 5912,50 35,27 4032 ' 0506.17 006,1] 1227.52 -389.4 213833.22 " 2500592,52 60'0205.63314 151.38'11.90"- 3.28 - ]103 109 - 530 89435 1)02 - 9,76 - 7,92 308.93 0.]0 51 30,09 41.92 4622.02 4562.42 1369,15 3 -3470 2138]05] .42 2500635 60'S0'06.43 N .151'38'1306102 1.05 3230 0.30 1.]0 946 37 1436 9]6 8.16 31993 5100]9 36.91 -- 4281 4898.06 453804 135051 -295.70 - -255.]2 21390929 202007388 WW1439N 151'38'1288002 189 4039 0.90 0,95 1022.04 1465 10.0] 0.8 - 35131 5192.21 37.90 4340 4]]6]2 4814.72 13M54 21395030 2500]15 35 60'02005914 151.38'118]302 0.89--- - 0.79 105953 1528 1038 8,76 - 352.76 5390.10 37.99 4312 484018 468618 139054 -216.52 21409050 2500]55]5 67'5007.NON 151'36'11.MM 0,21 -101.39 N 0.0 006 40 1171.]3 � 1530 10.70 0]6 35634 5305.90 37,89 43]0 4923]4 4833]4 143142 -176.19 21403100 2500)9]62 -50.50MR11 ON 155.36'5020002- 031 302 0.19 - 093 117177 ''. 15.60 11.03 8,97 35509 5581,80 360 4300 41937 48392] 152116 --96.73 21409320 2500889.69 W'W'35,520N 151.36'09,15602- -0.19 - 1fi0.53 0.19 074 12289] 1. 1595 1137 - 9.19 - 35].69 55]513 3690 --- 5327 50]35] 491357 - 1521.68 Oe,]3 2141M97 2500000.11 -60'50'00.52014.151.36'08.67802- 1.33 05.63 425 044 1304.15 " 1639 1110 091 35911 5675.42 36,92 - 4335 5150.08 51008 1583.51 5113 2141N 0] 250092099 W'S000.936N 151-N07.078V 0.26 Vol 0.02 - Odd 1339.78 ' 1702 1205 066 075 5785.38 3720 4371 530530 506528 2142M43 ' 2501MI55 67.60'09335N 151.3602,28802- 0.30 0.30 00 1494.75 ". 1702 1238 9.86 5954.14 4319 5300.81 B4 Ifi4332 - IU622 2134 2131 214234.43 250104155 151'36'0838402 035 123.74 123.94 -013 1450.17 11a1 1372 _ 1001 - 009 4M - 5959.64 WN 36.94 43,54 5376.00 U16 521630 107.8 0200 21427419 250104196 W-W'09.i55N W'5TIOMIN 151.46'05,496" 0.27 46.12 -024 0Z5537 0.9 1505.27 ' 1181 - 13,05 10,31 580 8043.8 _ 4373 555204 529204 17790] 214314.85 250100261 02.50'1059114 151.3'03,91 W 0.45 14830 1235 - 151.85 1 18.22 1339 10.75 729 62M52 M,85 38.85 4376 5$].36 5351,16 1]]919 3&91 13891 214354,99 250112201 60'50'10966% 151'38'0,191202 0.90 -15gm AM 6.39 0� 161559 1063 1317 _ 10]] 805 6238.52 38.8] - 4233 5673.19 541]19 101162 14.54 21/39464 08 151.3603,134YJ 0.99 0.09 462 1,6 16]055 19.5, 1405 1101 10.30 8333.05 38.44 4308 8]9]] 819]] 1853]1 215.64 214533]4 ON IMI 250120126 60'021140814 151.3 W -WI 036 123.98 137.57 -0.24 178501 19,57 1138 1135 11.15 3912 42.16 1937N 253)6 - 214572.02 250124576 1,J94W 151'36M W'Wl2 004 .0.02 005 0.05 178131 ' - 16]0 - 14,79 13.15 6529.58 8523.15 38.31 - 4193 5022.14 N32.14 M72 14 M7214 193303 202,91 21451102 250128574 NOW 845YV_ 60'50-12.02914 151'36'0204502 016 9724 97.20 012 025 181525 � M43 1743 15.04 11]3 15.90 6618 75 35,29 4223 5909.10 1029,1 214549.90 250IM6.80 151.36'00.0]9W Ot] - 57.90 0,02 0.26 1090.36 2090 15,34 1190 1502 6712Y5NOO,64 38.61 4309 596400 W2918 592080 210,16 MMON6,70 306]0 214588,01 2501386.95 W-50 Q427N W"02'1312]14 151'35'5031602 064 24.51 031 0.90 1999.85 21 3] 1597 1232 10,79 6902.61 33.90 4323 608004 590002 212,12 60515 21482825 - 250140695 60.50'13.WON 151'8'50.1002 064 11592 - 061 042 1999.12 2685 159] 1278 1191 6996M 36.79 4388 fi13599 599629 210305 44293 21666801 2501447.68 60.50'14.241N 151'35'9]7202 036 4]097 000 2059.]0 22.35 1629 1272 19,03 8996,86 - 35.32 42N - 021299 613399 2173.15 60203 214]0801 250168706 603615.03014151.3589)102 1S2 -16101 -151 -1.51 071 2108.50 22.04 1861 129] 20,03 709191 33.92 0268 6291,19 6131.19 21036 519.]] 21479561 - 250152567 60'W15.022N 151-35-56,22M 152 -19139 -153 063 2107.01 23,33 16.23 1323 20.90 2178.71 34.23 4220 6206.92 221)02 551 74 2148]852 250155903 151'35'55.36202 193 -168.30 -1.95 OSS 2201.06 2324 17M 1372 21.59 ]2]328 29.1 4001 64590 W570 826557 2253.98 58301 21481152 250159536 W5615.322N W'S0'15JR9N 151.355433502 373 -1]330 -3.32 -167 2254.39 24,20 1156 1399 ]360,15 2579 3962 63895] 226102 016)0 21461035 250162173 54 37M 3.32 1]9]9 -379 -105 2296.83 2U0 19.33 1399 1276 n46 7554.45 22.33 3965 N193] 061640 &5810 23160] MOM 21608552 2501881.4 W-W16D55N 151'35'549]]" 333 115.19 -3.33 0,03 2334.66 25.12 18.31 1425 2202 - _ 337M 43]5 670434 654434 234330 85902 214080.90 250160100 W-W1839N W'W16623N 151.35'5391802 250 -195.1 -312 035 236611 25.51 10.02 1410 23.99 76M35 ]69.49 120 1102 4390 679534 672697 23&99 0076 21491090 2501701.00 W -5916 623N151.36%,68402 2.80 17379 -226 000 2493,30 2508 19.1 1420 2339 _ ]]4210 1630 46,41 0053] 615,3] 23B3.75 690.30 21492926 250173232 WW17.152N 151.35'52624V 3.52 1]3.98 -351 1,62 244368 2632 19.30 1501 2351 7&261 4113 69]0.38 01496 - 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W'4919,256N 151.3643433W 020 67,08 0.19 0.05 493830 7082 2984 3508 20544 1614891 93.18 211.37 981569 967569 - 3571.06 -180346 - 21220207 24958/120 W 9'1B650N 1545.716W 060 -071.70 0.07 070 4020.86 459 2991 3501 ID554 16230.18 171 21102 984253 9602.53 - 4751 49 -093269 21215192 2495787.16 6049'14.6)31151-N1'3645,W9W 298 - 130,69 2.65 439 4121.70 5515 29.99 3574 205.74 16425.10 8940 203.92 984234 9682 37M358 - 3]2332 -1926.97 212101]2 2497082,43 60-49`16.86674NOW 151'36461070 1,41 -in4.4 -1.16 421594 4.13 30.07 35 70 205)4 16529& 7906 20Tg6 9843.58 10350 3806.36 -2026.50 212052.12 249560023 W'49'18849N 151'35'4158070 241 - -2881 28,81 -00 -292 -031159 4,92 - 30.15 3603 205]9 16553J2 B9.d6 20]46 707389 909309- 3027 55 -2031.4 21211252 27955]9.)2 607515.8111 151-7o^2803W 1.91 OW _ 1.67 4292 433558 57,11 30.9 3813 20500 Piga 3 of 3 Guhl, Meredith D (DOA) From: Cody Dinger <cdinger@hilcorp.com> Sent: Wednesday, January 2, 2019 9:42 AM To: Guhl, Meredith D (DOA) Cc: Schwartz, Guy L (DOA); Boyer, David L (DOA) Subject: RE: [EXTERNAL] TBU M-35 L1, PTD 218-105, BHL coordinates Hi Meredith, I provided incorrect X/Y coordinates(those are the BHL coordinates for M-35), here are the correct ones: X - 212025 Y —2495547 Happy new year to you as well! Thanks, Cody From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Wednesday, January 02, 2019 9:33 AM To: Cody Dinger <cdinger@hilcorp.com> Cc: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Boyer, David L (DOA) <david.boyer2@alaska.gov> Subject: [EXTERNAL] TBU M-35 L1, PTD 218-105, BHL coordinates Hi Cody, Happy New Year! I'm catching up on data entry for 10-407s that arrived while I was on vacation. I've got an error showing for the BHL coordinates on TBU M-35 L1, PTD 218-105, where the Box 4a calculated coordinates do not equal the coordinates listed in 4b. PT -t . I Fa ii= . I MD . '' TVI . I Fit*15 . M3 RE . i E . & . I Twl . i I . I Rr . P . I PD1 . Iadia . Azim . I ASPZ - BBL L REST FORD -AP 15490 9844 276 8 1503 E _ 32 91N 13W S _ _ _ 4 Yellow boxes are the coordinates reported by Hilcorp in box 4b, compared to the coordinates calculated from the location entered in box 4a. Can you please check the coordinates in both boxes and let me know which ones are correct? Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 mered ith.guhl @a laska.aov Direct: (907) 793-1235 I CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information tium the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,. use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.euhiPalaska.eov. Debra Oudean Hilcorp Alaska, LLC AK_GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Hil.wp Alu.ka, U.0 Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 11/20/2018 To: Alaska Oil & Gas Conservation Commission - fttUraHtes CtGolota %15s sit 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 TBU M -35L1 218-105 Transmitted herewith are cuttings WELL BOX # SAMPLE INTERVAL TBU M-351_1 1 OF 5 9670' - 11400' TBU M -35L1 2 OF 5 11400'- 12750' TBU M -35L1 3 OF 5 12750' - 14430' TBU M -35L1 4 OF 5 14430' - 15990' TBU M -35L1 5 OF 5 15990' - 16490' Please include current contact information if different from above. a�g-/o!S-- / 6 a-1 RECEIVED NOV 2 1 2018 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Receive ey< Date: !1/2`3/! C/ U THE STATE °fALASKA GOVERNOR BILL WALKER Stan Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, West Foreland Oil Pool, M-�5L1 Permit to Drill Number: 218-105 Sundry Number: 318-445 Dear Mr. Golis: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair, Commissioner DATED this Q) day of October, 2018. RBDMSILocT 0 8 2ols STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AA(-. 9F 2Rn //yrs/sf 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate E • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Completion ❑� 2. Operator Name: 4. Current Well Class: 15. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 218-105 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: 50-733-20680-60-00 ' Anchorage, AK 99503 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 ❑Q Trading Bay Unit M-351-1 9. Property Designation (Lease Number): 10. Field/Pool(s): McArthur River Field / West Foreland Oil Pool ' ADLO18730 / ADLO17594 it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): ±16,500' (proposed) ±9,810' (proposed) ±16,450 (proposed) ±9,820' (proposed) 3,129 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 488' 34" 488' 488' Surface 2,505' 13-3/8" 2,505' 2,482' 5,020 psi 2,260 psi Intermediate 10,595' 9-5/8" 10,595' 9,274' 6,870 psi 4,760 psi Production Liner 6,830' (proposed) 7" ±16,500' (proposed) ±9,81 0' (proposed) 7,240 psi 5,410 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A & N/A N/A & N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory ❑ Stratigraphic ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/17/2018 OIL ❑� - WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golis Contact Name: Michael Quick Authorized Title: Operations Manager Contact Email: m uick hilcor .Com Contact Phone: (907) 777-8442 O Authorized Signature: � Date: t0 3 t�j COMMISSION USE ONLY Conditions of approval: Notify Commission so tat a representative may witness Sundry Number: %✓', �U( I_.11 f✓/1 Plug Integrity ❑ BOP Test 1-g Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,� 3 500 i s 4610 Post Initial Injection MIT Yes ❑❑ No [-IYes Form Required: Spacing Exception Required?ired? No t'-�'/ Subsequent C APPROVED BY Ile, Approved by: COMMISSIONER THE COMMISSION Date: (D 6 �o.sis RCnhJall��Itll.��QMS��- OCT•�8'�' l"'�•/0 Submit Farm antl Form 10-403 Revised 4/2017 Approved applica d 5 e a e of approval. Attachments in Duplicate K tlil�orp Alaska, LLC Well Work Prognosis Well Name: M-351_1 API Number: 50-733-20680-60 Current Status: Grass Roots Producer Leg: A-2 SE Corner Estimated Start Date: October 17, 2018 Rig: Steelhead Rig #51 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: 3. Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 218-105 First Call Engineer: Mike Quick (907) 777-8442 (0) (907) 317-2969 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 4,100 psi @ 9,713' TVD 0.422 lbs/ft (8.12 ppg) based on offset producers Maximum Expected BHP: 4,100 psi @ 9,713' TVD 0,422 lbs/ft (8.12 ppg) based on offset producers Maximum Potential Surface Pressure: 3,129 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary M -35L1 is second lateral in the M-35 grass roots West Foreland only producer that will be completed with an ESP. This project will perforat6 the upper lateral (L1) and run the completion string for this dual lateral well. M- 35 (Lower lateral) was drilled, cased and perforated under PTD 217-119 and Sundry 318-310. Last Casing Test: Casing and liner tested to 2,000 psi under PTD 218-105. Procedure: 1. ***Take over operations from the Drilling Program *** 2. Test BOP'S every 14 days continued from last test date from PTD 218-105. Test to 250psi low/3,500psi high / 2,500 psi annular. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 3. BOP'S will be closed as needed to circulate the well. 4. Optional: RIH with bit and 7" casing scraper to TD. 5. Pump wash train to clean casing, displace well to diesel. 6. Run lateral diverter and land in RAM hanger. 7. Rig up E -Line and run gamma/ccl/cbl. POOH. 8. PU TCP guns, RIH and perforate per pro ram. • X-ro5 9. After detonation, circulate out any perf gas, confirm well is static, POOH. 10. Run Baker 7" packer with Seal Bore Extension and set below RAM liner hanger. 11. RIH and Pull lateral diverter. 12. Run in with seal assembly, sting into RAM Sealbore Diverter, shear out mainbore M-35 isolation packer pump out plug 13. Run RAM Level 5 equipment: Multi -Lateral completion tools, including Dual Seal Module, X Nipples, Selective RE -Entry tool, and SC -111 Production packer. 