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218-120
DATA SUBMITTAL COMPLIANCE REPORT 3/18/2019 Permit to Drill 2181200 Well Name/No. KUPARUK RIV UNIT 2T-371-1-01 fB1 • Operator CONOCOPHILLIPS ALASKA, INC. ?OV MD 14777 TVD 5880 Completion Date 12/13/2018 Completion Status 1-0IL Current Status 1-011- REQUIRED -OIL REQUIRED INFORMATION Mud Log Nov/" Samples No t/ API No. 50-103-20227-61-00 Directional Survey UIC No Yes V DATA INFORMATION List of Logs Obtained: GR/Res (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 21VID Final.cgm ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 51VID Final.cgm ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1.01 5TVDSS Final.cgm ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 21VID Final.pdf ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 5MD Final.pdf ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 5TVDSS Final.pdf ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 EOW - NAD27.pdf ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 EOW - NAD27.txt 1 ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 Final Surveys.csv •i ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 Final Sumeys.xlsx ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 Survey Listing.txt ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 Surveys.txt ED C 30187 Digital Data 1/4/2019 Electronic File: 27-371-1- 01 _25_tapescan_SH I_CTK.txt ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1- 01 _5_tapescan_131-11 CTK.bct ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1-01_output.tap ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 2MD Final.tif ED C 30187 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 51VID Final.tif ED C 30187 Digital Data 1/4/2019 Electronic File: 2T -37L1-01 5TVDSS Final.tif Log C 30187 Log Header Scans 0 0 2181200 KUPARUK RIV UNIT 2T-371-1-01 LOG HEADERS AOGCC Page 1 of 5 Monday, March l8, 2019 DATA SUBMITTAL COMPLIANCE REPORT 3/18/2019 Permit to Drill 2181200 Well Name/No. KUPARUK RIV UNIT 2T-371-1.01 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50.103-20227-61-00 MD 14777 TVD 5880 Completion Date 12/13/2018 Completion Status 1-011- Current Status 1 -OIL UIC No Log C 30188 Log Header Scans 0 0 2181200 KUPARUK RIV UNIT 2T-371-1-01 PB1 LOG HEADERS ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371-1-011381 21VID Final.cgm ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371-1-01PB1 5MD Final.cgm ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 PB1 5TVDSS Final.cgm ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 PB1 2MD Final.pdf ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 PB1 51VID Final.pdf ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371-1-01PB1 5TVDSS Final.pdf ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371-1-01PB1 EOW - NAD27.pdf ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371-1-011301 EOW - NAD27.bd ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-37L1-01PB1 Final Surveys 10888'.csv ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371.1-01PB1 Final Surveys 10888'.xlsx ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 PB1 Survey Listing.txt ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371-1-011381 Surveys.txt ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371-1- 01PB1_25 tapescan_BHI_CTK.txt ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371-1- 01PB1_5tapescan_BHI_CTK.txt ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371-1-01PB1_output.tap ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371-1-01 PB1 21VID Final.tif ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-371-1-01PB1 51VID Final.tif ED C 30188 Digital Data 1/4/2019 Electronic File: 2T-37L1-01PB1 5TVDSS Final.tif ED C 30189 Digital Data 1/4/2019 Electronic