14. PU and run ESP completion w/ high set packer, packer vent valve, and SSSV on 3-1/2" tubing. ' E S� Set Packer at +/-480' and test to 1500 psi for 30 minutes Al IT— tib 15. Set BPV. NU tree, test same. �h 16. Turn well over to production 17. Schedule SVS testing with AOGCC as per regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed H Hil.p Al..U, LLC 3. Wellhead Schematic Proposed 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form Well Work Prognosis ( Steelhead Platform Well: 1-35 CURRENT PTD: 50-7339 API: 50-733-20680-00 Ilacuro Alaska. LL[ Last Completed: Future RKB to MSL =160', RKB to Seafloor = 345' "x2 34" x 28" Cement Sam, Stage Collar @ 16,400' Ord ' Not Close Cement Barrier Only, TOC @ 2590' Per CBL - MMPtiner Hanger@P 9,719' 9-5/8" 4i; Baker Model FPermanent Packer w/shear out sub @ 9,830' v i,i S 1ITi t r 7- k > FETD: 15,335' TD: 15,375' Max Hole Angle 92' @ 15,374' CASING DETAIL Size Wt Grade I Conn ID Top Btm 34"x28" Top (MD) Conductor Top (TVD) 27.5" Surf 488' 13-3/8" 68L-80 WF -1 BTC 12.415" Surf 2,505' 9-5/8" 47 L-80 BTC 8.681" Surf 10,595' 7" 26 L-80 DWC/C 6.276" 9,719' 15,335' 14,692 15,224' 9,839' 9,823' 532' 6 9/28/2018 TUBING DETAIL Updated By: MJQ 10/02/2018 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Feet SPF Date Status WF -1 11,015' 11,955' 9,678' 9,826' 940' 6 9/28/2018 Open WF -1 11,982' 14,624' 9,827' 9,841' 2,642' 6 9/28/2018 Open WF -1 14,692 15,224' 9,839' 9,823' 532' 6 9/28/2018 Open Updated By: MJQ 10/02/2018 n corn Alaska. LLC RKB to MSL=160', RKB to Seafloor= 345 E 34" x 29' Stage Collad @427 i Cerrent i m Surface 13-3/8' Stage Collar @±6,404 Did not close. Cement barneronly TOC @2590' Per CBL 2 3 EA i• 6 e' 7 Baker RPM �• 8' Level SJUMion ;•H .. Mn10=2625" 11 91 10 PROPOSED SCHEMATIC rASINfi DFTAII Trading Bay Unit Well: M-35 Ll Last Completed: Future PTD: 218-105 API: 20-733-206808-60-00 Size Wt Grade I Conn ID Top Btm 34"x28" Depth TVD Conductor OD Item 27.5" Surf 488' 13-3/8" 68 L-80 BTC 12.415" Surf 2,505' 9-5/8" 47 L-80 BTC 8.681" Surf 10,595' M-35 7" 26 L-80 DWC/C 6.276" 9,719' 15,335' Ll 7" 26 L-80 DWC/C 6.276" 29,670' ±16,500' TUBING DETAIL 3-1/2" 1 9.2 L-80 IST 1 2.998" Surf 29,460' I Pvsl 5 MDlti-I Aterml .fi nntinn No Depth MD Item 5 JEWELRY DETAIL No 6 Depth MD Depth TVD ID OD Item Baker RAM Dual Seal Module 8 ±9,650' Baker TAM Level 5 RAM Hanger 9 Tubing Hanger 1 10 ±450' 1450' 11 SSSV 2 ±480' ±480' High set ESP ckerw/WFT ventvalve 3 ±9,400' ±8,536' X -nipple N/A Discharge, Bolt -On N/A Pum N/A Intake 4 N/A Seals N/A Motors ±9,500' ±8,669 1 N/A 1 Gauge / Centralizer / Anode "Note -Strai ht Hole Pum p Tangent Section±9,400'to x9,600' I Pvsl 5 MDlti-I Aterml .fi nntinn No Depth MD Item 5 ±9,550' Baker SCA R Retrievable Production Packer 6 ±9,575' Baker Selective Re -Entry Tool 7 ±9,600' Baker RAM Dual Seal Module 8 ±9,650' Baker TAM Level 5 RAM Hanger 9 ±9,800' Baker TAM Level 5 RAM Sealbore Diverter 10 9,830' Baker Model F Production Packerw/ Shear out sub 11 x9,850' Lt Baker Model F Production Packer LATERAL WINDOW DETAIL Top of "L1" Window @ 9670' MD; Bottom @ 9790' MD; Angle @ top of window is 28 deg l TD = ±16,500' (MD) / TD = 9,810'(TVD) IF If1111 L1 PTD 218-105 PBTD =±16,450' (MD) / PBTD = 9,820'(TVD) Irl L1 Wellbore Angle = 98 deg @ 14,800' MD PERFORATION DETAIL L3: ± 12,750'to±16,500' MO in West Foreland 1 & 2 zones ✓ M-35: 31,015'to 15,224' MD in West Foreland 1. 4-1/2" TCP 6 shots/ft; 60 deg phasing ax Wellbore Angle = 92 deg @ 15375' MD �L1H k4h1111 W11:1111 .4 TD = 15,375' (MD) / TD = 9,818'(TVD) PTD 217-119 PBTD = 15,335' (MD) / PBTD = 9,819'(TVD) Revised By: MJQ 10/01/18 Steelhead Platform M-35 Proposed xafer� ,�u..►.. ia.E: 07/05/2018 Steelhead Platform Tubing hanger, S -BB -ESP, 13 5/8 M-35 X4 M EUE 8rd lift and susp, w/4" 26 x 13 3/8 x 9 5/8 x 3 1/2 Type H BPV profile, w/ 4-1/2npt CCL ports, 6 Y, extended neck, prepped for BIW feed-thru BHTA, Bowen, 41/16 5M FE X 7"-55A Bowen top Valve, swab, CIW-FLS, 41/165M FE, HWO, T-24 V211/16in" MI HWO, L &111! N (( Valve, lower master, CIW-FLS, 41/16 SM FE, HWO, T-24 Multi-bowl, Seaboard SMB - 22, 13 5/8 SM x 20 %3M, prepped w/ 13 3/8 PP bottom, 4-21/16 SM SSO Starting head, Seaboard, S -22 -AP -8, 20 %3M FE x 28" BW bottom w/ 2- 21/16 5M SSO Valve, SSV, WKM-M, 31/8 5M FE, w/ Omni 15" operator Adapter, Seaboard, ESP-4CL, 13 5/8 SM rotating flange btm x 41/16 SM rotating flange top, w/ 4- X hint CCL —rth ...—d fnr m W fmA- 3 %" H 11a.rr AWAa, LIA: Mud Cross 13 5/8 5M FE X FE ./3 1/8 5M EFO Steelhead Platform 2018 Rig 51 BOP 04/11/2018 STEELHEAD PLATFORM RIG 51 FLOW DIAGRAM HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well M -35L1 (PTD 218-105) 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 GOVERNOR BILL WALKER Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99501 Re: McArthur River Field, West Foreland Oil Pool, TBU M -35L1 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1 433 Fax: 907.276.7542 www.aogcc.alaska.gov Hilcorp Alaska, LLC Permit to Drill Number: 218-105 Surface Location: 1144' FNL, 558' FWL, SEC. 33, T9N, RI 3W, SM, AK Bottomhole Location: 265' FSL, 1548' FEL, SEC. 32, T9N, R13W, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well Permit 217-119, API No. 50-733- 20680-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair J DATED thisZq day of August, 2018. STATE OF ALASKA AL XA OIL AND GAS CONSERVATION COMMI__ION PERMIT TO DRILL 20 AAC 25.005 AUG 2 0 2048 1a. Type of Work: I Drill ❑ Lateral'21 Redrill ❑ Reentry ❑ +' n' AJ Mile4 I 1 b. Proposed Well Class: Exploratory - Gas ❑ Stratigraphic Test ❑ De p rnpont Oil ❑v ' Exploratory - Oil ❑ Development - Gas ❑ Service - WAG ❑ Service - Disp ❑ Service - Winj ❑ Single Zone ❑v Service - Supply ❑ Multiple Zone ❑ 1 c. Speciryjf wpl(io�dior: ❑ Coalbed `,.L�1 !lLU--�iY\\f S�re((es Geothermal ❑ Shale Gas 2. Operator Name: Hilcorp Alaska, LLC 5. Bond: Blanket ❑' ' Single Well ❑ Bond No. 022035244 - 11. Well Name and Number: TBU M-351_1 3. Address: 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 6. Proposed Depth: MD: 16,532' TVD: 9,810' 12. Field/Pool(s): McArthur River Field - West Foreland Oil Pool 4a. Location of Well (Governmental Section): Surface: 1144' FNL, 558' FWL, Sec 33, T9N, R13W, SM, AK ' Top of Productive Horizon: 1547' FNL, 226' FWL, Sec 33, T9N, R13W, SM, AK Total Depth: 265' FSL, 1548' FEL, Sec 32, T9N, R13W, SM, AK 7. Property Designation: _ ADL018730, ADL017594 8. DNR Approval Number: N/A 13. Approximate Spud Date: , 9/15/2018 9. Acres in Property: . 8956 Acres 14. Distance to Nearest Property: • 9,755' to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x-214172 y- 2499356 Zone -4 10. KB Elevation above MSL (ft): 160' GL / BF Elevation above MSL (ft): N/A 15. Distance to Nearest Well Open to Same Pool: 1,180' to M-32RD2' 16. Deviated wells: Kickoff depth: 9621 feet • Maximum Hole Angle: 97 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 4443 • Surface: 2292 - 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" 26# L-80 DWC/C SC 6,911' 9,621' 8,693' 16,532' 9,810' 1123 ft3 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Drilling Ahead 11,474' 9,788' N/A Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 11,474' 9,788' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 450' 26# Driven 450' - 450' Surface 2,505' 13-3/8" L - 935 sx / T - 894 sx 2,505' 2,483' Intermediate 10,595' 9-5/8" Stg 1 1060 sx / Stg 2 920 sx 10,595' 9,460' Production (PLANNED) 5,511' 7" L-809 ft3 15,161' 9,800' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑� 20. Attachments: Property Plat O BOP Sketch v Drilling ProgramTime v. Depth Plot Diverter Sketch B Seabed Report 8 Drilling Fluid Program Shallow Hazard Analysis 8 20 AAC 25.050 requirements e 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Monty Myers Authorized Name: Monty Myers Contact Email: mm ers hilcof .Com Authorized Title: Drilling Manager Contact Phone: 777-8431 Authorized Signature: - Date: ZO O Commission Use Only Permit to Drill Number: I 5 PI Number: 50- — — O Permit Approval Data: I See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Q� No Mud log req'd: Yes ❑ No Kr Other: �9 ,� Samples req'd: Yes C-]L� HzS measures: Yes G�'NO ❑ Directional svy req'd: Yes [geNo ❑ Spacing exception req'd: Yes ❑ No Y Inclination -only svy req'd: Yes ❑ NOR' •JF '-Lt t S„ 41 Q --1 Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY I zq I )0 Approved by: C M IS I NER THE COMMISSION Date:o l ` Submit Form and Forth 10-401 Revised 5/2017 This permit is valid to o t �1-+tlk�a f royal per 20 AAC 25.005(g)� Attachments in Duplicate U Hilcorp Enc campmy 8/20/2018 Monty Myers Drilling Manager Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7`1 Avenue Anchorage, Alaska 99501 Re: M -35L1 Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com Dear Commissioner, Attached is the application for permit to drill M -35L1. M -35L1 is an oil production well planned to be re -drilled in a South-westerly direction from the existing M-35 utilizing the existing casing program down to 9621' MD / 8629' TVD. At 9621' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating West Foreland 1 and West Foreland 2 targets. A 6911' x 8-1/2" open hole section is planned. A 7" 26# L-80 DWC/C SC prod liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be tied back to the main bore utilizing a level 5 junction and completed with a 4-1/2" ESP completion. Drilling operations are expected to commence approximately September 15 th, 2018. L-� 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 Manager Hilcorp Alaska, LLC Page 1 of 1 Hilcorp Alaska, LLC M -35L1 Drilling Program McArthur River App�ro d by: M My s Revision 0 August 9, 2018 U mi..�. Al. k., LLC M -35L1 Drilling Procedure Rev 0 Contents Mud Program and Density Selection Criteria............................................................................12 12.0 1.0 Well Summary.................................................................................................................................2 2.0 Management of Change Information............................................................................................3 3.0 Tubular Program............................................................................................................................4 4.0 Drill Pipe Information.....................................................................................................................4 5.0 Internal Reporting Requirements..................................................................................................5 6.0 Planned Wellbore Schematic..........................................................................................................6 7.0 Drilling Summary............................................................................................................................7 8.0 Mandatory Regulatory Compliance / Notifications .....................................................................8 9.0 R/U and Preparatory Work..........................................................................................................10 10.0 BOP N/U and Test.........................................................................................................................11 11.0 Mud Program and Density Selection Criteria............................................................................12 12.0 Whipstock Running Procedure....................................................................................................13 13.0 Whipstock Setting Procedure.......................................................................................................16 14.0 Drill 8-1/2" Hole Section...............................................................................................................18 15.0 Retrieve Whipstock and Run Seal Bore Diverter.......................................................................19 16.0 Run 7" Production Liner..............................................................................................................20 17.0 Cement 7" Production Liner........................................................................................................23 18.0 Install RAM junction equipment.................................................................................................26 19.0 Run Completion Assembly...........................................................................................................27 20.0 RD...................................................................................................................................................27 21.0 BOP Schematic..............................................................................................................................28 22.0 Wellhead Schematic......................................................................................................................29 23.0 Days vs Depth.................................................................................................................................30 24.0 Geo-Prog.........................................................................................................................................31 25.0 Anticipated Drilling Hazards.......................................................................................................32 26.0 FIT Procedure................................................................................................................................33 27.0 Choke Manifold Schematic...........................................................................................................34 28.0 Casing Design Information...........................................................................................................35 29.0 8-1/2" Hole Section MASP............................................................................................................36 30.0 Plot (NAD 27) (Governmental Sections)......................................................................................37 31.0 Slot Diagram (As Built) (NAD 27)...............................................................................................38 32.0 Directional Program(wp09).........................................................................................................40 K lhl orp Alaska, Uk 1.0 Well Summary M-351-1 Drilling Procedure Rev 0 Well M -35L1 Pad & Old Well Designation Sidetrack of existing well M-35 (PTD#217-119 Planned Completion Type ESP on 4-1/2" Production Tubing Target Reservoir(s) West Foreland Planned Well TD, MD / TVD 16532' MD / 9810' TVD PBTD, MD / TVD 16449' MD / 9820' TVD Surface Location Governmental 1144' FNL, 558' FWL, Sec 33, T9N, R13W, SM, AK Surface Location (NAD 27) X= 214172.91, Y= 2499356.35 Surface Location (NAD 83) Top of Productive Horizon (Governmental) 1547' FNL, 226' FWL, Sec 33, T9N, R13W, SM, AK TPH Location AD 27 X=213831.93, Y=2498962.20 TPH Location AD 83) BHL Governmental 265' FSL, 1548' FEL, Sec 32, T9N, ROW, SM, AK BHL AD 27 X=211979.06, Y=2495538.77 BHL AD 83 AFE Number 1812535 AFE Drilling Days AFE Drilling Amount $5.7 MM Work String 5" 19.5# 5-135 NC -50 (Rental String from Weatherford RKB — AMSL 160 ft MSL to ML N/A BOP Equipment 13-5/8" 5M Hydril "GK" Annular BOP 13-5/8" SM Cameron Type U Double Ram 13-5/8" 5M Cameron Type U Single Ram Page 2 Revision 0 August, 2018 H Ilikorp AIu Bo. LLC 2.0 Management of Change Information M -35L1 Drilling Procedure Rev 0 11 Hilcorp Alaska, LLC F icz rP Changes to Approved Permit to Drill Date: August 9, 2018 Subject: Changes to Approved Permit to Drill for M -35L1 File #: M-351-1 Drilling Program Any modifications to M-351-1 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. By Approval: Drilling Manager Date Prepared: Monty M Myers Drilling Engineer Page 3 Revision 0 August, 2018 3.0 Tubular Program M -35L1 Drilling Procedure Rev 0 4.0 Drill Pipe Information All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 August, 2018 5.0 Internal Reporting Requirements M-351.1 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, mmyersahilcoip.