File: 2T-37L1-01PB2 21VID Final.cgm ED C 30189 Digital Data 1/4/2019 Electronic File: 2T-37L1-01PB2 5MD Final.cgm ED C 30189 Digital Data 1/4/2019 Electronic File: 2T-37L1-01PB2 5TVDSS Final.cgm ED C 30189 Digital Data 1/4/2019 Electronic File: 2T-371-1-01128221VID Final.pdf AOGCC Page 2 of 5 Monday, March 18, 2019 J DATA SUBMITTAL COMPLIANCE REPORT 3/18/2019 Permit to Drill 2181200 Well Name/No. KUPARUK RIV UNIT 2T-371-1-01 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20227-61-00 MD 14777 TVD 5880 ED C 30189 Digital Data ED C 30189 Digital Data ED C 30189 Digital Data ED C 30189 Digital Data ED C 30189 Digital Data ED C 30189 Digital Data ED C 30189 Digital Data ED C 30189 Digital Data ED C 30189 Digital Data Completion Date 12/13/2018 Completion Status 1-0I1 ED C 30189 Digital Data ED C 30189 Digital Data ED C 30189 Digital Data ED C 30189 Digital Data ED C 30189 Digital Data Log C 30189 Log Header Scans 0 0 ED C 30198 Digital Data ED C 30198 Digital Data ED C 30198 Digital Data ED C 30198 Digital Data Log C 30198 Log Header Scans 0 0 Log C 30199 Log Header Scans 0 0 ED C 30199 Digital Data ED C 30199 Digital Data Current Status 1 -OIL UIC No 1/4/2019 Electronic File: 2T-371-1-01 PB2 51VID Final.pdf 1/4/2019 Electronic File: 2T-371-1-01 P132 5TVDSS Final.pdf 1/4/2019 Electronic File: 2T-371-1-01 PB2 EOW - NAD27.pdf 1/4/2019 Electronic File: 2T-371-1-01PB2 EOW - NAD27.txt 1/4/2019 Electronic File: 2T-371-1-01PB2 final surveys 10869 TD.csv 1/4/2019 Electronic File: 2T-37L1-01PB2 final surveys 10869 TO.xlsx 1/4/2019 Electronic File: 2T-371-1-01 P132 Survey Listing.txt 1/4/2019 Electronic File: 2T-371-1-01 PB2 Surveys.txt 1/4/2019 Electronic File: 2T-371-1- 01 PB2_25_tapescan_BHI_CTK.txt 1/4/2019 Electronic File: 2T-371-1- 01 PB2_ 5_tapescan_BHI_CTK.txt 1/4/2019 Electronic File: 2T-371-1-01PB2_output.tap 1/4/2019 Electronic File: 2T-37L1-01PB2 2MD Final.tif 1/4/2019 Electronic File: 2T-371-1-01 PB2 SMD Final.tif 1/4/2019 Electronic File: 2T-37L1-01PB2 5TVDSS Final.tif 2181200 KUPARUK RIV UNIT 2T-371-1-01 PB2 LOG HEADERS 1/4/2019 Electronic File: 2T-371-1-01 EOW - NAD27.pdf 1/4/2019 Electronic File: 2T-371-1-01 EOW - NAD27.txt 1/4/2019 Electronic File: 2T-371-1-01 EOW - NAD83.pdf 1/4/2019 Electronic File: 2T-371-1-01 EOW - NAD83.bd 2181200 KUPARUK RIV UNIT 2T-371-1-01 LOG HEADERS 2181200 KUPARUK RIV UNIT 2T-371-1-01 PB1 LOG HEADERS 1/4/2019 Electronic File: 2T -371-1-01P81 EOW - NAD27.pdf 1/4/2019 Electronic File: 2T -371-1-01P81 EOW - NAD27.bd AOGCC Page 3 of 5 Monday, March 18, 2019 DATA SUBMITTAL COMPLIANCE REPORT 3/18/2019 Permit to Drill 2181200 Well Name/No. KUPARUK RIV UNIT 2T-371-1-01 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20227-61-00 MD 14777 TVD 5880 Completion Date 12/13/2018 ED C 30199 Digital Data ED C 30199 Digital Data ED C 30200 Digital Data ED C 30200 Digital Data ED C 30200 Digital Data ED C 30200 Digital Data Log C 30200 Log Header Scans Well Cores/Samples Information Name INFORMATION RECEIVED Completion Report 0 Production Test InformatiorO NA Geologic Markers/Tops YO COMPLIANCE HISTORY Completion Date: 12/13/2018 Release Date: 10/12/2018 Description Comments: Completion Status 1 -OIL Current Status 1 -OIL UIC No 1/4/2019 Electronic File: 2T-37L1-01PB1 EOW - NAD83.pdf 1/4/2019 Electronic File: 2T -371-1-01P81 EOW-NAD83.txt 1/4/2019 Electronic File: 2T-37L1-01PB2 EOW - NAD27.pdf 1/4/2019 Electronic File: 2T-371.1-01PB2 EOW - NAD27.t# 1/4/2019 Electronic File: 2T-371_1-01 PB2 EOW - NAD83.pdf 1/4/2019 Electronic File: 2T-371_1-01 PB2 EOW-NAD83.bd 0 0 2181200 KUPARUK RIV UNIT 2T-371-1-01 PB2 LOG HEADERS Sample Interval Set Start Stop Sent Received Number Comments Directional / Inclination Data �Y Mud Logs, Image Files, Digital Data Y! v�/a Core Chips Y 16J Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files O Core Photographs Y /,lBAA7/ Daily Operations Summary YO Cuttings Samples Y Laboratory Analyses Y / Date Comments AOGCC Page 4 of 5 Monday, March 18, 2019 DATA SUBMITTAL COMPLIANCE REPORT 3/18/2019 Permit to Drill 2181200 Well Name/No. KUPARUK RIV UNIT 2T -37L1-01 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20227-61.00 MD 14777 TVD 5880 Completion Date 12/13/2018 Completion Status 1 -OIL Compliance Reviewed By: Current Status 1 -OIL UIC No Date: AOGCC Page 5 of 5 Monday, Mamh 18, 2019 IRCEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 1 4 2019 WELL COMPLETION OR RECOMPLETION REPORT AND, LOG,��; 1a. Well Status: Oi10 Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ ib. Well Class: 20AAC25,105 20AAc25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 12113/2018 218-120 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 11/27/2018 50-103-20227.61.00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: Surface: 98' FNL, 556' FWL, Sec 12, T11N, RBE, UM 1211112018 2T -37L1 -0112T -37L1-01 PBV 2T -37L1-01 PB2 Top of Productive Interval: 9. Ref Elevations: KB:122 17. Field / Pool(s): 3745' FNL, 1580' FEL, Sec 10, T11N, R8E, UM GL: 80.5 BF: Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2598' FNL, 911 Sec 9, T11N, R8E, UM N/A ADL 25568, ADL 25569 • 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 498945 y- 5969882 Zone- 4 14777/5880 ' LONS 84-133 TPI: x- 491531 y- 5966240 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 487735 y- 5967392 Zone- 4 NONE 1569/1515 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 NIA (ft MSL) 1 10680/5814 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 41 121 41 121 36 103 SX AS 1 9.625 40 L-80 41 4145 41 4145 12.25 860 sx AS III Lead, 400 sx of 7 26 L-80 39 11074 39 11074 8.5 240 sx Class G 2.375 4.6 L-80 10620 14777 5777 5880 3 Slotted Liner 24. Open to production or injection? Yes ❑� No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number; Date Perfd): SLOTTED LINER@: \1-1 vAo 10621.14777 MD and 5777-5880 TVD' _.O:vIPi.E r�q1= vl-ttiV 00 r.F1'-L 3 112 10626 10597/5763 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 12128/2018 GAS LIFT Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 1/6/201918hrs Test Period 146.25 306.75 2217 124 beans 2098 Flow Tubing Press. 237psi Casino Press: I Jn17 Calculated 24 -Hour Rate Oil -Bbl: 1 Gas -MCF: 409 Water -Bbl: 1 2966 Oil Gravity-API(corr): Form 10-407 Revised 00178 aVTL 2/S-1/ 9 r%%NTINUED ON PAGE 2 ��� 5� M� J 1 i; 1 C 21,19 Submit ORIGINIAL only �qm / % v 28. CORE DATA Conventional Corals): Yes ❑ No 21 Sidewall Cores: Yes ❑ No R] If Yes, list formations and intervals cored (MD/TVD, FromfTo), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1569 1515 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 10730 - 5840 information, including reports, per 20 AAC 25.071. Formation @ TPI - Kuparuk A 2T-37L7-01PB1 TO 10888 5877 2T-37L1-01PB2 TD 10868 5880 TO 14777 5880 Formation at total depth: Ku aruk C4 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolooical report production orwell test re ults. per 20 AAC 25.070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: Ryan McLaughlin Authorized Title: Staff CTD En ineer Contact Email: R an.McLau hlin co .com Authorized Contact Phone: 265-6218 Signature: Date: �y/f INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10407 well completion report and 10404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this forth and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 2T47 Current CTD Sch metro 16'fi28H<D ¢M �121'MD B L-0O¢Iae ® 41e45 u• MD Y vOtomw Geantl pe1650UEEZED 1D,ers-t6sprklD KW 010.714•MO - 1w b 10,]20'-Po10�,]/9M0 r zBktfis ¢nwg 11,0]¢'MD }t!Y Cemco DS WPW � 505'RI® (2.BiYlD) }1/Y 9]8LL0 EUEBN