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@hilcoip.com, and mmyers@hilcorp.com 5.4 EHS Incident Reporting viii. Notify EHS field coordinator. 1. This could be one of (2) individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it outH H a. Leonard Dickerson: O: (907) 777-8317 C: (907) 252-7855 b. Mark Tornai: O: (907) 283-1372 C: (907) 748-3299 2. Spills: a. Keegan Fleming: 0:907-777-8347 C:907-350-9439 ix. Notify Drlg Manager 1. Monty M Myers: O: 907-777-8431 C: 907-538-1168 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 hilcorp.com and cdinger@hilcorp.com 5.6 Casing and Curt report xii. Send casing and cement report for each string of casing to mmyers@hilcorp.com and cdinger@hilcorp_com Page 5 Revision 0 August, 2018 n Hi4.rorp Aleeba, LLC RKB to MSL =160', RKBto Seafloor = 345' SCHEMATIC CASING DETAII rading Bay Unit Well: M-35 Ll Last Completed: Future PTD: XXX -XXX API: XX-XXX-XXXXX-00 Size Wt Grade Conn ID ID DD Item 34" x 28" Conductor Tubing Hanger 27.5""" SSSV 13-3/8" 68 L-80 BTC 12.415 2 -nipple 9-5/8" 47 L-80 BTC 8.681" NIA Pum 7" 26 L-80 DWC/C 6.276" NIA Seals NIA Motors ±8,669 N/A Gau I Centralizer) Anode TD= '(MD)/TD= '(TVD) PBTD = ' (MD) / PBTD = '(TVD) TUBING DETAIL L-80 I2.998" Surf ±9,460' LATERAL WINDOW DETAIL f "L3" Window @ 9600' MD; Bottom @ XXXXX' MD; Angle Col top of window is XX deg Ll PTD XXX -XXX PTD 217-119 WELL INCLINATION DETAIL Max Wellbore Angle =97 deg @ 13500' MD -1 Wellbore Angle = XX deg @ XXXXX' MD Revised By: MJQ08/28/18 JEWELRY DETAIL Depth TVD ID DD Item Tubing Hanger ±450' SSSV ±480' High set ESP pacrc- x8,536' 2 -nipple NIA Discharge, Bob -0n NIA Pum NIA Intake NIA Seals NIA Motors ±8,669 N/A Gau I Centralizer) Anode ip Tangent Section±9,450'to±9,600' LATERAL WINDOW DETAIL f "L3" Window @ 9600' MD; Bottom @ XXXXX' MD; Angle Col top of window is XX deg Ll PTD XXX -XXX PTD 217-119 WELL INCLINATION DETAIL Max Wellbore Angle =97 deg @ 13500' MD -1 Wellbore Angle = XX deg @ XXXXX' MD Revised By: MJQ08/28/18 U Il&.q, Alk.. LI.0 M -35L1 Drilling Procedure Rev 0 6.0 Planned Wellbore Schematic it PROPOSED SCHEMATIC Stell No. -355 Platform Well No. M -35L1 mbn,n u:,.l. 133/8" RKB = 73.70' 7'• JEWELRY NO Depth (MD) Depth (TVD) item CASING DETAIL Window Depth / Baker Whipstock (To Be Removed) 2 9,300-9,621 1 8,692' SIZE WF I GRADE CONN ID TOP BTM. 26 262# Surf 450' - 13-3/8" 68# L-80 12.415 Surf 2,505' 9-5/8" 47# L-80 8.681 IDWC/C-SC Surf TOW (9,621') 10,595' Set MD 7" 26# L-80 6.276 9,621' 16,532' JEWELRY NO Depth (MD) Depth (TVD) item 1 9,621' 1 8,692' Window Depth / Baker Whipstock (To Be Removed) 2 9,300-9,621 1 8,692' 9-5/8 x 7" Level 5 RAM Hanger Junction 1 2 tALZx 95/8" IJ PBTO: 16,400' MD /9,827' TVD TD: 16,532' MD / 9,810' TVD Page 6 Revision 0 August, 2018 Open Hole / Cement Detail Conductor Driven 17-1/2" L-935 sx/T— 894 sx(Cement to Surface) 12-1/4" Stgl L-620 sx/T-440 sx Stg 2 L— 920 sx (Est TOC 32,000' MD) 8-1/2" 1123 ft3 (Planned Cement to 9,621' MD) 1 2 tALZx 95/8" IJ PBTO: 16,400' MD /9,827' TVD TD: 16,532' MD / 9,810' TVD Page 6 Revision 0 August, 2018 7.0 Drilling Summary M•35L1 Drilling Procedure Rev 0 M -35L1 is an oil production well planned to be re -drilled in a South-westerly direction from the existing M- 35 utilizing the existing casing program down to 9621' MD / 8629' TVD. At 9621' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating West Foreland 1 and West Foreland 2 targets. A 6911' x 8-1/2" open hole section is planned. A 7" 26# L-80 DWC/C prod liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be tied back to the main bore utilizing a level 5 junction and completed with a 4- 1/2" ESP completion. Drilling operations are expected to commence approximately September 15', 2018. 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. General sequence of operations pertaining to this approved drilling procedure: I. Steelhead Rig 51 will be over M-35. 2. Items 3 — 7 are covered by the M-35 completion sundry'(318-310) RIH with bit and 7" casing scraper to TD. 4. Pressure test 7" to 2000 psi. (This will require an approved change by the AOGCC, due to 9-5/8" stage tool, as approved PTD was 3500 psi) 5. Pump wash train to clean casing, displace entire wellbore to diesel (Approx 900 bbls), POOH. 6. Rig up eline and run CBL/CCUGR on tractor, from TD to surface. CBL is required to above TOC in 9- 5/8" casing per AOGCC. 7. RIH with TCP guns with 7" packer and perforate per perforating sheet (estimated 3500' to 4000' of shots), set packer and fire guns. Reverse out the gun gas after unseating packer. POOH. 8. RIH with Baker 7" packer/isolation plug and set —500' above top perforation (depth to be picked later). 9. Displace wellbore above 7" packer to OBM. Recover approx. 700 bbls of diesel for reuse. 10. PU whipstock, and mills and TIH to packer 11. Whipstock offset should be set to tool face offset from dedicated TFO run. 12. Swap well to 9.0 ppg oil based drilling mud 13. Mill 8-1/2" window and 50' of new formation at 9621'. 14. Perform FIT to 12.5 ppg EMW 15. POOH and LD mills. PU rotary steerable directional BHA and TIH to window. 16. Drill 8-1/2" production hole from 9671' to 16532' MD, performing short trips as needed ? 17. Perform short trip and condition mud. POOH 18. LD Directional Tools. RIH w/ 7" liner. Set liner and cement. Circ wellbore clean. �f laying down DP and liner running tools, 20. Run RAM hanger equipment (covered under separate sun I 21. Pressure up to shear plug in lower lateral r 22. Run 4-1/2" ESP completion 23. Land hanger and test. Ss+ti to 24. ND BOPE, NU tree and test void Page 7 Revision 0 August, 2018 H rlik,,q, .Alaska, ux 7.0 Drilling Summary M-35LI Drilling Procedure Rev 0 M -35L1 is an oil production well planned to be re -drilled in a South-westerly 35 utilizing the existing casing program down to 9621' MD / 8629' TVD. At 9621' MD the parent wellbore will be sidetracked and new wellbore and West Foreland 2 targets. A 6911' x 8-1/2" open hole section is planr, A 7" 26# L-80 DWC/C prod liner will be run, cemented, and F the interveUPERp The ll will be tied back to the` 0 bore utilizing a level completion. Drilling operations are expected to commence All waste & mud generated during drilling and G&I facility for disposal / beneficial reuse depe: A separate sundry notice will be submitted and for runni from the existing M- ��..n.�- penetrating West Foreland 1 based on data obtained while drilling junction and completed with a 4-1/2" ESP September 15`x', 2018. ion operations will be hauled to the Kenai Gas Field test results. P&A and wellbore preparation for the sidetrack the completion assembly General sequence of operations pertaining t this approved drilling procedure: CBS • 1. Steelhead Rig 51 will be o/eddrilling 5. 2. DP should be stood back ik 3. PU whipstock, and mills to�P P?14ak.. 4. Orient whipstock and set aright of highside. 5. Swap well to 9.0 ppg oil bmud 6. Mill 8-1/2" window and 5w formation at 9621'. 7. Perform FIT to 12.5 ppg 8. POOH and LD mills. P rotary steerable directional BHA and TIH to window 9. Drill 8-1/2" productio 10. Perform short trip an 11. LD Directional Tool . 1 xe ipletion t. and test void 12. POOH, laying do 13. Run RAM hanger 14. Drill out plugs in 15. Run 4-1/2" ESP 16. Land hanger an t 17. ND BOPE, NU n ole from 9671' to 165 orming short trips as needed condition mud. POOH RIH w/ 7" liner. Set liner atli��t. Circ wellbore clean DP and liner running tools, W � �-f utpment (covered under separate sundry) v�� r lateral Page 7 Revision 0 August, 2018 U Ilil,orp Al.k., I.I.0 M -35L1 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 the drilling of M -35L1. Ensure to provide AOGCC 48 hrs notice prior to testing BOPS. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP 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: Alternate MASP Calculation The calculated MASP for this wellbore when completely evacuated to gas is 3437 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 2292 psi which assumes that only 2/3 of the wellbore is evacuated to gas and 1/3 to 9.2 ppg reservoir fluid. Page 8 Revision 0 August, 2018 K Ilii o,p Al.kw LLC Summary of BOP Equipment and Test Requirements M -35L1 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 • Blind ram in bum cavity (Annular 2500 psi) 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) 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.reRR@alaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz@alaska.gov Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / (C): 907-223-3605 / Email: melvin.rixse@alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: victoria.loeppOa alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: hgp://doa.alaska.gov/oac/forms/TestWitnessNotifhilml Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 Revision 0 August, 2018 K IIII.g1 Ak.ka, LI.0 9.0 R/U and Preparatory Work 9.1 Mix mud for 8-1/2" hole section. M-351.1 Drilling Procedure Rev 0 PUMP PERFORMANCE CHART LINER SIZE IN INCHES tM53DMUD 150 12' M5P.S1 7500 7052 5715 4723 4313 3968 3650 3381 GPR. 1.96 248 3.06 370 4.05 441 478 517 3130 5.58 2915 600643689F 2718 2590 G P.M. @ 150 SPM 294 372 459 555 608 652 717 778 837 900 965 1032 HHP 1266 1530 11519 1530 1531 1527 1529 iS18 1531 1530 1529 RODLOAD# 91,245 1122110 11220D t1ij59 111, 5 112J91 11133 112JN f NOTE: I.H P.=INPUT HORSE POWER S.P.Mn STROKEPERMINUTE P'S1.= POUNDS PER SOUARE G.P.R= GALLONS PER REVOLUTION INCH 'MAX-P.S.I. CALCULATIONS DO NOT EXCEEDMAMMUM FLUID END PRESSURE RATINGS BASID ON 10096 VOLUMErRIC EFFICIENCY AND90%MECHANICAL EFFICIENCY Page 10 Revision 0 August, 2018 H nil. ,p.Alaska, LLC 10.0 BOP N/U and Test M -35L1 Drilling Procedure Rev 0 10.1 * BOPE was NU and tested on prior completion 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 Hydril GK annular BOP. • 13-5/8" Cameron "U" Double gate. (blind ram in bottom cavity) • 13-5/8" mud cross • 13-5/8" Cameron "U" single gate. • 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!!! 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 > 8-1/2". Page 11 Revision 0 August, 2018 H Ililwrp .Alaska, LIA: 11.0 Mud Program and Density Selection Criteria 11.1 8-1/2" Production hole mud program summary: M -35L1 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: 9.2 ppg 80/20 Enviromul MOBM Properties: ND u 2 Viscosity Pv YP HTHP WPS ES EZ MUL NT pg1 GELTONE V 6-10 ppb Lime 7 ppb DURATONE HT 2 ppb 9,621 —16,532' 9.2- 9.7 50-80 25-35 15-22 <5 250-270K '580 System Formulation: 80/20 Enviromul MOBM Product Concentration LVT 0.662 bbI Water .172 bbl INVERMUL NT 4 ppb EZ MUL NT 4 ppb GELTONE V 6-10 ppb Lime 7 ppb DURATONE HT 2 ppb Calcium Chloride 21 ppb BAROID 41 9.0 ppg (as needed) BARACARB 5 3-5 ppb BARABLOK 2ppb 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 August, 2018 N Qil""p AlaAa, LIX 12.0 Whipstock Running Procedure M -35L1 Drilling Procedure Rev 0 The MLZXP was set on the prior liner run and the orientation of the helical profile has to be known to orient the whipstock face to the proper direction for kick off. An independent MWD run is required to understand what orientation the helical profile is in to adjust the offset before running the whipstock. 12.1 Make up MWD and drilling anchor and RIH to MLZXP liner top 12.2 Wash down through top of liner and land drilling anchor in helical profile 12.3 Record MWD azimuth and inclination orientation of helical profile 12.4 Unlatch from profile and repeat step 12.3 a minimum of 3 times to makes sure numbers are within 5 degrees on azimuth and 2 degrees on inclination. 12.5 Once numbers are confirmed POOH and lay down drilling anchor and MWD 12.6 CBU & circ at least (1) hi -vis sweep to remove any debris. Anything left in the wellbore could affect the setting of the Whipstock. 12.7 Pick up Whipstock per Baker rep using the Baker Whipstock handling system using air hoist. Allow assy to hang while Baker Rep inspects and removes shear screws as needed and any safety screws. 12.8 Verify that the orientation of the spline on the drilling anchor is offset from high side to match the readings that were obtained. Whipstock Orientation Diagram: 25R HS 65R HS Desired orientation of the Whipstock face is 45 degrees right of high side. Hole Angle at window interval (9621' MD) is 28 deg. The wellbore trajectory is planned to kick off at 198 degrees azimuth. Page 13 Revision 0 August, 2018 U lnm.p Af nka, LK Note: Attach mills to Whipstock with(]) 35k mill shear bolt. 12.9 If needed, open BOP Blinds. M -35L1 Drilling Procedure Rev 0 12.10 Run the Whipstock in the hole, install safety clamp as per Baker Rep, and install hole cover wrap. 12.11 Release pickup system at this point, Makeup mills. 12.12 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. 12.13 The assembly can now be picked up to ensure that the shear bolt is tight. 12.14 Remove the handling system. 12.15 TIH to MLZXP helical profile (9621' MD). Keep up with the # of joints picked up so we know where we are. 12.16 Slowly run in the hole as per Baker Rep. Run extremely slow through the BOP & wear bushing. 12.17 Run in hole at 1 % to 2 minutes per stand. 