T�inp ro au0aw }t? Cavo¢ MMD 0u Brtmanerela121B8', S2b'. ]¢O6', 8]1]', 9]BT, tO,S¢B'RKB Canty W I Sekx5ve WPW @ 10,$WRKB (1.812• W) KAn @1D,SM'WB baker SA9d packer � 10.58TRI® DPIpWMtOS1SMD(MlledoWm280'16n ID,R o) }12' Baku SOS ®1OA25' RKB zrmlmW1 ro-marKo ¢wo141aV Mp nm+m m-la.m up TYe'rww ie� w mMnea rYrn �. r¢av up. eoinAmuP D1. AKUP PROD WELLNAME 2T37 WELLBORE 2T-37 ConocoP11ll1p5 Well Attributr Max Angle nn TDo^ ^ FMIE Name We10oq APWW1 Wenevem Sggs ncl l•1 MD(ft ACI BIm (N(B) Nested. Inc KIIPGRIIK RIVER I INIT RMnp000gAy oof,n � � n Zf3).1/tYN182ia:ID PM Last Tag Vwh/esMma&l�gsl) Annelallon OepM InK01 FM wle We11M1ore UP Matey Lasl Tag: IRKS (Est. 15 of Fill, Leaving 5'o Open Pegs) ]/fi2018 2T-3) zembeej HANGER:365 Last Rev Reason Anna lbn Endwq WNlbore Last Map By Rev Reason Installed GLD, Added Line Top Depth 12212018 2T-37 inegump Casing Strings Casing Dercuplion option) ID gnl Top (NINE) S. Dip"lnKBl Ser UP H'.)... WIILen 0-12UIde TOP Treed CONDUCTOR 16 15.06 41.0 121.0 1210 62.58 H-40 WELDED CONDUCTOR. 41 D+n o Casing Desnlplion pptlm) 081r) rop lflKe) sel wpM lnNe1 stl DeplM1 (Npj... WBLM g...Gme rop roma SURFACE 95/8 8.83 414 4,145.3 2,8891 Zoo L-80 BTC NIPPIE: Yb.a et wpN nVD1... VMen (1... Grape ToTFmd Lasing 0escripgon OO gn) I011n) iopinitB) Sat wpN lnKB) 56'0'6`b. PRODUCTION ] 628 38.] 11,0)]6 6OfiS9 2600 L-80 BTC -M00 Gas urT:2ta3 Casing Descusion OD (in) ID gn) Top(NNel Set D.P. Inner SeI DepN]TVD)... WULen(I GNNO TOPThond LI LATERAL 2318 1.99 10,]09.8 10,)680 5,9]00 4.60 1 -6D STL Tubing Strings Tubing Description sning Mn.- 1Door Top RE; sM Depth lrt.. ser Depin lrvo) l... E`-` Grade rop conn"i n TUBING 3112 2.99 366 10,625.6 5,780.3 9.30 L-80 ABM-EUE Completion Details 6URFhCE: 41.1 ,10,a Anmw ead-nanal"00- 9.T3yo roP(1YD) Tap qd xominm Top al (MB) PI Item Das Com 10 (in) 36.6 36.6 000 HANGER FMC GEN IN TUBING HANGER 3500 505.0 504. 1.61 NIPPLE CAMCO DS LANDING NIPPLE, 2 SEE' NO GO 2812 GAS OFT; s,a4v 10,588.3 5,]5)4 52.54 NIPPLE CARCO W-1 SELECTIVE LANDING NIPPLE 2812 10,5964 5,762.4 52.36 ANCHOR K ANCHOR, RUN WITH PACKER 2.992 10,597.3 5,7629 52.34 PACKER BAKER SAB -3 PERMANENT PACKER (SEAL ATTACHED) 3250 Gas uFT: >.1(q.3 10,6134 5,)RB 51.99 NIPPLECAMCOD LANDING NIPPLE, .75' MILLED OUT 2800 280') 10,624.7 5,))9.8 51.74 SOS BAKER SHEAR OUTUB, ELMDTTL during SWS 3015 PERF on 09/26/95 1 Gas UFr:en25 Other In Hole (WWI line retrievable plugs, valves, pumps, fish, etc.) Top nVol Topma Top IRK.) (ARE)1'1 Oes coin Run Dine rpt DN 10,620.0 5,]]6.9 51.84 CID4,RO L1-0llinerlinedupinto35"Ibg.Liner TDp@10.620. 1013120 1992 NER TOP g GFB UPr: e.rdT.3 10,982.0 6.00]0 1 49.e5 FISH 11l - DMY oO RK UMcb Dropped in Ralhts. g2B11995 923/1995 Perforations & Slots shin PaS UR', to.s4g.9 BIm IM e) rop 100) mrce) BMnVD) (nKe) unbd Zone pare Earn Ish'Wa Type Co. 10,6750 10.698.0 5, 1 5,625] C4, 2T-3] ]/62001 4.0 APERF SQUEEZED O NIPPLE,10,510.3 WWO07 1M80 T 14>]J.0 5,8144 C<, 7r-3) 12/1OM 8 lofted ANCHONR Vsas4 liner PAc6ER,1e59)3 10,)200 10,]90.0 5,8396 5,852.2 A-3, 2T-3) 926/1995 4.0 1PERF Oriented deg. ] tleg. fl IdwsidC of hole NIPPLE: 10.6134 Caement Squeegees TopKBI I0ZO, film DVG) r Top(M!B) BIm M 1nN8) MKBj SW paq Co. 10,6]5.0 10,698.0 5,8112 5.825] t CEMENT 6130200) SANDS UEEZE-MILLED' 4" ] 'W J 'u SOUEEZE BIT aos. f0,.7 Mandrel Inserts 10 ad L1At IATERAL; l0,M.P 16)))0\ N Tap IIBLB) Top lryDl MaFe Model Op big Sal Valve Types Lavern PonTRO Run lin)) (Rare Runwle Lam C. .m.B10o s ^ I aPERP:1ner.p CSAXD 60UEEZE',10.8 AE 1 2,194.3 2,00 6.3 CARCO MMM 1112 GAS LIFT LV RK IK 0.1 1,1930 12/232018 2 5,34].) - 3,4010 CAMCO MMM 1112 GAS LIFT OV RK 0.250 0.0 12/262018 100 ass 3 7,4063 4, 7 CARCO MMM 112 GAS LIFT DMY RK 0000 00 12/2]]2018 110 4 8.]12.5 4,8555 AMCO MMM 112 U -s LIFT My RK BOB 00 TO -0-61 8 1'30 N01e'. uq body DV 5 9,]3).3 5.303.9 CARCO MMM ttl2 GAS LIFT OV IRK I 0.186 00 110311997 6:30 fi 10542.6 5.730.1 CARCO MMM 112 GAS LIFT DMY RK O.00D 0.0 111 ... 010 1208 (PERF; tO.TID.p10,)AO.p- Notes: General & Safety sea End Date Anrrogfwn 211412001 NOTE: UNABLETO GET GUNS DOWNHOLE -4140"MAXDEPTH u uTERa1:10]W.610.T490 9/1312011 NOTE:VIaw Schematic wl Alaska SCM1emalic90 72 12 NOTE: Nor ABLE TO PULL OV AT 973T AFTER MANY ATTEMPTS 111 1 NOTE: View Schemelic w/Alaska Schematic 100 L1 IAtERK, 10'04.613.01]0 Ran 10.1020 PRODUCTION..1110T1.8 CTO2WUNERTOP: _ p8N0\ - sw.alin.r, ID,100.O1a.mo ConocoPhillips Mesas. Inc. KUP PROD WELLNAME 2T-37 WELLBORE 2T -37L1-01 naum,vlvmtezaa:3z PM Last Rev Reason verYsl.Paaell End mte -11-he Last MW er Rev Reason'. Installed GLD. Addeo Liner Top Depal I 2T -3.L1-01 jennalt ............._....__.._......................_............................. .....__. casing Strings HANGER, 3e.e caring pe.onPlion GG linl mpp TOP loner setDeP1N INKeI se oegn lrvGl... WVLen 0... aaee TOP Tnr..a L1-01 LATERAL 2318 1.99 10,619.9 14770 5.8)96 4.60 L-80 STL Notes: General & Safety End Oxh Annotation 111012019 NOTE'. View Schematic el Alaska Schematic 10.0 Ah CONDUCTOR, 4111 10 HIPPIE;& . UFT: 21..3 SURFACE; 41 H.I13 AmWx1 FNa-mai 00. 0.]3]0 GAB UFT', 5.11 Gly -11 r,],"3 Gas LIFT. 8 c25 GA3 UFT: P,)3).3 GM UFT; 10,0120 NIPPLE; I ast ANCHOR; 105964 PACKER; f0f1.3 NIPPLE, 1Q0104 ats; 1aM7 CTD 2 We LINER MP; 1g6Z10 APERF: Io.0Nv.0.1 aa0 GSM'O6GUEEa. f0,8]SO PROOUGTION; Y.] -It NdB I� I In 1! 11 I LI41 LAI IGSI 14m0 Uperations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Torre End Time our that Phase Op Code Activity Code Time P -T-% Operation Stan Depth (ftKB) End Depth(M(B) 11/20/2018 11/20/2018 3.50 MIRU MOVE RURD P Raise stairs & landings, lift & secure 0.0 0.0 12:00 1530 beaver slide, disconnect PUTZ, disconnet hi-liine, check tree bolts, continue RD checklist 11/20/2018 11/20/2018 1.50 MIRU MOVE RURD P Complete RD check list, trucks arrive 0.0 0.0 15:30 1700 at 16:30, pre job. 11/20/2018 11 /20/2018 2.30 MIRU MOVE RURD P Jack and pull service mod to edge of 0.0 0.0 17:00 19:18 pad, install jeep. Jack and pull sub mod forward - 5', Replace tree cap, pull sub completely off well, stage at edge of pad, install jeep. Perform environmental walk down with DSO. 11/20/2018 11/20/2018 1.90 MIRU MOVE MOB P Roll off pad, Peak Crew change on the 0.0 0.0 19:18 21:12 access road - 10 min, continue on to CPF3 11/20/2018 11/21/2018 2.80 MIRU MOVE MOB P Enter main spine from CPF3 an rout to 0.0 0.0 21:12 00:00 2T-37 11/21/2018 11/21/2018 3.30 MIRU MOVE MOB P Arrive at 2T -Pad 0.0 0.0 00:00 03:18 11/21/2018 11/21/2018 0.40 MIRU MOVE MOB P Drop off sub jeep, lay pit liner, drop 0.0 0.0 03:18 03:42 dozer 11/21/2018 11/21/2018 0.80 MIRU MOVE MOB P Spot sub over -well & lay mats 0.0 0.0 03:42 04:30 11/21/2018 11/21/2018 2.00 MIRU MOVE MOB P Crew change, turn pits around, hook 0.0 0.0 04:30 06:30 up cat to sow, spot pits, lay mats 11/21/2018 11/21/2018 2.50 MIRU WHDBOP MOB P Drop stairs & landings, connect PUTZ, 0.0 0.0 06:30 09:00 begin RU, NU ROPE Rig Accept 9:00 AM 11/21/2018 11/21/2018 1.00 MIRU WHDBOP RURD P Change out annular preventer 0.0 0.0 09:00 10:00 11/21/2018 11/21/2018 1.00 MIRU WHDBOP RURD P Energize Koomey, MU tiger tank hard 0.0 0.0 10:00 11:00 1 line, spot half -way house & shop 11/21/2018 11/21/2018 1.60 MIRU WHDBOP RURD P Complete RU, grease master, swab, & 0.0 0.0 11:00 12:36 tango valves, fluid pack lines & stack, clear floor, place barricades 11/21/2018 11/21/2018 0.40 MIRU WHDBOP BOPE P Shell test, good, PJSM 0.0 0.0 12:36 13:00 11/21/2018 11/21/2018 3.00 MIRU WHDBOP BOPE P Testing BOP'S, Test witnessed by 0.0 0.0 13:00 16:00 AOGCC Adam Earl, lest to 3500 psi / 2500 psi Upper 2" Fail Pass 11/21/2018 11/21/2018 2.50 MIRU