12.18 Fill every 30 stands or as needed, do not rotate or work the string unnecessarily. 12.19 Call for Baker Rep. 15 stands before getting to bottom. Page 14 Revision 0 August, 2018 H juh—p \la.kv. LI.I. ®'. 3.41 Page 15 Window Master G2 Whipstock With Torque Master Bottom Trip Anchor 9.625 53.5# Non Special Drift Casing Revision 0 M-35LI Drilling Procedure Rev 0 rIi BAKER HUGHES Baker Oil Tools SHEAR BOLT 25,000 35,000 45,000 55,000 65,000 75,000 Lower Watermelon Mill Upper watermelon Mill OD:8.500 8.375 Length: Length: 5.66 6.25 17.08 Flex Joint OD: 6.375 Length: 8.500 9.00 Lower Watermelon Mill OD: 8.000 8.375 Length: Face Angle: 5.66 Face Length: 17.08 WlndowMill OD: 1 8.500 Length: 1 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: 1 44' August, 2018 H nileorp Almiku, LLC 13.0 Whipstock Setting Procedure M -35L1 Drilling Procedure Rev 0 13.1 RIH until the bottom of the anchor is 20-30' away from the window exit. 13.2 Record PU weight, SO weight and torque. 13.3 Continue to RIH until the anchor orients on the MLZXP helical profile. Set down 20k lbs to ensure anchor is fully landed. 13.4 Apply an overpull of 10-20k lbs to verify that the anchor is latched in place. 13.5 The window mill can then be sheared off by slacking off weight on the Whipstock shear bolt. (25k shear value). 13.6 P/U 5-10' above top of Whipstock. 13.7 Displace to 9.2 ppg 80/20 Enviromul MOBM. 13.8 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. 13.9 Install catch trays in shaker underflow chute to help catch iron.. 13.10 Keep iron in separate bbls. Record weight of iron recovered on ditch magnets. 13.11 Estimated metal cuttings volume from cutting window: Wieght of Cuttings For Milled Casing Exit O.D. Of Casing (In) 9.625 I.D. Of Casing (in) 8.535 Whipstock Face Length (Ft) 16.00 Percent of Casing Removed (%) . 38 Milled Area (In"12) 5.908 Volume of Cuttings pn"3) 1134.272 Density of Casing (lbAnA3) •• 0.2 Weight of Cutting Generated (Ibs) 321.0 Calcufaled Average of Casing Removed Be on Drift Mills (38%) •• DenW of Steel =.283 Page 16 Revision 0 August, 2018 K l/ik.,p M.A., TAX M-351-1 Drilling Procedure Rev 0 13.12 Drill approx. 50' rat hole to accommodate the drilling assembly. Ream window as needed to assure there is little or no drag. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 13.13 Circulate Bottoms Up until MW in = MW out. 13.14 Conduct FIT to 12.5 ppg EMW. • (12.5 — 9.2) * 0.052 * 8629' tvd = 1481 psi 13.15 Kick Tolerance • (12.5-9.2) * (8629/10053) = 2.8 Note: Offset field test data predicts frac gradients at the window to be between 12 ppg and 15 ppg. 4 12.5 ppg FIT results in a 2.8 ppg kick tolerance while drilling the interval with a 9.2 ppg fluid density. 13.16 Slug pipe and POOH. Gauge Mills for wear. 13.17 Should a second run be required pick up the following BHA. Back UD Mills Connection Length O.D. WINDOW MILL 4'/: REG -P X MILL 2.25 8.5 NEW LOWER WATERMELON MILL 4'% REG -P X 4'/z REG -B 5.5 8.5 FLEX JOINT 4'/: REG -P X 4'/ REG -B 9.0 6.375 STRING MILL 4'/z REG -P X 4'/ REG -B 5.5 8.5 FLOAT SUB 4'/" IF -B X 4'/z" REG -B 3.0 6.375 30'ts-HWDP 4 %' XH-B X 4 %° REG -P 900' 6.5 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA's SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY! FAF Page 17 Revision 0 August, 2018 H llil.q .Alaska, LIA: 14.0 Drill 8-1/2" Hole Section 14.1 PIU 8-1/2" rotary steerable directional drilling assy. 14.2 Ensure BHA Components have been inspected previously. M -35L1 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 350-425gpm. 14.6 Must keep up with 3 deg/100 DLS in the build section of the wellbore. 14.7 Primary bit will be the Baker Hughes 8-1/2" Kymera bit. Ensure to have a back up bit available on location. 14.8 TIH to window. Shallow test MWD on trip in. 14.9 TIH through window, ensure Baker D service rep on rig floor during this operation. • Do not rotate string while bit is across face of Whipstock. 14.10 Drill 8-1/2" hole to 16,532' MD using motor assembly. ' • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain API fluid loss < 6. • Take MWD surveys every stand drilled. 14.11 Hilcorp Geologists will follow LWD log closely to determine exact TD. 14.12 At TD pump a sweep and a marker to be used as a fluid caliper to determine annulus volume for cement calculations. CBU, and pull a wiper trip back to the window. 14.13 TOH with drilling assembly, handle BHA as appropriate. Page 18 Revision 0 August, 2018 5 M -35L1 Drilling Procedure Rev 0 15.0 Retrieve Whipstock and Run Seal Bore Diverter 15.1 Have Baker Hughes rep on the rig floor for all these operations. 15.2 PU Baker Hughes fixed lug retrieving tool. 15.3 TIH to top of whipstock and bring on pumps. 15.4 Wash down past retrieval slot. Turn tool 90 degrees and wash back up past retrieval slot. Repeat this operation until we have made one full rotation. 15.5 Kill pumps and slack of past retrieval slot. PU easy looking for indication of hooking slot. If not successful rotate tool, 90 degrees and try again until we have made one full rotation. 15.6 If we have no success, rotate the hook 45 degrees and try again. If not successful on first attempt repeat o era ion again in 90 degree increments until we have made one full rotation. 1Once hooked, pull 40k to release whiptock. Pew I ,,, yw- 15.8 Once free DO NOT SLACK OFF. u easy, set easy in and out of slips. 15.9 Pull to surface and lay down whipstock. • Handle carefully because there could be sharp edges. 15.10 PU Baker Hughes RAM seal bore diverter, production anchor, and bullet seal assembly with FJD running tool RIH as per Baker's recommendations. 15.11 Seal bore diverter should be spaced out and oriented relative to window 15.12 Set down on MLZXP profile and release from FJD running tool 15.13 After releasing tool, circulate a bottoms up and condition mud. Mix viscous weighted pill and balance it across the SBD. • The idea behind this pill is to keep debris and cement out of the profile. 15.14 POOH and lay down FJD running tool 15.15 Prep floor for running liner Page 19 Revision 0 August, 2018 H Hilmr10 Alaka, u.c 16.0 Run 7" Production Liner M -35L1 Drilling Procedure Rev 0 16.1 Verify ID of everything going through the table is less than 7.5" OD 16.2 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. 16.3 P/U shoe joint, visually verify no debris inside joint. 16.4 Continue M/U & thread locking shoe track assy consisting of: • (1) Shoe joint w/ shoe bucked on & threadlocked (coupling also thread locked). • (1) Baker locked joint. • (1) Joint with float collar bucked on pin end & threadlocked (coupling also thread locked). • (1) Joint with landing collar bucked up. • No centralizers to be installed on shoe joint, FC joint, and LC joint. • Install centralizers, one per joint to +/- 9,700' TMD, and leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe & FC. 16.5 Continue running 7" production liner • Fill casing while running using fill up line on rig floor. • Use "API Modified" thread compound. Dope pin end only w/ paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 7" DWC/C SCC M/U torques Casing OD Minimum Maximum Yield Torque 7" 17,100 ft -lbs 19,800 ft -lbs 22,500 ft -lbs Page 20 Revision 0 August, 2018 Connection Type: DWC/C-SC Casing (7 5W SC DD) M-351.1 Drilling Procedure Rev 0 Technical Specifications Size(O.D.): Weight (Wail): Grade: 7 in 26.00 Wit (0.362 in) L-80 7.500 Material L-80 Grade 80,000 Minimum Yield Strength (psi.) 95,000 Minimum Ultimate Strength (psi.) 6,600 Pipe Dimensions 7.000 Nominal Pipe Body O.D. (in.) 6.276 Nominal Pipe Body I.D. (in.) 0.362 Nominal Wall Thickness (in.) 26.00 Nominal Weight (lbs./ft.) 25.69 Plain End Weight (Ibs./ft.) 7.549 Nominal Pipe Body Area (sq. in.) 7.500 Pipe Body Performance Properties 604,000 Minimum Pipe Body Yield Strength (lbs.) 5,410 Minimum Collapse Pressure (psi.) 7,240 Minimum Internal Yield Pressure (psi.) 6,600 Hydrostatic Test Pressure (psi.) 7.500 Connection Dimensions Connection O.D. (in.) 6 Connection I.D. (in.) 6.151 Connection Drift Diameter (in.) 4.50 Make-up Loss (in.) 7.106 Critical Area (sq. in.) 94.1 Joint Efficiency (%) Connection Performance Properties 569,000 Joint Strength (Ibs.) 15,630 Reference String Length (ft)1.4 Design Factor 641,000 API Joint Strength (lbs.) 604,000 Compression Rating (Ibs.) 5,410 API Collapse Pressure Rating (psi.) 6,980 API Internal Pressure Resistance (psi.) 24.7 Maximum Uniaxial Bend Rating [degrees/100 ft] Approximated Field End Torque Values 17,100 Minimum Final Torque (ft: lbs.) 19,800 Maximum Final Torque (ft.-Ibs.) 22,500 Connection Yield Torque (ft. -lbs.) USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston. TX 77041 Phone: 713479-3200 Fax: 713479.3234 E-mail: VAhtUSAsales@vam-usa com For detailed Information on performance properties, refer to DWC Connection Data Notes on following page(s) Connection specifications within the control of VAM USA were correct as of the date printed. Specifications are subject to change without notice. Certain Connection specifications are dependent on the mechanical properties of the pipe. Mechanical properties of mill proprietary M grades were obtained from mill publications and are subject to change. Properties of mill proprietary grades should be confirmed with Ne grades Users are advised to obtain current connection specifications and verify pipe mechanical properties for each application. All information is provided by VAM USA or its affiliates at users sole risk, without liability for loss, damage or injury resulting from the use thereof; and on an 'AS IS' basis without warranty or representation of any kind. whether express or implied, including without limitation any warranty of merchantability, fitness for purpose or completeness. This document and its contents are subieect to change without rotice. In no event shall VAM USA or its affiliates be responsible for any indirect. special, incidental, punitive. exemplary or consequential loss or damage (including without limitation, loss of use. loss of ba am, loss of revenue, profit or anticipated profit) however caused or arising, and whether such losses a damages were foreseeable or VAM USA or its affiliates was advised of the possibility of such damages. Page 21 Revision 0 August. 2018 �r J� �r If H llikorp .Ala_eka, 1.1.1: M-351.1 Drilling Procedure Rev 0 16.7 Before picking up Baker RAM hanger count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.8 M/U Baker RAM hanger. 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. 16.9 RIH one stand and circulate a minimum of one liner volume. Note weight of liner. 16.10 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. 16.11 M/U top drive and fill pipe while lowering string every 10 stands. 16.12 Set slowly in and pull slowly out of slips. 16.13 Circulate 1-1/2 drill pipe and liner volume at 8-1/2" 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. 16.14 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 16.15 Continue to fill the string every 10 joints while running liner in open hole. 16.16 P/U the cmt stand and tag bottom with the liner shoe. P/U 2' off bottom. Note slack -off and pick-up weights. 16.17 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. cam' 16.18 Reciprocate & rotate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 22 Revision 0 August, 2018 N nilmrp .Alaska, Lr.0 17.0 Cement 7" Production Liner M-351.1 Drilling Procedure Rev 0 • Cement will be mixed using batch mixer to ensure consistent density 17.1 Hold a pre -job safety meeting over the upcoming curt operations. 17.2 Attempt to reciprocate the casing during curt operations until hole gets sticky. 17.3 Pump 15 bbls 12.5 ppg spacer. 17.4 Test surface cmt lines to 4500 psi. 17.5 Prior to pumping lead cement, drop first "lead" dart. 17.6 Mix and pump 200 bbls of 15.3 ppg class "G" cmt per below recipe with 0.5 lb/bbl loss circulation fiber. Ensure cmt is pumped at designed weight. Job is designed to pump 25% OH excess but if fluid caliper dictates otherwise we may increase excess volumes. Cement volume is designed to bring cement up to 9-5/8" window. Est TOC 9621' 17.7 Displacement fluid will be drilling mud. Cement Calculations 8-1/2" OH x 7" Liner: (16532'— 9621') x 0.02259 x 1.25 = 195 bbls Shoe Track: 80' x 0.03715 = 3 bbls Total Volume (bbls): 195 + 3 = —200 bbls Total Volume (ft3): 200 bbls x 5.615 ft3/bbl = 112 ft Total Volume (sx): 1123 ft3 / 1.34 ft3/sk = 38 sx Page 23 Revision 0 August, 2018 H lliknrp .A64., r.1.0 Slurry Information: M-351.1 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 Be 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 17.8 Drop second "follow" dart and displace with drilling mud. 17.9 Pump cement at max rate of 8 bbl/min. Reduce pump rate to 3 bpm prior to latching each 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 17.10 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. 17.11 Slack off total liner weight plus 40k and land RAM hanger into SBD. 17.12 Do not overdisplace by more than %2 shoe track (-1 bbls). Shoe track volume is 2 bbls. 17.13 Pressure up to 4200 psi to release the running tool (HRD-E) from the liner 17.14 Bleed pressure to zero to check float equipment. 17.15 P/ J, verify setting tool is released Page 24 Revision 0 August, 2018 H I lily nrp Ua..ka. 1.1.1'. M -35L1 Drilling Procedure Rev 0 17.16 Pressure up drill pipe to 500 psi and pick up to remove the packoff bushing from the 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). 17.17 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 junction. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 17.18 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. 