WHDBOP BOPE P Install test joint, continue BOP test 0.0 0.0 16:00 18:30 completeBOP test - 5:30 hrs 11/21/2018 11/21/2018 2.50 SLOT WELLPR CTOP P Adjust tree and stack, struggle a bit 0.0 0.0 18:30 21:00 with leaning tree. Make up nozzle, stab on and line up to reverse circ, test inner reel iron / stripper- good. 11/21/2018 11/21/2018 0.60 SLOT WELLPR CTOP P Test DS PDL/ tiger tank line, 0.0 0.0 21:00 21:36 1 11/21/2018 11/22/2018 2.40 SLOT WELLPR CTOP P Instal night cap, lock out and cut e- 0.0 0.0 21:36 00:00 line, boot, stab on, pump slack, ramp up pump rate 3 times, unstabed, cut coil, found wire @ 1 ft back. Cut 20' of coil. rehead. 11/22/2018 11/22/2018 SLOT 0.0 00:00 00:00 Page 1127 ReportPrinted: 12/26/2018 Operations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur(hr) Phase op Code Aclivity Code TIme P-T-XStart operaticn Depth (WS) End Depth (fl(B) 11/22/2018 11/2212018 2.20 SLOT WELLPR CTOP P Complete instil of CC, pull test good, 0.0 0.0 00:00 02:12 rehead, test wire 2000/66, PT - good, Pumped open SSV and installed fusible rap. Measure coil thickness per SOP 0.208, 0.201, 0.206, & 0.204" 11/22/2018 11/22/2018 3.40 SLOT WELLPR PULD P PJSM, Tubing pressure 1846 psi. IA 0.0 55.0 02:12 05:36 1584 psi. Line up dow the tubing with seawale, bullhead 97 bible @ 3 bpm, circ pressure 1700 psi fell to 750 psi. Bled A to 1360 psi. PU & PD BHA#1, clean out assembly w D331 ridge set - 2.80" go 12.79" no go. 11/22/2018 11/22/2018 2.40 SLOT WELLPR TRIP P RIH w/ BHA#1 Cleanout Assembly, 55.0 10,510.0 05:36 08:00 1.2 bpm, erratic returns (gas), 80 fpm PUW = 18K @ 3030', PUW = 28K 6000', PUW = 38K @ 9000' 11/222018 11/22/2018 0.20 SLOT WELLPR DLOG P Log K1 for +6'correction, close EDC 10,510.0 10,545.0 08:00 08:12 11/222018 11/22/2018 0.30 SLOT WELLPR TRIP P Continue RIH, pumping 1.8 bpm FS = 10,545.0 10,765.0 08:12 08:30 331 psi, CWT= 15K, PUW =42K @ 10,627' ( just past D -nipple), 11/22/2018 1122/2018 0.10 SLOT WELLPR TRIP P PUH, PUW = 48K @ 10,765',1.85 10,765.0 10,510.0 08:30 08:36 bpm, still circulating out gas & well bore fluids 11/222018 11/222018 0.10 SLOT WELLPR DLOG P Log K1 for 0' correction, prep tool for 10,510.0 10,546.0 08:36 08:42 CCL 11/22/2018 11/22/2018 0.30 SLOT WELLPR DLOG P Perform CCL (10,510 to 10,725') 10,546.0 10,765.0 08:42 09:00 11/222018 11/22/2018 2.30 SLOT WELLPR TRIP P POOH, PUW = 40K, displacing to 10,765.0 55.0 09:00 11:18 used PowerPro, losing -0.4 bpm, open EDC, PJSM 11/22/2018 11/22/2018 1.30 SLOT WELLPR PULD P PUD BHA#1, stripped allen head on 55.0 0.0 11:18 12:36 bleed port (resolve) 11/22/2018 11/222018 1.00 SLOT WELLPR RGRP T Adjust riser alignment, swap out T& 0.0 0.0 12:36 13:36 1 1' riser for one 4' riser. 11/22/2018 1122/2018 1.20 PROD1 RPEQPT PULD P PJSM, PU & begiin PO BHA#2 HEW 0.0 73.0 13:36 14:48 1122/2018 11/22/2018 1.00 FRODI PULD T Unable to raise mast, trouble -shoot, 73.0 73.0 14:48 15:48 combinatioin of wind & hanging weight of PDL was not allowing raising of mast. Raised PDL's & mast raised 11/22/2018 11/222018 0.60 PROD1 RPEQPT PULD P Complete PO BHA #2, slide in cart, 73.0 73.0 15:48 16:24 1 MU to coil, tag up, set counters 11/22/2018 11/22/2018 2.30 PROD1 RPEQPT TRIP P RIH w/ 13HA#2, EDC open, density 73.0 10,540.0 16:24 18:42 1 out erratic, taking retums to TT, Bullhead 30 bbl 150K LSRV pill 11/22/2018 11122/2018 0.20 PROD1 RPEQPT DLOG P Tie into he K1 for a +5' correction 10,540.0 10,587.0 18:42 18:54 11/22/2018 11/22/2018 0.30 PROD1 RPEQPT WPST P WH, 123 psi, IA 1136 psi, OA 82 psi. 10,587.0 10,718.8 18:54 19:12 RIH to 10,718'. PU, 45 k lbs. RBIH to WS setting depth 10718.78', PU to neautrel weight, CT 36.9 k lbs, zero WOB, Stage pump up, sheared at 3900 psLS/D 4.5 k IDS WOB, PU 44 k IDS. HEW set, TOW @ 10,710' Page 2127 Report Printed: 1212611081 operations Summary (with Timelog L,t:pths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Our(M) Plass Op Cede Adiviq Code lime P -T -x Opetatlon Start Depth (WB) End Depth (111<13) 11/22/2018 11/22/2018 2.00 PROD1 RPEQPT TRIP P PU, bullhead 30 bbl -100 k SRV, open 10,718.8 80.0 19:12 21:12 EDC, Circulate bottoms up to the tiger tank. Pumping 2 bpm, loses 0.75 bpm, Bleed IAfrom 1140 psi to 962 psi over an hr. POOH losses @- 0.25 bpm. 11/22/2018 11122/2018 1.50 PROD1 RPEQPT PULD P PJSM, bump up, PUD BHA#2 while 80.0 0.0 21:12 22:42 pumping managed pressure. 11/22/2018 11723/2018 1.30 PROD1 WHPST PULD P PU & PD BHA *3, window milling 0.0 80.0 22:42 00:00 asssembly, WFD 1° fixed bend motor. 2.80" No go 11/23/2018 11/23/2018 0.70 PROD1 WHPST PULD P PU & PD BHA *3, bump up, set 0.0 82.0 00:00 00:42 counters. 11/23/2018 11/2372018 2.30 PROD1 WHPST TRIP P RIH W BHA#3. 82.0 10,550.0 00:42 03:00 SID @ 9223', 9285', 9566', PU's 37 k lbs. Close EDC, Pumps @ 0.8 bpm, continue in his without issue 11/23/2018 11/23/2018 0.20 PROD1 WHPST DLOG P Tie into Ki for a +7' correction. 10,550.0 10,576.0 03:00 03:12 11/23/2018 11/23/2018 0.20 PROD1 WHPST WPST P PU Wt 44 k IDs. RIH ad drytag TOB 10,576.0 10,714.2 03:12 03:24 @ 10,714.9' PU, 41k Ibs, CT 3976 psi, @ 1.89 bpm in, 1.29 bpm out - full open choke, WH 5 psi, IA 957 psi, OA 80 psi. Free spin diff 764 psi, CT Wt 14.4 k be, see motor work at 10,714.22 11/23/2018 11/23/2018 0.90 PROD1 WHPST WPST P CT 3976 psi, @ 1.89 bpm in, 1.29 10,714.2 10,715.2 03:24 04:18 bpm out - full open choke, Free spin diff 764 psi, CT Wt 14.4 k lbs, WOB 0.94 k Itis 11/23/2018 11/23/2018 1.70 PROD1 WHPST WPST P Engage auto drill 10,715.2 10,716.7 04:18 06:00 CT 4053 psi @ 1.88 bpm in, 1.42 bpm out. CT Wt 13.2 k Its, WOB 1.35 k be - ROP = 1 fithr 11/23/2018 11/23/2018 1.70 PROD1 WHPST WPST P Milling, CWT = 11.6K, WOB = 1.5K, 10,716.7 10,718.5 06:00 07:42 1.9 bpm in, 1.5 bpm out, rip = 887 psi, bleed down IA to 757 psi Mill exits 7" casing, call BOW @ 10,717.2', TOW @ 10,714.2' pump sweeps '• Pre -load PDL (Build BHA) 11/23/2018 11/232018 1.80 PROD1 WHPST WPST P Milling rat -hole, CWT= 13.81K, WOB = 10,718.5 10,739.0 07:42 09:30 1 2K, 1.9 bpm in, 1.57 bmp out, dip = 808 psi, circ = 4051 psi, TD ret -hole = 10,739' (29' from TOWS) 11/23/2018 11/23/2018 1.00 PROD1 WHPST REAM P Perform reaming passes, PUW = 40K, 10,739.0 10,739.0 09:30 10:30 HS, 30°R, 30°L (all down passes at HS), sand in samples from rat -hole TD, Dry drift up & down, clean, tag bottom, PUW = 40K 11/23/2018 11/2312018 0.30 PROD1 WHPST TRIP P Begin POOH, lose hi -line power, shut 10,739.0 10,739.0 10:30 10:48 I in choke, MP5 & MP9 Page 3127 ReportPrinted: 1 212 6/2 01 8 Vperations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Tuna Our(hr) PhaseOp cow Activity Code Time P -T-% operation DepthMB)MB) End Depth (flK8) 11/23/2018 11/23/2018 1.10 PROD1 WHPST WAIT T Work to resolve issue, unable to pump 10,739.0 10,548.0 10:48 11:54 with power down, HMI screens down, etc, fire up generators, difficulty getting on gen power, reaquire hi -line powerm, EMW dropped to 9.7 ppg With pumps off line 11/23/2018 11/23/2018 0.50 PROM WHPST WAIT T RBIH to 10,690', begin circulating 10,548.0 10,690.0 11:54 12:24 bottoms up, 18 bbl above bit, again lose hi -line, successfully get on generator power At second power failure: BHP = 3430 psi, WHP = 522 psi, MD = 10,585', time = 12:15 11/23/2018 11/23/2018 2.60 PROM WHPST TRIP P POOH, circulating bottoms up, tag up, 10,690.0 77.0 12:24 15:00 PJSM 11/23/2018 11/23/2018 1.30 PROD? WHPST PULD P PUD BHA#3, worked to pull down 77.0 0.0 15:00 16:18 weight bar in PDL (frozen shieve), string reamer & mill came out 2.80" no -go, LD tools 11/23/2018 11/23/2018 0.70 PROM DRILL CIRC P MU nozzle &jet stack, unstab, break- 0.0 0.0 16:18 17:00 off nozzle 11/23/2018 11/23/2018 1.40 PROD1 DRILL PULD P PD BHA #4 Build/Turn Assembly (2.4° 0.0 72.0 17:00 18:24 AKO motor, RB P104 bit), slid in cart, MU to coil, tag up, set counters, check pack offs - good. 11/23/2018 11/23/2018 1.90 PROM DRILL TRIP P RIH 72.0 10,531.0 18:24 20:18 11/23/2018 11123/2018 0.20 PROM DRILL DLOG P Tie into the K1 for +5.5' correction 10,531.0 10,559.1 20:18 20:30 11/23/2018 11/23/2018 0.20 PROD1 DRILL TRIP P Close EDC, PU wt 48 k lbs, contiune 10,559.1 10,739.0 20:30 20:42 in hole. Slight WOB bobble as we transited the window, 10,721'. 