17.19 Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 17.20 POOH, standing back DP. Ensure to report the following on Wellez: • Pre flush type, volume (bbis) & 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 duringjob, 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 mmversahilcorn.com Page 25 Revision 0 August, 2018 U lhlc,rp AI.A., r.1.0 18.0 Install RAM junction equipment M -35L1 Drilling Procedure Rev 0 • The next several steps are cased hole work to install the parts and pieces required for the Level 5 RAM junction. More detail will be provided by the Baker Hughes engineering team, this is merely for reference. 18.1 RIH with RAM lateral diverter using Hydraulic GS spear and set inside RAM hanger. 8.2 RIH and perforate 7" lateral as per separate completion RIH and set signature F packer, with SBE inside 7" upper lateral liner for pressure isolation • Signature F packer to be located 400' below top of landed RAM hanger. A no-go locating on the RAM hanger will be used for exact spaceout. 18.4 Retrieve RAM lateral using Hydraulic GS spear 18.5 RIH with contingency seal assembly, stab into RAM SBD, blow out mainbore pump out plug in signature F packer 18.6 RIH with upper completion, including RAM DSM, selective re-entry tool, SCAR production packer. Land upper completion and RAM DSM, each leg of the DSM will be guided into the respective sealbores. 18.7 Drop ball for BSC -R HSAK 18.8 Pressure up string to set SCAR packer, pressure up against setting ball. POOH and L/D BSC -R running tool assembly. Page 26 Revision 0 August, 2018 H nils®,p MaA., LLC 19.0 Run Completion Assembly M -35L1 Drilling Procedure Rev 0 19.1 Run ESP and tubing completion assembly as per separate Approved Completion Sundry. 20.0 RD 20.1 Install BPV in wellhead. RILDs. 20.2 ND BOPE, NU tree, test void 20.3 Rig Down Page 27 Revision 0 August, 2018 H Ililrorp AWA., 1.11.11; 21.0 BOP Schematic M -35L1 Drilling Procedure Rev 0 R, Floor Page 28 Revision 0 August, 2018 22.0 Wellhead Schematic h1/16 w 4-1/+6 SM GING NMN . 31 = I}6/e X Fe/6 B/Y A L7 16 DBL 0 Y PRP -� GeX16 I1N4CER, U -E 103/4 X 13-3/B BC BOX BIN X 14.000 OD 4TP1 U BOOL TOP 16-8/6 Oft 0 SM PREP GING NN1' 3 E 20 X 16 SC BOX BWX 16.760 00 471 M VOX TOP 26 m (.760 BML) X66 PrE 16 OD GS•G f}3/B CO CABNG 0-3/8 m GING 4-1/2 GG ry - DRUMS .. R wsa — M -35L1 Drilling Procedure Rev 0 =-LGlB WINECfiR M b/e 3G �-MIA3110IA-AleeC WLF RO.6NG 1001 -� 2-1/16 3Y ^1\0-33/44 U is NX 1N13/8 J X11 B-�11.I1 RE511e M COWMENML X 13-3/8 X 1-10 '61 31 { d- 7-3150 2 Page 29 Revision 0 August, 2018 HILCORP ALASKA STEELHEAD PLATFORM HO -32101 �� uer<5 11BIf3: n r 6Y HOLO- nl4lmGIiM }1/e sN L4EGIIp1 }3/e 9N RGTAeNG PLMIGE =-LGlB WINECfiR M b/e 3G �-MIA3110IA-AleeC WLF RO.6NG 1001 -� 2-1/16 3Y ^1\0-33/44 U is NX 1N13/8 J X11 B-�11.I1 RE511e M COWMENML X 13-3/8 X 1-10 '61 31 { d- 7-3150 2 Page 29 Revision 0 August, 2018 H ❑ihoq, .A., LLC. 23.0 Days vs Depth 0 100 2000 300 4000 500 6000 z r 7000 v � 5000 m m u f 900 1000 1100 1200 13000 14000 1500 M-351.1 Drilling Procedure Rev 0 Steelhead Offset Wells DaysysDepth III IIiII —M-21(2011) —M-11 (2010-2011) —M-18 (2006-2009) —M-17 (2007) —M-31 (1394) —M-27 (1490) —M-27 (1990) —M-28 (1990) —M-29 (1991) —M-30 (1992) —M-34 Han 0 10 20 30 40 s0 60 70 Dap Page 30 Revision 0 August, 2018 0 Ililcorp AWkn, IA.1: 24.0 Geo-Prog 812012018 12:30 M -35L1 Drilling Procedure Rev 0 MCARTHUR RIVER Alaska KB 160.0 0.0 0187.0 Based on subsurface evaluation TOP NA "" ` TVD TVDSS NORTHING EASTIM (FT) (F,� KOP Coal 39 Coal 9,572 00 6,650.00 -8,490.00 H1X_FW Sand/Conglomerate Oil Sand 10,124.25 9,073.00 -8,913.44 Coal 59 Coal 10,180.48 9,096.00 -8946.22 HTKE_FW Sand /Conglomerate Oil Sand 10,199.34 9,117.00 -8,956.75 HK2T Sand/Conglomerate Oil Sand 10,274.51 9,155.00 -8,995.99 HK3T 10,716.23 9,304.00 -9,143.71 HK4T 10,98061 9,369.00 -9,209.37 HKST 11496.71 9,498.00 -9337.55 HK6T 12,079.25 9,64200 -9482.22 HK7T 12,479.44 9,740.00 -9,580.29 WF1 Sand/Conglomerate Oil Sand 1260383 9,766.00 -9,605.75 2,499,010.70 213,847.00 WF2 Sand/Conglomerate Oil Sand 13,45564 9,905.00 -974549 2498,192.80 213,384.40 WF2 Sand lConglomerate Oil Sand 15,698.42 9,919.00 -9,758.72 2,496,27470 212,251.30 TD y Steerable, Gamma Res with Triple combo Mad Pass at TD run upon completion of the well to validate wellbore tortuosity and postion. Page 31 Revision 0 August, 2018 • i n Itil »,p .Alaska, LLC 25.0 Anticipated Drilling Hazards M -35L1 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: H2S is not present in this hole section. No abnormal temperatures or pressures are present in this hole section. Page 32 Revision 0 August, 2018 U 11ii.gi Alaska, LLC 26.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: M -35L1 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 33 Revision 0 August, 2018 27.0 Choke Manifold Schematic TO GAS BUSTER TO DERRICK VENT TO SHALE SHAKERS M-351-1 Drilling Procedure Rev 0 * ALL VALVES IN FLOW PATH ARE 0-1/76' $000 PSI CAMERON GATE TYPE Page 34 Revision 0 August, 2018 SECTION AA K uikc q AMaka, 1.1.1: 28.0 Casing Design Information Page 35 Calculation & Casing Design Factors Steelhead Platform DATE: 8-20.2018 WELL: M -35L1 FIELD: McArthur River DESIGN BY:Monty M Myers Design Criteria: Hole Size 8-1/2" Hole Size Hole Size M-351.1 Drilling Procedure Rev 0 Mud Density: 9.2 ppg Mud Density: Mud Density: Drilling Mode See attached MASP determination and calculation MASP (8-112" hole): 2292 psi Production Mode MASP (Sec 2,3,4): 4443 psi Collapse Calculation: Section Calculation All Max MW gradient external stress (9.2 ppg) and the casing e%ecuated for the internal stres Casing Section 2 3 Calculation/Specification 1 Casing OD T' Top (MD) 9,621 Top (TVD) 8,693 Bottom (MD) 16,532 Bottom (TVD) 9,810 Length 6,911 Weight (ppf) _ 26 Grade L-80 Connection DWC/C SC _ Weight w/o Bouyancy Factor (lbs) _ 1 179,686 Min strength Tension (1000 lbs) 604 Worst Case Safety Factor (Tension) Collapse Pressure at bottom (Psi) 4,658 Collapse Resistance w/o tension (Psi) 5,410 Worst Case Safety Factor (Collapse) 1.16 MASP (psi) 2,292 Minimum Yield (psi) 6,980 Worst case safety factor (Burst) 3.05 1 Revision 0 August, 2018 t/ 29.0 8-1/2" Hole Section MASP M-351.1 Drilling Procedure Rev 0 Maximum Anticipated Surface Pressure Calculation Hill 8-1/2" Hole Section M -35u McArthur River MD ND Planned Top: 9,621 8,693 Planned TD: 16,532 9,810 Anticinated Fnnnations and Pressures - Formation TVD Est Pressure Oil/Gas/Wet PPG Grad HKT 9,396 3946 Oil/Water &1 0.42 WF1 9,722 4275 Oil/Water 8.5 0.44 WF2 9,810 4400 oil/Water 8.6 0.45 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date M-31 9.8-10.3 7,800 10,500 1994 W27 9.6-9.8 4,235 10,500 1990 W28 9.4-9.6 4,610 10,500 1990 W29 9.5-9.7 3,770 10,500 1991 M-30 9.4-9.9 4,247 10,500 1992 Assumptions: L Fracture gradient at 9,621' MD / 8,688' TVD is estimated at 0.832 psi / ft based on field test data. 2. Maximum planned mud density for the hole section is 9.2 ppg. 3. Calculations assume "Unknown" reservoir contains 100% gas (worst case). 4. Calculations assume worst case event is 2/3 evacuation of wellbore togas. Remaining 1/3 volume in wellbore remains drilling fluid density. Fracture Pressure at shoe considering a full column of gas from shoe to surface: 8,693 (ft) x 0.832(psi/ft)= 7233 7233(psi)-[0.1(psi/ft)R8693(ft))=6364psi MASP from pore pressure (unknown gas sand atTD, at 15 ppg (0.442 psi/ft) 10,053(ft) x 0.442(psi/ft)= 4443 psi 4443(psi)-[(2/3)'0.1(psi/ft)•10,053(ft))-[(1/3)•0.442(psi/ft)'10,053(ft))= 2292 psi - Summary: L MASP while drilling 8-1/2" hole is governed by pore pressure minus 2/3 of wellbore evacuated to gas (remaining 1/3 remains 9.2 ppg drilling fluid) Page 36 Revision 0 August, 2018 M-351.1 Drilling Procedure Rev 0 30.0 Plot (NAD 27) (Governmental Sections) •k•B 0'1. _ -- �__ C,ftRYtO�p l— _ ♦� V^-f.]Y_I I , \\ pL�L//TM; Of 91. 1i699ta ��/ ` • 14,aveK BD Bei' _ - •' \1 � \ 1G21 B!1. , \\ pL�L//TM; I TRADING,',v"" II eK \, \I \\► "sm 11 \ 1 • „ I I 1 �♦, 1 i ADL017594 \\ 1 M-740 a.. /(siV BHL I I i 1 IGS •• I I_ - --------� J_– Mr r • / �� 1 M -351 -I -TPI // o �� \t1� est /�� •�OB , 1 1 , I I • • it;yt eHL � ,° � I 1 064201a l 0 / � 103aBK / /1• / I / I R_M-760W1 L I // 62610 FI --W76 BHL i//Wlb ��+ 0• r�y�r�glgtpl Bi00t3o24HLl 1 D/7BKI DD1 Bta • r,M9 ' -' / _�� I„ ✓ kl.t7 ,fir /' /' °�'•'4 a aBK � 91. 1i699ta ��/ ` • 14,aveK BD Bei' _ - •' \1 � \ 1G21 B!1. .�CsOBBK Der} \ \r um eta ` PL Mfi19a 62fiRO BHL D BHL • Gt2Ap2 / nz7 /P�{M,.98eK• Jam' r•"720 eK Legend ----"a ��• 4 'rr r/, –''• • M -35L1 SHL • Otner Somace Hae Locawn 7579 1�' {tits Bfi//' X M-35Lt_TPH • Omer Boeom Mae Location sAD1-018729 --- -i- M-35L7_BHL --- wen Paths i 11' 1 Daz eH. 1 Trading Bay Unit �°° °°° ''°° 2.°°° 1.1 Feet M-35 Alaska State Plane Zone 4. NAD27 A llil , kla.La. 1.11. wp 09 Map Date: 9202018 Page 37 Revision 0 August, 2018 , \\ pL�L//TM; I i I Jia1e+ "sm 11 \ 48D9i1�•' \ , \ [L07BD9ta _�Mp2BK \ Oo7emz ge.– \ .�CsOBBK Der} \ \r um eta ` PL Mfi19a 62fiRO BHL D BHL • Gt2Ap2 / nz7 /P�{M,.98eK• Jam' r•"720 eK Legend ----"a ��• 4 'rr r/, –''• • M -35L1 SHL • Otner Somace Hae Locawn 7579 1�' {tits Bfi//' X M-35Lt_TPH • Omer Boeom Mae Location sAD1-018729 --- -i- M-35L7_BHL --- wen Paths i 11' 1 Daz eH. 1 Trading Bay Unit �°° °°° ''°° 2.°°° 1.1 Feet M-35 Alaska State Plane Zone 4. NAD27 A llil , kla.La. 1.11. wp 09 Map Date: 9202018 Page 37 Revision 0 August, 2018 n Ilil.rp Alaska, LI.0 M -35L1 Drilling Procedure Rev 0 31.0 Slot Diagram (As Built) (NAD 27) 29 j 2e SECTION LINE NOT TO SCALE (NTS) 32 33 1 (PROTRACTED) N: 2500506.888' E: 213=54.958' NOTES 1. BASIS OF HORIZONTAL CONTROL: NAD83 US FEET POSITION (EPOCH 2010) AND VERTICAL CONTROL (NAVD68) IS AN OPUS SOLUTION FROM NGS STATIONS KEN5, AC51 AND ANC2 TO ESTABLISH CP -1. THE ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE: N = 2488311.366 — E = 1354193 305 ELEV. = 150.436 (NAVD88) 2. SECTION LINES SHOWN ARE EXTENSIONS OF PROTRACTED VALUES. 3. DATUM TRANSFORMATIONS (NAD83 ASPZ4 TO NAD27 ASPZ4) WERE DONE USING CORPSCON SOFTWARE VERSION 6.0.1. `,\\\\\I\11 '1.' Ari �xi iH 14:1 i sN+w 1.pvc 1 _+ +no I SCALE Ar U..�.J' o x Fa 4481111U\�\� FEET IN1XfLIIFnI WI,rFn/WMrNG/iffi,W 'e4.+uwra..arerr.4w+ S51'FN4 S) - MILLUUNr ALH3Mr LLL. STEELHEAD PLATFORM WELLS COOK INLET ALASKA AS BUILT SURFACE LOCATION"' NAD 27 ZO CENTER LEG t1-1 Cml0:1M ILVM wxr 'aro LAT: fiO'49'S4.939R4 I °X3 1 538' FWL (NTS} LON: 151' 36' 8.88514 citrfWLlNTS LEG A -t N. N 499.259' 4 +' E:214167 !n wr y 13W FNL (NISI 106Z FNL (NTS) W �..wn ASSUILT WELL LOCATIONS +4 a Q SECTION 33 T914 R13W U CENTER LEC A-1 CENTER LEG Lit N 71\ LAT: 80' 49 54370'N O LON', 151' 35' 62SM'' LON: 15113(75415" ti N 249W7IST N. 2499429384' N E 214238.13? ASP ZONE 4 NAD 21 ASP ZONE 4 NAD 27 2 CENTER LEG A-2 LAT: 60' 49' 53 OWN 2 LON'. 151.3=' 67n'W NOTES 1. BASIS OF HORIZONTAL CONTROL: NAD83 US FEET POSITION (EPOCH 2010) AND VERTICAL CONTROL (NAVD68) IS AN OPUS SOLUTION FROM NGS STATIONS KEN5, AC51 AND ANC2 TO ESTABLISH CP -1. THE ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE: N = 2488311.366 — E = 1354193 305 ELEV. = 150.436 (NAVD88) 2. SECTION LINES SHOWN ARE EXTENSIONS OF PROTRACTED VALUES. 3. DATUM TRANSFORMATIONS (NAD83 ASPZ4 TO NAD27 ASPZ4) WERE DONE USING CORPSCON SOFTWARE VERSION 6.0.1. `,\\\\\I\11 '1.' Ari �xi iH 14:1 i sN+w 1.pvc 1 _+ +no I SCALE Ar U..�.J' o x Fa 4481111U\�\� FEET IN1XfLIIFnI WI,rFn/WMrNG/iffi,W 'e4.+uwra..arerr.4w+ Flilc i1mka, LIA: F' - MILLUUNr ALH3Mr LLL. STEELHEAD PLATFORM WELLS COOK INLET ALASKA AS BUILT SURFACE LOCATION"' NAD 27 ZO Cml0:1M ILVM u PROTRACTED SEC. 33 T09N R13W SEWARD MERIDIAN, ALASKA I °X3 1 BM FWL INTS) citrfWLlNTS LEG A -t a 4 L) ,,.,� STEELHEAD PLATFORM .N LEG &2 �..wn ASSUILT WELL LOCATIONS +4 a SECTION 33 T914 R13W CENTER LEC A-1 CENTER LEG Lit LAT: 69' 49' 54213'}1 LAT: 80' 49 54370'N LON', 151' 35' 62SM'' LON: 15113(75415" N 249W7IST N. 2499429384' E7 2140961 W E 214238.13? ASP ZONE 4 NAD 21 ASP ZONE 4 NAD 27 CENTER LEG A-2 LAT: 60' 49' 53 OWN LON'. 151.3=' 67n'W N: 24S9357A6.T 544' FWL INT$) E: 214169615" ASP ZONE 4 NAD 27 LEG A-2 NOTES 1. BASIS OF HORIZONTAL CONTROL: NAD83 US FEET POSITION (EPOCH 2010) AND VERTICAL CONTROL (NAVD68) IS AN OPUS SOLUTION FROM NGS STATIONS KEN5, AC51 AND ANC2 TO ESTABLISH CP -1. THE ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE: N = 2488311.366 — E = 1354193 305 ELEV. = 150.436 (NAVD88) 2. SECTION LINES SHOWN ARE EXTENSIONS OF PROTRACTED VALUES. 3. DATUM TRANSFORMATIONS (NAD83 ASPZ4 TO NAD27 ASPZ4) WERE DONE USING CORPSCON SOFTWARE VERSION 6.0.1. `,\\\\\I\11 '1.' Ari �xi iH 14:1 i sN+w 1.pvc 1 _+ +no I SCALE Ar U..�.J' o x Fa 4481111U\�\� FEET IN1XfLIIFnI WI,rFn/WMrNG/iffi,W 'e4.+uwra..arerr.4w+ Flilc i1mka, LIA: F' - MILLUUNr ALH3Mr LLL. STEELHEAD PLATFORM WELLS COOK INLET ALASKA AS BUILT SURFACE LOCATION"' NAD 27 nwasX-..m Cml0:1M ILVM .XM M. I]A PROTRACTED SEC. 33 T09N R13W SEWARD MERIDIAN, ALASKA I °X3 1 Page 38 Revision 0 August, 2018 H I I i h oqi . Vwka, LLC M-351-1 Drilling Procedure Rev 0 Page 39 Revision 0 August, 2018 Center Leg A-2 2499357.463 214169.815 NAD 27 60' 49' 53.544" -151' 36'6.777" Slot # Well # Northing Easting Latitude Longitude 60' 49'53.478" -151' 36'6.776" Center Leg A-1 2499427.187 2 214098.135 60°49'54.213" -151°36'8.257" _ 60' 49' 53.495" 1 M-13 2499426.829 3 214091.116 60°49'54.208" -151°36'8.398" 60' 49'53.537" 2 M-20 2499431.313 Empty 214092.688 60°49'54.253" 214163.970 -151°36'8.369" 60' 49'53.578" -151' 36'6.897" 3 M-12 2499433.800 Empty 214096.804 60°49'54.278" 214167.569 -151°36'8.287" 60' 49'53.610" -151' 36'6.826" 4 M-16RD 2499433.035 214101.478 60' 49' 54.272" 214172.261 -151° 36'8.192" 60' 49'53.613" -151' 36'6.731" 5 Empty 2499429.409 Empty 214104.608 60' 49' 54.237" 214176.254 -1510 36'8.128" 60' 49'53.579" Leg A-1 6 M-19RD 2499424.654 Empty 214104.770 60"49'54.190" 214176.836 -151°36'8.122" 60' 49'53.533" -151' 36'6.635" 7 M-10 2499420.723 Empty 214101.288 60'49'54.150" 214173.849 -151'36'8.190" 60'49'53.490" -151' 36'6.693" 8 M-15 2499420.018 Empty 214097.005 60`49'54.142" 214167.374 -151'36'8.276" 60' 49'53.528" -151'36'6.826" 9 M-17 2499421.994 Empty 214093.178 60'49'54.161" 214169.715 -151°36'8.354" 60' 49'53.578" -151' 36'6.781" 10 Empty 2499430.107 214098.609 60' 49' 54.242" -151' 36'8.249" 11 M-14RD 2499425.271 214100.854 60' 49' 54.195" -151' 36' 8.201-- .201"12 12 M-11 2499426.184 214094.941 60' 49' 54.203" -151' 36'8.321" Page 39 Revision 0 August, 2018 Center Leg A-2 2499357.463 214169.815 60' 49' 53.544" -151' 36'6.777" 1 Empty 2499350.776 214169.687 60' 49'53.478" -151' 36'6.776" 2 Empty 2499352.552 214165.228 _ 60' 49' 53.495" -151' 36'6.867" NAD 27 3 Empty 2499356.900 214163.194 60' 49'53.537" -151' 36'6.910" llilrorp Alaska. LLC 4 Empty 2499361.062 214163.970 SEWARD MERIDIAN, ALASKA 60' 49'53.578" -151' 36'6.897" 5 Empty 2499364.241 214167.569 60' 49'53.610" -151' 36'6.826" Leg A-2 6 Empty 2499364.364 214172.261 60' 49'53.613" -151' 36'6.731" 7 Empty 2499360.898 214176.254 60' 49'53.579" -151' 36'6.649" 8 Empty 2499356.164 214176.836 60' 49'53.533" -151' 36'6.635" 9 Empty 2499351.877 214173.849 60'49'53.490" -151' 36'6.693" 10 Empty 2499355.862 214167.374 60' 49'53.528" -151'36'6.826" 11 Empty 2499360.905 214169.715 60' 49'53.578" -151' 36'6.781" 12 Empty 1 2499356.347 1 214172.9131 60'49'53.534" 1 -151'36'6.714" Page 39 Revision 0 August, 2018 PLATFORM WELLS - COOKINLET NLETLETHEAD ALASKA AS BUILT SURFACE LOCATION _ NAD 27 PROTRACTED SEC. 33 T09N R1 3W ... ..-..._..�s.v...�o llilrorp Alaska. LLC r� Z"3 SEWARD MERIDIAN, ALASKA Page 39 Revision 0 August, 2018 H ffil rp .Almku, LK 32.0 Directional Program (wp09) M -35L1 Drilling Procedure Rev 0 Page 40 Revision 0 August, 2018 I Hilcorp Alaska LLC sak Location: Cook Inlet Alaa (Offshore) 7Slot: slot #A2-12 UC7HES Field: McArthur liver Field Well: M-3511 ace canpany Plot reference wellpath is M -35L1 WP09 Grid System: NAD27 / TM Alaska SP, Zone 4 (5004), US feet True vertical depths are referenced to Actual Datum (RKB) North Reference: True north p/dnr7eO Measured depths are referenced to Actual Datum (RKB) Scale: True distance neafOp Actual Datum (RKB) to mean sea level: 160 feet mean sea level to Mud line At Slot: slot #A2-12.: 0 feet Coordinates are in feet referenced to Slot Depths are in feet Created by: ulricard on 2018-08-16 Database: WA ANC Defn Of N1 Q 01 -1 Well Profile Data `o Design Comment MD ft n- nc Az TVD ftLocal N ft Local E ft DLS °/100ft VS ft Tie On to M-35 9548.66 27.810 198.770 8628.89 2145.25 629.64 0.28 2181.54 Planned top of WS 9621.00 27.800 198.720 8692.88 2113.30 618.80 0.04 2148.33 End of 3D Arc 9638.00 29.580 200.790 8707.79 2105.62 616.04 11.99 2140.28 End of Tangent 9658.00 29.580 200.790 8725.19 2096.39 612.53 0.00 2130.50 End of 3D Arc 10578.68 75.620 200.440 9269.46 1429.84 362.55 5.00 1426.34 End of Tangent 12381.99 75.620 200.440 9717.32 -206.99 -247.48 0.00 -301.02 End of 3D Arc 12688.81 80.630 208.330 9780.53 -480.06 -371.47 3.00 -599.96 End of Tangent 14205.17 80.630 208.330 10027.41 1796.99 -1081.46 0.00 -2095.99 End of 3D Arc 14485.17 89.000 209.000 10052.69 2041.441215.11 3.00 -2374.59 End of 3D Arc J 14788.68 97.437 205.567 10035.66 2310.46 1353.91 3.00 2677.16 End of Tangent J 16532.16 97.437 205.567 9810.00 -3870.00 -2100.00 0.00 -4402.88 c 1 1250 L CL 500 Wo U 1= i 625 H 7500 p/dnr7eO neafOp Of N1 Q 01 n o S 8750 `o v _ /T w J5L7 w 4 w > < 10000 7 6 � o m toe 11250 1250g75n -"nn -171n _oSnn -t15n Azimuth (ft) 50 -1500 -750 0 �� S.1e1 inc -2500 N, 0.00 E Tin pasn �°i 9P�oa`CfiOn F zzso t 500 75G ?-12 0 750 -1500 -3000 1 4500 1 Page 1 oB Planned Wellpath Geographic Report - including Position Uncertainty 0811611B M 13:43 using WelArcMlec15.1 NAD27I TM Alaska BE, Zone 4 5004 , US feet Hilcorp Alaska, LLC True Cook Inlet, Alaska (Offshore) D.999993 MCAdtlur Rivar Field 1.4011 STEELH EAD oldru n Slot s1ot#A2-12 Actual Delum RKB M -35L1 Actual Datum RKB M -35L1 mean sea level . M-3511 WP09 160.006 0811512018 160 OD B M-35 two at 9648 66 MD 16000 it Ulricard E 0.00 R Minimum curvature N 0.00 B Magnetic North is 16 30 degrees East of True Norm 2400° 2 00 Std Dev included WA ANC Defn 000 f1 -113].55 54594 214172.91 249935635 60°495363P'N 151°36'08.714"W mesa 0.00 000 213654.96 2500506.90 1 W-D)04]36"N 151'36'17,72]"W 0.00 0.00 213640.71 MD514.08 W -50'04803"N 151°36'18,018"0 Stan MID End MD positional Uncertainty M0,10 L., Name i 3 --on, Wellbore 0.00 2430.00 Gyrodele standard- Drop gyro or Multi -diol_ G ODansG a�0-2430'� M-35 243000 9548.88HI OnTrak(MagCADtlFR1 SAG) BHGEOTK MWD+CA*_MSA-2516-10559, _ 14-35 _ 954866 16532.111,HI OnTrak Ma CAD+IFR] SAG _ M-3511 - - - arm, I Diameter Start MD End NO lrdrr�al Start TED End TVD Stan NIS Start EIV,` End NIS End EXV W,Ilb.,a 28in Cantlutlor _-1 0 00 460 00 460.00 0.00 459.99 0 00 0 00 -2 67 046 M-35 RSin Open Hole _ ' 000 250000 250000 000 _ 247825 _ 0.00 0.00 160]] -8978 M-35 1 - 85'hDoi Hole 962100 1655449 693349 8692.88 NIA 211330 61880 NIA NIA M-3511 7h Citing Protluction 9471 00 16532.16 ]051.16 0560.13 9810.00 2179.43 64127 -387000 -210000 M-3511 Target Name MID TVID North East Grid East Odd North Latitude Longitude She,. Comment 77SL1 WPO)Heel 0.00 9]1]50 -20.05 -247.23 _ 213920 70 _ 249915540 60"49 of 4. 5"N 151°36'11]01"W point M -35L1 WP076HL Tgt 0.00 9810.00 -3624.15 -22354) 211844 77 249558]95 60'40'15374"N 15136'51]94"W point hL35L1 WP36 CPIT t 0.00 1005300 -2041.4] _ -121494 21290851 _ 249734517 60"4933430"N 151'3631218"W point NO 0.00 Inclination 000 Azimuth 16641 WO 000 WDSS -16000 North 0.00 Earn 0.00 Grid East 214112 J1 Grad North 249935635 Estrada 60°49'53534"N Longitude _151"3606)14"W DES 0.00 Tiaolfacar 16641 Build Rate T... plate 0.00 000 Van Best 000 Major Sandi 000 Minor Semi 0.00 Vast Semi 0.00 Minor Aund comments 000 10000 023 16641 100,00 -60.00 0.20 0.05 21417295 2499356.15 160"4953.528"N 5'49'53532"N 151°36'06]13"W 0.23 14106 023 15641 -0.15 0-15 0.15 230 ]64'. 200.00 0.21 1]0.9] 1 20000 4000 -05] 0.12 214173 02 249935578 151°36 06.]12"W 003 12251 _ -002_ .044 127 026 230 25]58 30000 0.19 18224 30000 14000 -0.92 0.15 214173 E, 249935543 60.49'5152FN 151°3606711"W 0.04 -16.14 -0.02 _4.56 11 27 -073 035 0.33 260.59 40000 083 159.]5 39999 23099 1.00 0.27 214173 13 2499314.55 60°4953516"N x151°3606709"W 065 -46.)5 064 1249 -144 041 0.39 _ _2.30 230 _ 8190 50000 0.92 16408 49998 33998 -328 062 21417345 249935305 60°49'53.502"N'151°3606702"W 0.12 -15929 009 -5.0 048 044 2.31 80.67 60000 037 12324 59998 439.98 4.23 _ 1.11 21417391 249935209 60°49'53492"N 1151°36 06.692"W 068 45601 -055 _ 4084 -316 0.53 _ 0.49 231 ]654 70000 021 101 699.97 53997 444 156 21417436 2499351 87 60°49'53.490"N 06.664"W 019 533 -. 016_ -. -21]] 313 0.56 053 232 6903 800.00 039 82]9 ]999] 63997 -445 1.99 21417525 2499351.85 60°4953491"N 1151.3fi 1151°36'066]4"W 0.11 10,16 . 0.08 293 062 057 233 62.05 025 7582 8999] ]399] .4 .36 2.45 2141]5.25 249935193 60°4953491"N 1151°36'06655"W 005 50.16 1. -0.08 717 -263 066 0.61 2.34 5447 0000 _ 033 6103 999.9 03997 -4.17 2.91 21495]2 2499352.11 60.4953493"N 0.11 0,00 4EI _17,59 -223 065 2J5 0.12 110010 110000 033 7821 1099.9) -3.97 3.45 214176.26 249935230 60°4953495"N 1151°35'06655"W 1151"36'06645"W 0.10 1497 149 70 0111 1118 -1.80 _069 0,]3 088 2.36 4051 1200.00 0.1] 30.1] 1199.9) 10399 10399) 378 380 2149662 2499352,48 60-4953497 N lSt°36'O6.fi3]"W, 025 11 71 -0.16 -48.04 -146 OJfi 0]i 238 34.35 136D.00 033 72 55 129997 113997 357 4.15 2141]6.9] 249935260 60°4953499"N 151"36'05530"W 023 -9175 0.1642.48 _ --1.11 OJ9 �_ 0.74 2.39 2836 1400.00 0.33 69.15 1399 97 1239 97 -338 4.70 2141]].52 249935367 151"36'06619"W 002 -94.19 _-.-- 000 -3.50 -016 083 0,P _.. 2.41 23]] 1500.00 _082 358.62 1499.96 ll39.96 -256 495 2141)>>9 24993536] 60°49'53501"N 60°4953509"N 151°36'06.614"W 0.76 049 -]053 9.16 006 0.80_ 243 1890 1800.00 3.15 33472 159990 143990 064 3.76 21417668 249935690 60°4953.540"N 151°36'06638"W 2.42 _-31.]] -936 233 -23.90 238 088 0.63 244 1640 1700,00 j 649 329.87 1699.53 1539.53 8.01 -025 21417205 249936437 60°4953613"N 151°36'06719"W 336 10.75 _ 334 4.85 688 091 1 087 246 2473 160000 -__ _. 824 32].56 1]90.]0 1638,70 10.95 -6 93 21416 644 249937546 5°49'53]20"N 151"36'06.854"W 1.]] -4.49 1.]5 -2.31 1321 - 096 j 0,91 2.47 339) 1900.00 32686 169572 93572 3209 -1541 214158.29 2499380.80 60°4953.050"N 151°36'0.025"W 151 5]3 151 -0]0 20.59 100 f 096 249 3].30 200000 16 1189 327.82 199323 1835.22 47]5 -2543 _ 21414865 _ 2499404]1 60°4954004"N'151-36'0.4227 1.95 196 096 29.44 105 1.01 2.51 43.63 _2100.00 13.88 320.64 2093.23 193323 605) -3936 21413].4] 2499423.81 60°4954.109"N 151.36'07710W 6TW 220 79 _ 219 _ 0.82 40.25 112 1.08 2.52 52.86 220000 1439 330.87 2190.21 2030.21 8].0 -4936 214125]0 249944520 5°49'5439]"N 1151°36'0]10"W 075 3C2 3.02 0.51 223 5275 - 1.18 1.14 215 24382 2300.00 1503 33100 220693 212693 10985 -6170 21411391 249946]69 60°4954616N 151.3607959W 064 209 064 0.13 66.18 1.23 121 258 26760 2400.00 1674 331 30 2363.10 2223.10 13384 -]490 21410130 249949198 60°4954852 N 151'3608225 W 1 71 1 20 171 030 0074 _ 1 30 128 I 261_ J 2]9.96 243000 1992 331.38 241154 2251.]4 14168 -]9.19 21409721 249949992 60°4954929N 151.3608312W 393 2654 393 02] 8553 1.33 1.30 260 1 _ 259.34 _251600 18.54 33041 249343 2333.43 165.18 -9228 21408469 249952374 60°4955160 N1.151 -3608576W 060 9790 072 -143 9974 16] 3.58 241,93 1, 254541 1553 33064 2521.31 236131 1]3.32 -96.88 214060.29 2499531.98 5°4955241 N 1151°3608668"W 025 -24.15 0.03 078 10462 169 _1.34 1.3] 361 241.30 _ 263658 2166 32669 260880 1 244580 200.64 113.53 214064.31 2499559.70 50°4955510"N 151°3609.004"W 363 -2239 3.36 1 -402 12044 199 1 15] 37T 4807 2]33.33 25.55 32322 2695.61 ,_253561 231.66 -13533 21404328 249959124 60°49'55.015"N 1151°3609.444"W 439 -532 4.11 1 -387 137.01 2.66 1 8 305 3504 2829.21 26.36 322.35 2781 06 2621.06 26627 -16163 21401983 249962649 60°4956.156"N'151°36'09.975"W 2.96 -1049 295 -091 154.53 3.64 225 403 3190 292366 3097 32142 2863.12 2]03.12 303.05 190.50 21398986 249966396 60°4956510"N 151'36' 10.55TW 279 5.85 274 -098 17269 404 269 4.19 3201 3018.70 33.33 32106 2943.58 278358 34271 -22188 21395946 2499]043]-60°4956909"N '151°3611.190"W 250 -222 240 046 192.1] 4.39 320 435 30.72 Page 1 oB J11LA 3206.84 3844 320.]6 30796 2937.96 426.85 -28876 21389466 2499]90.12 60°495773]"N 151°3612539"W 184 -12655 174 1.06 23334 4.96 4.30 466 1939 _330159 36.30 _32044 3174 26 301426 470.25 -324.42 21306007 249983439 60°4958.165"N 151"36.13.259"W 025_ __ -2221 -0]5 -034 25492 5.33 477 4.82 1.49 _339705 3fi94 320.14 3250.97 3090.97 51397 -360.]2 213824.85 2499878.96 60°4958.595"N 151°3613991"W 050 _12943 046 .031 274 65 582 5.11 498 34243 3490.56 3438 _3254] 3327.06 3167.06 55720 -39362 213793.01 2499922.99 ; 60°49'59021"N 151°36'14655"W 4A6 _109.]2 2.52 570 29651 644 538 5.17 _ 334.89 358582 33]] 32875 3405.97 3245.97 60200 -42260 213]65.13 '1 2499968.48 1160°49'59 5 462"N 151°36'1239" 7 4 203 11962 0.64 344 32164 19 565 539 3336 368041 3234 333 78 348526 3325.26 64].18 -44742 213741 42 12500014.25,60°49'59.90]"N'151°36'15]40" 327 119.55 1.51 532 349.12 702 590 5.57 33290 3771.19 312] 33]51 356242 340242 690.]5 46].13 213722 79 2500058.29 60°50'00.336"N 1151°36'16.138'- 2.52 11800 1.18 4.22 37768 842 6.15 576 33328 3870.16 30.17 342.00 364751 348751 738.16 48460 21370648 2500196.12 60"5000803"N 1513616490' 2_ . .52 11841 -1.11 444 410.67 9.00 642 5.95 333.62 396559 2890 34725 3]30.55 3570.55 ]834] -49].10 213695.09 250015171 60.5001249N 1513fi16742' 302 95.20 133 550 44424 955 670 6.15 33449 406006 2817 35300 381332 365332 02031 -504.91 213688.37 2500196]3 60°5001690N It 5136'16900' 2.94 93.09 0.14 609 4]96] 1008 698 633 33566 4155.12 28]0_ 35824 389669 3736.69 87384 -50840 21368600 250024233 60°5002.139"N 151.38169]1" 285 ` 9724 0.07 5.51 517.80 10.60 724 6.51 33662 -. __ 4349.47 284)_ 051 3079.56 3819.56 918.92 -50747 21368803 25002873] 60°50'02.583"N 151°3616952" 301 9015 -024 623 55768 11.08 150 6.68 337]3 4343.87 2861 _ 10.51 406251 390251 963.59 -501]1 21369488 250033189 '60°5003.023"N 151°36'16.836"W 312 8652 0.15 643 599.54 11.55 ]7] 6.86 339.19 4433 28.93 of gl 4145.73 405788 100]94 -49090 213]0668 25003753 ' 50°5003459"N 151°36'1631TW 313 6389 0.34 644 643.53 12.00 8.05 703 34027 4533.14 30.00 _ 2161 422788 405788 1051]4 -4]5.]6 213722.3 250041938 60°5003898"N151°3616312"W 2.82 63.89 1.13 526 66922 1243 833 _ 721 342.27 462860 3133 2647 431008 415008 109689 -45508 213743.93 250046333'605004328"N 115136159883 294 5768 139 509 ]37.]3 1284 860 739 34359 ,8173] 34 J5 3520 4468.45 430845 110415 - 403,40_213798 1 .54 250054998 605005194 N'i 1513615430__ 201 5481 158 439 717.57 1323 0.06 4.58 34495 4]2260 3281 _ 3059 4389 fi9 42296]_ 113996 43205 213]6882 250050651 _605004 ]59N 1513614053 339 7306 205 3.86 84010 1363 9.84 78) 34638 491253 3577 _4032 6546.1] 4386.17 122]52 369.)] 213:33.22 2500592.52 60'5005622 N11513614114 3.28 ]183 13 538 89435 1402 944 >3 34810 5006.]0 36.09 4192 462242 446242 126915 -333.43 2138705] 250063325 60°5006032 N' 1513613„1 105 3228 034 120 9483] 1436 9.26 8.16 34993 5100]9 3694 _4281 4698.04 453004 131051 -295.70 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21346698 2490320.16 60.4943163'N 1151°3620439' 0.00 0.00. 000 000 -125096 34]427]4 2643 20665 13440.65 663 _20833 990424 974424 113997 -]2].25 213418.06 249823440 60°4942308"N'151°36'21,383"W1 000 000 0.00 000 -134962 1 3532 27.81 26.71 20680 _ 13548661 0063 20833 9920.52 9)6052 5226.82 -774.07 21336913 249814880 60°4941453"N 155°36.2232]"W 000 000 000 000 -1448.28 3592 2].89 2699 20686 13627,51 8063 _ 20833 993336 9]]}36 -129530 -81099 213330.55 249808124 60°4940778'N 151°36'23.0]2"W 000 000 0.00 000 -15260] 3fi 4fi 2].95 1] 35 206 ]3 WF -2 13648.fi� 20833 993680 9]]6.80 131367 -82009 213320.20 2498063.12 60°4940597 N. 15136' 233]1"W 000 000 0.00 0.00 -154694 3fi 53 2].96 2]28 206]3 13]4866 80.63 20033 995308 9793.08 140052 -Bfi7]1 1 2132)1.2] 249]9]]44 60°4939]42 N 15136'24216"W 000 9.90 0.00 000 -164560 3].15 20.04 2757 20671 1384866 80.63 20833 996937 980937 1487 37 -914.54 21322235 2497691 76 60°4930008N115136265dt 0.00 0.00 000 000 174426 3889 28.12 2]07 206]0 _ M4 .66 80.63_ 20833 990565 9825.65 15]422 95136 - 2131]3.42 249780609 60°49'38032"N 151°3626104'._ OOD 0.00 000 _0.00 -180292 3844 2820 28.1] 20669 _ - 14048.66 0063 20833 1 10001.93 904193 -166106 -1008.18 21312449 249]]2041 60°493].1)5"N 1513627048'_ 000 0.00 000 0.00 -19415] 3910 28.29_ 28.47 206.69 14148.66 8063 20833 10018.21 905021 -1)4]91 1 -1055.00 2130]556 249763463 60°49'36.321"N 151°36'2]993' 0.00 0.00 000000 -204023 3978 28.3] 2878 20669 14205.1] 00_63 20833 1002]41 9867.41 -1]9699 -500546 213047.91 249750631 6049'35838"N 1513628.526"_ 0.00 .59 000 0.00 -209599 - 6016 _ 2842 28.96 206.69 End of Tangent 14248.661 8193 20844 10034.00 98)400 -183481 1 -1101.89 21302656 249]54900 6049'35.465"N 1513628930" 300 4.58 288 024 -21389] 4046 28.46 29.09 20669 _ 14346.66 0492 20866 1004565 988545 192206 -114930 212976 97 249]45294 6049'34.606"N 151°3629896" 300 4.55 299 024 -223830 4116 2854 29.42 206.70 1444866.1_8791 20891 10051 71 9891.]1 200951 -119]44 212926.78 249737669 604933745"N 151°3630865"07 300 6.53 2.99 0.24 -233009 4186 2862 2978 206.73 144059 8900 _ 20900 1005269 9892.69 204144 121511 212908.34 169]345.19 160°4933430"N 151°3631221' 3.00 -2204 299 024 -2374 59 42.12 2865 2990 206.73 End of 3O Aro 14548.66 9077 20829 10052.82 989282 204i.92 -1245.54 21290806 249]344.]3 60°4933426 N'', 151°3531227- 300 -22.04 2)8 -1.13 23]5.13. 42.35 28.65 30.25 20653 WF -3 14485]1 89,:02:::1_20899 10052]0 9892]0 204192 12153] N'151-3631 035' 300 -22.04 2]B -1.13 -2436.0]- 4250 28.69 30.09 20675 - 2128]6.55 249729024 60°4932882 129203 / 21282793 249]202.95 60-4932011 N 151 36 32 77T - 300 -22.04 2]B -1.13 244696 4296 2871 30.63 206.60 CWF -3 14556.55 9099 80820 10052.]0 9892]0 2104.11 -44928 21287265 2497283 38 60°49320llN 151 36 31 910_ 1464866 93 55 10049 06 900906 -2185.61 _300 -22.00 270_ __-1.13 253798 43.30 28]6 3041 208]5 1478866 9633 _ 20602 1004066 988046 -2274.69 -1336.62 212781 17 2497114.99 60°4931133N 151 363367i 300 _ -22.10 2]8 .113_]-:265749 67716 44.01 28.82 3075 20672 14]88.66 9744 205.57 1003560 987566 -2350.46 -1353.91 21276302 249707965 60.4930 781 253N 151°3634070' 3.00 _ 0.00 2]e 00 26]].56 � 44.35 _ 28.84 30.88 20666 _End of 3D Am (J) 1484866' 97.44 205.5] 1002].96 986].96 -2360.56 -13]95] 212736.0508 2497026 64 60"4930253"N 151°3634538' 0.00 000 000 000 -2]3653 4475 2888 3506 20fi51 1 1594866 9744 205.57 1003406 985496 _-2453.56 -14223] 212646O8 2496938.26 160°49293]2"N'151 3635400" 0.00 _ 000 000 _ 000 -203551 45.48 28.94 3136 20651 15048.66 9764 2055] 100907 984207 -254305 .1507 95 212646.12 249684988'60°49'28491"N 1151°3636.263' 000 _000 _ _0.00 0.00 -293449 4622 2899 31.97 206.56 1514866 9744 205.57 1 9989.0) 98290] 2632.46 -155075 212601.16 2496]61.53 60°492]610"N '151°3638/2fi 0.00 0.00 000 000 -303347 46 ,96 29.05 3197 20652. 1524866 9744 1 20557 1 99]6.13 981613 2721 91 -1550]5 212556.19 2496673.53 60°6925829 N 151363]989' 000 000 000 000 -313246 4))2 29.17 32.20 20647 1534066 9744 20557 9963.18 980318 2811.36 -159356 21251123 2496584.75 60°4925868 N1151 36 30 852" 000 000 000 000 -3231.44 48 47 299 3260 20643 -- 1544866 97.44 20557 995024 9]9024 - -290081 -163633 21256627 20964963] 60"4924.967 N151°3639.]14" 0.00 000 000 0.00 -333042 4924 2924 32.92 20640 1554866 9744 20557 993]30 9]]730 -2990.26 -16]9.13 212421.30 2496408.00 60°4924086"N 151 "364057T' _00 _ 000 1 000 000 -3429.40 5001 2930 3324 206 36 155]90] 9744 20557 9933.36 1. 9))336 _-301].46 1 -1692.14 21240763 2496381.12 60°4923819"N 151°3640839" 000 ' 0.00 0.00 000 -345950 5051 _ 2931 33.45 20634 IWF-2 15648.66 9.44 20557 9924.35 976435 '1 -307971 -1]2192 21237634 249531962 60°4923.206"N 151°36'41.440° 000 000 000 000 -3528.38 - 5078 2935 33.56 206.33 1574866 97.44 20557 991141 1 9]51.41 -3169.16 -1]64]1 212331 37 2496231.24 60°4922325"N 1513642.303" 0.00 000 000 000 -362736 51.56 29 43 3369 20630 t564B66 9766 205 57 9898.4] 9]384] -325661 -100]51 212286.41 269616266 60°4921444N 1513643165"__ 000 000 r 000 0 0 -3626.34 52.35 2949 3422 2062] _ 1594666_ 9_7.4_4_ 205 57 988552 9725.52 334606 -165030 212241.45 269605449 60.4920563N 1513644026' 000 000 000 0.00 -3025.32 53.14 2956 3455 206.24 189309 1 21219648 2495966.11 60`4919682 N 1151.3644691 OW 0.00 0.00 000 -392430 5393 29.62 34.88 206.22 16048.66 9744 _20558 98]2.58 9]5258 -343751 _ 16148.88 97/4 _ 20557 985964 969964 -352696 -1935.89 1 312151.52 249507773 60"49'18.801"N '151°3645753 0.00 0.00 000 0.00 -4023281 5473 _ 2969 3522 206.19 16248.66 97.// _20557 984669 960669 -361641 -1978.68 212106.56 2495]0935 60°49'17920"N 1151:36'46,6161.10.00 000 000 0.00 -41225611 5553 29]6 3556 2061] 16340.07 97.44_ 205.57 983375 967385 1 -3705.86 -20214] 21206159 2495700.98 60°4917039"N 1536'474]9" 0.00 0.00 0.00 000 -4221.251, 56.34 29.83 3590 20615 1544866 9744 205.57 982081 966081 -3795.31 -206427 21201663 249561260 60°4916.158"N.151°36tl8361" 000 000 000 000 rtr320235]15 _29.90 3635 206.13 16532.16 • 9744 205.57 9810.00 965000 -38]000 -2100.00 2119]900 249553880 60°4915.423"N 151°36'49062" 0.00 0.00 000 0 1 00 440200 5783 2995 36.54 206.12 1Entl of Tangent J Page 3 of 3 /aa Clearance Summary Report M -35L1 W1309 -Closest Approach Page 1 of 6 BA ER F�UGHES a GE company REFERENCE WELLPATH IDENTIFICATION Operator Hilcorp Alaska, LLC Slot slot #A2-12 Area Cook Inlet, Alaska (Offshore) Well M-351-1 Field McArthur River Field Wellbore M -35L1 Facility STEELHEAD Platform Sidetrack from M-35_awp at 9548.66 MD REPORT SETUP INFORMATION Projection System NAD27 / TM Alaska SP, Zone 4 (5004), US feet Software System WellArchill 5.1 North Reference True User Ulricard Scale 0.999993 Report Generated 08/16/18 at 13:52 Convergence at slot 1.40° West Database/Source file WA_ANC _Defn/M-35L1_WP09_CR.xml WELLPATH LOCATION Actual Datum (RKB) to Facility Vertical 160.00ft Local coordinates Grid coordinates Geographic coordinates North[ft] Easill Easting[US ft] Northirl ft] Latitude Longitude Slot Location -1137.55 545.94 214172.91 2499356.35 60°49'53.534"N 151°36'06.714"W Facility Reference Pt 213654.96 2500506.90 60°50'04.736"N 151°36'17.727"W Field Reference Pt 213640.71 1 2500514.08 60°50'04.803"N 151°36'18.018"W WELLPATH DATUM Actual Datum (RKB) to Facility Vertical 160.00ft Calculation method Minimum Curvature Datum 55278 nT Horizontal Reference Pt Slot Actual Datum (RKB) to mean sea level 160.00ft Vertical Reference Pt Actual Datum (RKB) Actual Datum (RKB) to Mud Line at Slot 160.00ft (slot #A2-12) MD Reference Pt Actual Datum (RKB) Field Vertical Reference mean sea level POSITIONAL UNCERTAINTY CALCULATION SETTINGS Ellipse Confidence Limit 13.00 Std Dev Ili se Start MD .00ft urface Position Uncertaintyincluded Declination 16.38° East of TN Di Angle 3.78° a Field Stren th 55278 nT Slot Surface UncertaintylSD Horizontal .000ft ertical 0.000ft FacilitySurface Uncertainty@1 SID Horizontal .000ft ertical 10.000ft Positional Uncertainty values In the WELLPATH DATA table are the projection of the ellipsoid of uncertainty onto the vertical and horizontal planes „e /qA Clearance Summary Report M -35L1 WP09-Closest Approach Page 2 of 6 BA ER FUGHES a GE company REFERENCE WELLPATH IDENTIFICATION String/Diameter Operator Hilcorp Alaska, LLC Slot Isfot #A2-12 Area Cook Inlet, Alaska (Offshore) Well M -35L1 Field McArthur River Field Wellbore 10-351-1 Facility STEELHEAD Platform Sidetrack from M-35 awp at 9548.66 MD ANTI -COLLISION RULE String/Diameter Rule Name Hilcorp HSE Stop Drilling ACR Rule Based On Ratio Plane of Rule IClosest Approach IThreshold Value 11.00 Include Casing & Hole Size 1yes jApply Cone of Safety Ino HOLE & CASING SECTIONS - Ref Wellbore: M -35L1 Ref Wellpath: M -35L1 W1309 String/Diameter Start MD ft End MD I ft Interval I ft StartTVD End TVD Start NIS Start EM End NIS End EM ftft] Iftl Iftlft ft 8.5in Open Hole 9621.001 16554.491 6933.49 8692.88 N/A 2113.30 618.80 N/A N/A Tin Casing Production 9471.00 16532.1fi 7061.16 8560.13 9810.00 2179.43 641.27 -3870.00 -2100.00 SURVEY PROGRAM - Ref Wellbore: M-35Li Ref Wellpath: M -35L1 WP09 Start MD [ft] End MD Positional Uncertainty Model IN Log Name/Comment Wellbore 0.00 2430.00 Gyrodata standard - Drop gyro or Multi -shot GyroData Gyro<0-2430'> M-35 2430.00 9548.66 BHI OnTrak (MagCAD+IFR1, SAG) BHGE OTK MWD+CA+MSA <2516-10559> M-35 9548.66 16532.16 BHI OnTrak (MagCAD+IFR1, SAG) M-351_1 /43 Clearance Summary Report M -35L1 WP09-Closest Approach Page 3 of 6 BA ER F UGHES a GE company REFERENCE WELLPATH IDENTIFICATION Operator Hilcorp Alaska, LLC Slot slot #A2-12 Area Cook Inlet, Alaska (Offshore) Well M -35L1 Field McArthur River Field Wellbore M-351-1 Facility STEELHEAD Platform Sidetrack from M-35 awp at 9548.66 MD CALCULATION RANGE & CUTOFF From: 0.00ft MD To: 16532.16ft MD IC -C Cutoff: (none) OFFSET WELL CLEARANCE SUMMARY (92 Offset Wellpaths selected) Ratios are calculated in Closest Approach plane C -C Clearance Distance AGR Separation Ratio Ref Min C -C Diverging Ref MD of Min Min Ratio ACR Offset Offset Offset Offset Offset MD Clear Dist from MD Min Ratio Ratio Dvrg from Status Facility Slot Well Wellbore Wellpath Ifti Ift!ft ft ff STEELHEAD slot #A2- M-35 M-35 M-35WP18 9686.84 2.67 13700.00 9690.57 0.8 15000.00 FAIL Platform 12 DOLLY VARDEN slot D-1 D-1 MSS <0-120715 16069.20 355.00 16069.20 16086.65 1.01 16086.65 PASS Platform #A2-1 GRAYLING Platform slot #3-3 G-26 G-26 GMS <0-11544> 14688.45 286.79 14688.45 14764.78 1.02 14764.78 PASS DOLLY VARDEN slot #B 1- D-30 D-30 MSS <10156 -136005 14848.66 491.27 14848.66 14748.66 1.38 14748,66 PASS Platform 12 DOLLY VARDEN slot D-7Rd D-7Rd GMS <0-12900'> 15090.69 759.32 15090.69 14965.60 1.77 14965.60 PASS Platform #A2-4 GRAYLING Platform slot G-7 G-7 PGMS <0-10100>, MSS 10593.07 248.58 10593.07 10485.29 2.32 10485.29 PASS #4-24 <10100-11229> GRAYLING Platform slot G-30 G-30 GMS <0-500>, MSS <630- 11714 90 425.54 11714.90 11820.98 2.34 11820.98 PASS #2-44 11451> GRAYLING Platform slot G-2Rd G-2Rd PGMS <0-10700> 13694.87 581.70 13694.87 13536.79 2.76 13536.79 PASS #4-20 GRAYLING Platform slot G-3 G-3 GMS <0-11050> 13274.33 550.12 13274.33 13572.34 2.79 13572.34 PASS #4-19 GRAYLING Platform slot #3-3 G-26 G-26RD GMS <0-10200>,> MWD 15096.79 293.21 15096.79 15070.41 2.93 15070.41 PASS <10298.75-11587 DOLLYVARDEN slot D-7 D-7Rd#2 MWD <1 2052 - 12438'> 15502.43 924.07 15502.43 15414.86 3.03 15414.86 PASS Platform #A2-4 Rd#2 GRAYLING Platform 119 G-3 G-3RD2 MS 0-7600>, GMS <7700- G 12944 23 546.70 12944.23 13181.41 3.49 13181.41 PASS #4 050 DOLLY VARDEN slot D-26 D-26 GMS <0-119055 16532.16 1189.77 16532.16 16532.16 3.50 16532.16 PASS Platform #At -7 DOLLY VARDEN slot #B1- D-30 D-30Rd GMS <0-12237'> 15234.02 859.48 15236.50 15234.02 3.69 15234.02 PASS Platform 12 STEELHEAD slot M-29 M-29 PGMS <0-11896'> 9668.50 509.31 9668.50 9648.66 3.71 9648.66 PASS Platform #B1-7 GRAYLING Platform slot #3-5 3-24 G-24 GMS <0-10400> 12248.66 601.49 12248.66 12068.84 3.92 12068.84 PASS DOLLY VARDEN slot 3-28 D-28 PGMS <0-12445'> 15404.87 1696.66 15404.87 15400.00 4.19 15400.00 PASS Platform #A1-2 GRAYLING Platform slotG-3 G -3RD G 278 0-9144>, MSS <9144- 13381.71 771.02 13381.71 13800.00 4.31 13800.00 PASS GRAYLING Platform slot #3-9 G-34 G-34 GMS <0-2100>, MSS <2284- 14512.17 1075.98 14512.17 14427.58 4.38 14500.00 PASS 11655> DOLLY VARDEN slot D-26 D-26Rd2 MWD <10743 - 115005 16532.16 1237.61 16532.16 16532.16 4.68 16532.16 PASS Platform #A1-7 DOLLY VARDEN slot D-7Rd D-7 GMS <0-133005 15374.33 1485.32 15374.33 14700.00 4.98 14800.00 PASS Platform #A2-4 DOLLY VARDEN slot D-42 D42 PGMS <0-12830'> 14768.67 923.17 14768.67 14806.89 5.18 14806.89 #A2-7 DOLLYVARDEN slot D-26 D-26Rd1 MWD <10743 - 10834'> 16532.16 1359.19 16532.16 16532.16 5.44 16532.16 Platform #A1-7DOLLYVARDEN JPASSPlatform slot #81- D-30 D-30 Rd 2B MWD <10936 -12164'> 15071.76 1110.26 15071.76 15130.93 5.94 15130.93 Platform 12 „6 /4A OFFSET WELL CLEARANCE SUMMARY (92 Offset Wellpaths selected) Ratios are calculated in Closest Approach plane C -C Clearance Distance ACR Separation Ratio Ref Min C -C Diverging Ref MD of Min Min Ratio ACR Offset Offset Offset Offset Offset MD Clear Dist from MD Min Ratio Ratio Dvrg from Status Slot Well Wellbore I Well ath Ffti Ffti ..Fac,l,tX. DOLLY VARDEN Platform slot #B1- 12 D-30 D-30 Rd 2B1 MWD <11951 - 121455 15088.45 1112.37 15088.45 15180.11 6.02 15180.11 PASS „e /4A Clearance Summary Report M -35L1 W1309 -Closest Approach Page 4 of 6 BA ER BAT a GE company REFERENCE WELLPATN IDENTIFICATION Operator Hilcorp Alaska, LLC Slot slot #A2-12 Area Cook Inlet, Alaska (Offshore) Well M-351-1 Field McArthur River Field Wellbore M-351-1 Facility STEELHEAD Platform Sidetrack from M-35_awp at 9548.66 MD CALCULATION RANGE & CUTOFF From: 0.00ft MD To: 16532.16ft MD C -C Cutoff: (none) OFFSET WELL CLEARANCE SUMMARY (92 Offset Wellpaths selected) Ratios are calculated in Closest Approach plane CC Clearance Distance ACR Separation Ratio Ref Min C -C Diverging Ref MD of Min Min Ratio ACR Offset Offset Offset Offset Offset MD Clear Dist from MD Min Ratio Ratio Dvrg from Status Facility Slot Well Wellbore Wellpath Iftl Ift]ft ft ft GRAYLING slot G-33 G-33 MSS <0-10790> 9755.08 868.97 9755.08 9800.00 6.33 9800.00 PASS Platform 3-11 STEELHEAD of M -32B1- ST#4 / M-32 St#4 / MWD <9758 - 13835'> 9548.66 544.85 9548.66 9548.66 6.43 9548.66 PASS Platform M-32 RD 10 M-32RD DOLLY lot VARDEN B1- D-30 D-30 Rd 2A MWD <10809 - 11890'> 15367.91 1012.96 15367.91 15522.08 6.46 15522.08 PASS Platform 12 GRAYLING slot G-23 G -23RD GMS <5500-11742> 14024.33 1497.64 14024.33 15000.00 6.48 15000.00 PASS Platform 3-10 DOLLY slot VARDEN B1- D-30 D-30 RD MWD <11868-12048'> 15166.63 1145.84 15166.63 15291.32 6.54 15291.32 PASS 2B2 Platform 12 slot_ STEELHEAD M-32RD2 M-32RD2 M-32RD2_Hilcorp_awp 11528.66 504.14 11528.66 11574.21 6.67 11574.21 PASS Platform Hilcorp 101 GRAYLING slot G-20 G-20 GMS <0-10642> 9548.66 1103.66 9548.66 9548.66 6.91 9548.66 PASS Platform 3-6 GRAYLING slot G-21 G-21 RD GMS <0-7800>, MWD <7938-10750> 10381.55 865.17 10381.55 9548.66 7.25 10948.66 PASS Platform -2 GRAYLING slot G-23 G-23 GMS <0-12075> 13135.89 1909.89 13135.89 15100.00 7.59 15100.00 PASS Platform 3-10 DOLLY VARDEN slot D-27 D-27 PGMS <0-11000'> 16532.16 1680.20 16532.16 16532.16 7.84 16532.16 PASS At -1 Platform DOLLY VARDEN slot D-32 D-32 GMS<0-24005 MSS<2506-111605 16532.16 2350.39 16532.16 16532.16 7.90 16532.16 PASS A1-4 Platform GRAYLING slot G-11 G-11 GMS <0-10115> 13836.49 1634.36 13836.49 13600.00 8.04 13600.00 PASS Platform -21 DOLLY VARDEN slot D-41 D-41 GMS <0-11600'> 16532.16 2544.02 16532.16 16532.16 8.13 16532.16 PASS A1-6 Platform GRAYLING slot G-4 G4RD GMS <1400-10400> 9548.66 1288.59 9548.66 9548.66 8.34 9548.66 PASS Platform 2-39 DOLLY slot VARDEN B1- D-30 D-30 Rd 2C PGMS <0-11365'> 15864.06 1296.90 15864.06 16126.98 8.40 16126.98 PASS Platform 12 GRAYLING lot G-21 G-21 GMS <0-11160> 9548.66 1234.50 10648.66 12000.00 8.59 12000.00 PASS Platform 3-2 STEELHEAD slot_ M-32/ M-321 M-32 / M-32 PB1_awp 9548.66 536.67 9548.66 9548.66 8.63 9548.66 PASS Platform 101 M-32 PB1 M-32 PB1 slot M-32 STEELHEAD #B1ST#1 / M-32 / M-32 PB2_Hilcorp_awp 9548.66 536.67 9548.66 9548.66 8.63 9548.6fi PASS Platform PB2 M-32 PB2 10 M-32 PB2 M-32 St#2 / M-32 PB3_Hilcorp_awp 1 9548.66 536.47 9548.66 9548.66 8.66 9548.66 PASS „e /4A OFFSET WELL CLEARANCE SUMMARY (92 Offset Wellpaths selected) Ratios are calculated in Closest Approach plane C -C Clearance Distance ACR Separation Ratio Ref Min C -C Diverging Ref MD of Min Min Ratio ACR Offset Offset Offset Offset Offset MD Clear Dist from MD Min Ratio Ratio Dvrg from Status Facility Slot Well Wellbore Wellipath ft ft ft ft ft STEELHEAD slot M-32 M-32 St#2l Platform B1- ST#2/ M-32 P63 10 M-32 PB3 STEELHEAD slot B1- M-32 M-32 St#3 / Platform ST#3 / M-32 M-32 St#3 / M-32_Hilcorp_awp 9548.66 536.47 9548.66 9548.66 8.66 9548.66 PASS 10 M-32 slot M-32 ST M-32 St STEELHEAD Bt PB1/ PB1 / M-32 St PB1 / M-32RD PB1 g548,66 536.47 9548.66 9548.66 8.66 9548.66 PASS Platform 10 M-32RD M-32RD Hilcorp_awp PB1 PBI DOLLY VARDEN Al -5 D40Rd D-40Rd PGMS c0-125205 16436.50 3504.27 16436.50 15700.00 9.14 15700.00 PASS Platform lot PDMS <0-10300>, PGSS <10400- -8 G-36 G-36 10982>, MSS <11259-11542>, PMSS 13292,30 2482.82 13292.30 15500.00 9.5 15500.00 PASS <11830-12453> Gyrodata EPIatformJ3 ot 2-8 D-47 D-47 Gyro<0-10692.8'>PGMS<10720- 16532.16 1376.67 16532.16 16532.16 9.60 16532.16 PASS 11930> ot .1' G-36 G-36DPN PGMS <0-10300>, PGSS <10400- 10400- 13248.66 2484.26 13248.66 15200.00 10.01 15300.00 PASS 3-8 10998>, PGMS <1 1100-13380, „e /43 Clearance Summary Report M -35L1 W1309 -Closest Approach Page 5 of 6 BA ER BAT a GE company REFERENCE WELLPATH IDENTIFICATION Operator Hilcorp Alaska, LLC Slot slot #A2-12 Area Cook Inlet, Alaska (Offshore) Well M -35L1 Field McArthur River Field Wellbore M-351-1 Facility STEELHEAD Platform Sidetrack from M-35_awp at 9548.66 MD CALCULATION RANGE & CUTOFF From: O.00ft MD To: 16532.16ft MD C -C Cutoff: (none) OFFSET WELL CLEARANCE SUMMARY (92 Offset Wellpaths selected) Ratios are calculated in Closest Approach plane C -C Clearance Distance ACR Separation Ratio Ref Min C -C Diverging Ref MD of Min Min Ratio ACR Offset Offset Offset Offset Offset MD Clear Dist from MO Min Ratio Ratio Dvrg from Status Facilitv slot Well Wellbore Wellpath ft ff) Iftl Iftlft DOLLY VARDEN slot GMS<0-2550'> MSS<2701- Platform #A2-3 D-1 1 D 11 11682'> 16532.16 3015.14 1653216 16532.16 10.40 16532.16 PASS STEELHEAD slot M-25 M-25 PGMS<0-3620'>PGMS<3700- 9548.66 1131.90 9548.66 9548.66 10.42 9548.66 PASS Platform #81-11 11880'> GRAYLING slot Platform #3-1 G-22 G-22 GMS <0-11335> 15087.17 3027.41 15087.17 15600.00 10.58 15700.00 PASS GRAYLING slot Platform #3-9 G-34 G-34RD GMS <0-10268> 11303.65 1165.09 11303.65 11000.00 10.61 11000.00 PASS DOLLY VARDEN slot D-30 D-30 GMS <10500 - 11000'> 16038.93 1489.27 16038.93 16510.03 10.66 16510.03 PASS Platform #B1-12 Rd3#2 GRAYLING slot G-8 BH G-8Rd GMS <0-11750> 11711.56 2334.19 11711.56 13300.00 11.201 13400.00 PASS Platform #2-45 Original GRAYLING slot G-6 G-6RD GMS <0-8800>, PGMS <8900- 9548.66 1311.18 9548.66 10925.33 11.24 10925.33 PASS Platform #2-46 11000> DOLLY VARDEN slot Platform #B1-7 D -2A Rd D-2Rd MSS <9482 - 124255 16532.16 3174.51 16532.16 16532.16 12.05 16532.16 PASS GRAYLING slot Platform #2-46 G-6 G-6 GMS <0-9600> 9548.66 1374.84 9548.66 9548.66 12.13 11048.66 PASS GRAYLING slot Platform #2-38 G-31 G-31 MSS <0-12736> 9548.66 2132.82 9548.66 9548.66 12.16 9548.66 PASS KING SALMON slot Platform #4-28 K-25 K-25 PGMS <0-14325'> 9674.80 2012.73 9674.80 9900.00 12.44 9900.00 PASS DOLLY VARDEN slot D-43 D -43Rd PGMS <0-11250'> 16532.16 3467.15 16532.16 16532.16 12.64 16532.16 PASS Platform #A1-9 STEELHEAD slot Platformtform #A1-11 M-14 M-14 PGMS <0-26405<2700-9190'> 10361.50 652.63 10361.50 10167.99 13.52 10167.99 PASS DOLLYVARDEN slot Platform #A1-11 D-31 Rd D-31 Rd GMS <0-10628'> 16532.16 1048.87 16532.16 16532.16 13.70 16532.16 PASS DOLLY VARDEN slot Platform #B1-7 D -2A Rd D-2 MSS <6927 - 125575 16532.16 3511.88 16532.16 16532.16 13.76 16532.16 PASS GRAYLING slot G-1 G-1 RD PGMS <0-11430>, MWD <11430- 9548.66 2322.08 9548.66 9548.66 14.35 9548.66 PASS Platform #2-40 11500> GRAYLING Platform slot #1-32 G-40 G-40 PGMS <0-11317> 13303.65 2736.89 13303.65 13900.00 14.79 14000.00 PASS GRAYLING slot G-1 G-1 PGMS <0-8450>, MSS <8491- 9548.66 2327.72 9548.66 9548.66 15.05 9548.66 PASS Platform #2-40 11420> DOLLY VARDEN slot Platform #A1-3 D-29 D-29 PGMS <0 - 130505 16466.63 2575.05 16466.63 14901.28 15.05 15500.00 PASS GRAYLING slot Platform #247 G-32 G-32 MSS <0-11570> 9548.66 2415.46 9548.66 9548.66 15.17 9548.66 PASS GRAYLING slot Platform #2-39 G-4 G-4 GMS <0-9000> 9548.66 2088.64 9548.66 9548.66 15.22 9548.66 PASS GRAYLING slot G -14A MMS <0-1365>, PMSS <1395- Platform #4-13 l G-14ARD1 12743> 9548.66 2561.06 9548.66 12300.00 15.80 12400.00 PASS HE BHGE D-3 Rd2 D -3Rd IGMS <0-11100'> 16532.16 1669.96 16532.16 16532.16 15.86 16532.16 PASS „6 /4a OFFSET WELL CLEARANCE SUMMARY (92 Offset Wellpaths selected) Ratios are calculated in Closest Approach plane C -C Clearance Distance ACR Separation Ratio Ref Min C -C Diverging Ref MD of Min Min Ratio ACR Offset Offset Offset Offset Offset MD Clear Dist from MD Min Ratio Ratio Dvrg from Status Facility Slot Well Wellbore Wellpath ft H] Iftl Iftift DOLLY VARDEN slot Platform #A2-11 DOLLY VARDEN slot Platform #A2-11 D-3 Rd2 D-3Rd2 PGMS <0-11055'> 16532.16 1500.59 16532.16 16532.16 16.28 16532.16 S DOLLY VARDEN slot JPASS Platform #A1-11 D-31 Rd D-31 MSS <2520-10125'> 16532.16 2246.59 16532.16 16532.16 16.53 16532.16 'AA Clearance Summary Report M-351-1 WP09-Closest Approach Page 6 of 6 BATER UGHES a GE company REFERENCE WELLPATH IDENTIFICATION Operator Hilcorp Alaska, LLC Slot slot #A2-12 Area Cook Inlet, Alaska (Offshore) Well M -35L1 Field McArthur River Field Wellbore M-35LI Facility STEELHEAD Platform Sidetrack from M-35_awp at 9548.66 MD CALCULATION RANGE & CUTOFF From: 0.00ft MD To: 16532.16ft MD IC -C Cutoff: (none) OFFSET WELL CLEARANCE SUMMARY (92 Offset Wellpaths selected) Ratios are calculated in Closest Approach plane C -C Clearance Distance ACR Separation Ratio Ref Min C -C Diverging Ref MD of Min Min Ratio ACR Offset Offset Offset Offset Offset MD Clear Dist from MD Min Ratio Ratio Dvrg from Status Facilltv slot Well Wellbore Wellpath ft ft k ft ft GRAYLING slot G-8 BH G-8 GMS <0-7700>, MSS <7709- 11092.30 2609.02 11092.30 13315.61 16.64 13400.00 PASS Platform 2-45 Original 12175> DOLLY VARDEN slot D-29 D-29Rd PGMS <0-13111'> 16532.16 2656.22 16532.16 16532.16 18.02 16532.16 PASS Platform Al -3 STEELHEAD t M-06RD M-06RD M-O6RD_awp 10200.00 942.85 10200.00 10400.0018.34 10400.00 PASS Platform 2-6 GRAYLING t G-8RD G-8RD G-8RD Hilcorp_awp 12086.36 2277.93 12086.36 13500.00 19.53 13600.00 PASS Platform Hilcorp HilcorpDOLLYVARDENt D-3 Rd2 D-3 GMS <0-10881'> 16532.16 2402.50 16532.16 16532.16 0.04 16532.16 PASS Platform 12-45 2-11 GRAYLING tG-8 Hilcorp G-8 Hilcorp G-8 Hilcory_awp 11424.33 2592.20 11424.33 13700.00 0.12 14800.00 PASS Platform -45DOLLYVARDENtD-10 D-0811 MWD <10565 - 11234'> 16532.16 2037.00 16532.16 16532.16 0.76 16532.16 PASS Platform 1-9DOLLYVARDENt D-20 D-20 GMS<0-450'><500- 16532.16 3281.79 16532.16 16532.16 0.89 16532.16 PASS Platform B1-4 3000'>MSS<3219-10506'> DOLLY VARDEN slot D-10 D-48 PGMS <0-10873'> 16532.16 2108.38 16532.16 16532.16 22.23 16532.16 PASS Platform B1-9 STEELHEAD slot M-31 M-31 St #2 MWD <10248 - 11265'> 9548.66 1586.49 9548.66 9548.66 22.29 9548.66 PASS Platform B1-12 STEELHEADslot M-31 M-31 St#1 PGMS <0-10726'> MWD 9548.66 1586.49 9548.66 9548.66 2.29 9548.66 PASS Platform B1-12 <10741-12018'> STEELHEAD slot M-31 M-31 MWD<947-10355'> 9548.66 1586.49 9548.66 9548.66 2.29 9548.66 PASS Platform 81-12 DOLLY VARDEN slot D-5Rd D-5Rd GMS <0-10650'> 16532.16 3476.90 16532.16 16532.16 23.05 16532.16 PASS Platform A2-9 GRAYLING slot G-2Rd G-2 PGMS <0-1300>, MSS <1300- 11136.50 2903.15 11136.50 13400.00 5.31 13400.00 PASS Platform -20 10150> STEELHEAD slot M-12 M-12 GSS<454-1150'> MWD<l 199- 8548.66 2679.25 9548.66 9548.66 35.68 9548.66 PASS Platform Al -3 10715'> STEELHEAD slot M-28RD M-28RD M-28RD_awp 9548.66 2631.67 9548.66 9548.66 36.47 9548.66 PASS Platform B1-3 GRAYLING slot G-14ARD G-14ARD G-14ARD Hilcorp 9548.66 2584.17 9548.66 11900.00 38.17 14448.66 PASS Platform -13 Hilcorp Hilcorp „e J TRANSMITTAL LETTER CHECKLIST WELL NAME: T B w M 3 5l-. 2 PTD: "o.1,3- 105 ✓Development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: M G / V'+� P- A I✓eJ'�_POOL: V/(z Fore. (4144_ 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. a.1771-_119, API No. 50-77-33ADGMam-00-00. V/ (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 -4 1. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Comnanv 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, W FORELAND OIL - 52019 PTD#:2181050 Company HILCORP ALASKA LLC Initial Class/Type Well Name: TRADING BAY UNIT M-351_1 Program DEV Well bore seg ❑d DEV / PEND GeoArea 820 Unit 12070 On/Off Shore Off Annular Disposal ❑ Administration 17 Nonconven, gas conforms to A531,05.030Q. 1.A),Q,2.A-D) _ NA 1 Permit fee attached - _ _ _ _ _ - _ _ NA. 2 Lease number appropriate.. Yes .. ..... _ _ _ 3 Unique well. name and number Yes 4 Well located in a defined pool _ Yes 5 Well located proper distance from drilling unit. boundary Yes McArthur River West Foreland Oil Pool - governed by CO 228A 6 Well located proper distance from other wells _ _ _ Yes CO228A contains no. spacing. restrictions with respect to drilling unit boundaries. 7 Sufficient acreage available in. drilling unit Yes CO228A has no interwell spacing restrictions.... 8 If deviated, is. wellbore plat. included _ Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force _ Yes Appr Date 11 Permit can be issued without conservation order _ _ _ _ Yes 12 Permit can be issued without administrative approval Yes DLB 8/23/2018 13 Can permit be approved before 15 -day wait. _ _ _ _ _ _ _ NA 14 Well located within area andstrata authorized by Injection Order # (put 10# in. comments). (For NA. 15 All wells within 114 mile area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA 16 .Pre -produced injector. duration of pre production less than 3 months(Forservice well only) - NA 18 Conductor string.provided .... _ _ . ........................NA ..... conductor in M-35 already set. Engineering 19 Surface casing- protects all known USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA..... _ 20 CMT vol adequate to circulate. on conductor & surf csg .............. NA 21 CMT. vol adequate to tie-in long string to surf cS9 NA 22 CMT will cover all knownproductivehorizons.. Yes 7" liner will. be fully cemented. back to window. 23 Casing designs adequate for C, T, B & permafrost_ _ _ _ Yes BTC for liner provided. 24 Adequate tankage or reserve pit _ Yes Rig has steel pits. All waste to. KGF. G& I _ 25 If.a. re -drill, has a 10-403 for abandonment been approved NA Lateral.... motherbore will be utilized and capable of flowing.. 26 Adequatewellbore separation proposed _ Yes 27 If. diverter required, does it meet regulations NA Appr Date 28 Drilling fluid. program schematic & equip list adequate _ Yes - _ Max form pressure= 444.3. psi (will. drill with 9.2 - 9.7 ppg mud) _ GLS 8/29/2018 29 BOPEs, do they meet regulation _ _ _ _ _ _ Yes _ _ 13 5/8" 5000 psi BOPE 30 BOPE-press rating appropriate; test to (put psig in comments)_ _ _ _ Yes _ _ MASP = 2292 psi (Altcalc using 2/3 gas. column approved) 31 Choke manifold complies w/API. RP -53 (May 84)... _ Yes 32 Work will occur without operation shutdown _ - _ , - - _ No 33 Is presence of H2S gas probable, . .......... No Rig has H2S sensors and alarms. 34 Mechanical. condition of wells within AOR yedfled (For service well only) ..... ....NA 35 Permit can be issued w/o hydrogen sulfide measures ....... .......... No. Steelhead Platform is a designated H2S site, Measures required; rig has sensors and alarms. Geology 36 Datapresentedon potential overpressure zones _ _ _ _ _ _ - - _ - _ _ Yes _ _ _ _ For West Foreland; Reservoir pressures of 8.5-6.6 EMW will be drilled with. 9.2-9.7 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones _ - _ _ _ NA DLB 8/23/2018- X38 Seabed condition survey -(if off -shore) _ _ - _ - _ _ - _ _..._ _- NA- 39 Contact name/phone for weekly progress reports. [exploratory only] _ _ _ _ _ _ _ _ NA Geologic Engineering Public M-351_1 lateral will be a level 5 junction using Baker RAM system. Motherbore M-35 will also be capable of flowing. GIs. CoDate: Date Commissioner: Commissioner: Commissia r Date