11/23/2018 11/23/2018 1.80 PRODt DRILL DRLG P CT 3846 psi, 1.85 bpm in, 1.61 bpm 10,739.0 10,920. 20:42 22:30 out, free spin diff 568 psi. Annular 3486 psi, 11.46 ppg at the window. CT wt 11.5 k lbs, WOB 2.0 k lbs, ROP 140-100 It, hr. Pump 5 x5 sweep timed out to TD Losses @ 02 bpm while holding 11.47 ppg 11/23/2018 11/24/2018 1.50 PROD1 DRILL TRIP P PU Wt 51 k lbs. POOH chasing 10,920.0 3,252.0 22:30 00:00 sweeps to surface, jog 7", pull out of hole. -1 k WOB tug and motor work @ 10,538' 11/24/2018 11/24/2018 0.60 PROD1 DRILL TRIP P PU Wt 51 k lbs. POOH chasing 3,252.0 72.0 00:00 00:36 sweeps to surface, jog 7", pull out of hole. -1 k WOB lug and motor work @ 10,538'. Holdig 11.5 ppg EMW. 11/24/2018 11/24/2018 1.90 PROD1 DRILL PULD P Bump up, PUD and LD BHA #4, 72.0 0.0 00:36 02:30 holding 11.5 ppg EMW. Reset crown saver and Floor saver post power outage. Lower section of BHA hung up in tree, worked wire, tried pumping and worked wire, no luck. 5x5 PJSM for change of scope, pressure un deploy, plug into tool and rotate HOT 180'. Stab PDL, pull with no luck, prep to pump again, had not pumped and BHA pulled free with no overfull. Continued to PUD / LD. Bit came out 2/4. chipped reamers from swinging bit with high bend out of hole. Page 4127 Report Printed: 1 212 612 01 8 operations Summary (with Tirri Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Siert Time EM TmaSta Dur(hd Phase Op Code Aavity Code Time PJA Operation (rt De pth rt lt) End Depth (Po(B) 11/24/2018 11/24/2018 1.40 PROD1 DRILL PULD P PU& PD BHA#5, L1 drilling assembly 0.0 80.0 02:30 03:54 0.5° AKO W BH P104 cutters, check pack offs -good, 11/2412018 11/24/2018 2.10 PROD1 DRILL TRIP P RIH 80.0 10,540.0 03:54 06:00 Park @ 500', Close EDC, shallow test agitator. "Note computer had issues restarting SARA monitoring program, possibly from yesterdays black outs. rate (bpm) Diff pressure (psi) 1.0 377 1.5 717 1.9 1030 11/24/2018 11/24/2018 0.10 PRODt DRILL DLOG P Tie into th K1 for+4.5' correction, 10,540.0 10,558.0 06:00 06:06 PUW =43K 11/24/2018 11/24/2018 0.30 PROD1 DRILL TRIP P Continue RIH, log RA tag. confirm 10,558.0 10,920.0 06:06 06:24 bottom of window @ 10,717' (RA @ 10,717") 11/2412018 11/24/2018 2.10 PROD1 DRILL DRLG P Drilling, FS = 983 psi @ 1.88 bpm, 1.7 10,920.0 11,320.0 06:24 08:30 bpm out, CWT= 14K, WOB = 2K, BHP = 3528 psi, WHIP = 9 psi, circ = 4729 psi, pump 5x5 sweeps, avg ROP = 190 fph 11.8 ppg @window, 1.87 bpm in, 1.72 bpm out, -9 bph losses 11/24/2018 11124/2018 0.20 PRODi DRILL WPRT P Wiper up -hole to EOB, PUW =45K 11,320.0 10,920.0 08:30 08:42 11/24/2018 11/24/2018 0.20 PROM DRILL WPRT P Wiper in-hole, RIW = 14K 10,920.0 11,320.0 08:42 08:54 11/24/2018 11/24/2018 0.40 PROD1 DRILL DRLG P Drilling, FS = 991 @ 1.88 bpm, 1.77 11,320.0 11,448.0 08:54 09:18 bpm out, CWT = 9.5K, WOB = 2.6K, BHP = 3621 psi, WHP = 80 psi, circ = 5000 psi, IA= 766 psi, OA= 108 psi 11/24/2018 11/24/2018 0.20 PROD! DRILL WPRT P 200' wiper, PUW = 56K, RIW = 13K 11,448.0 11,448.0 09:18 09:30 11/24/2018 11/24/2018 0.50 PRODt DRILL DRLG P Drilling, FS = 1050 psi, CWT = 12K, 11,448.0 11,550.0 09:30 10:00 WOB = 1.5K, BHP = 3666 psi, WHP = 52 psi Go on 100% losses @ 11,500', PUW = 51 K, annular dropped to 3380 psi 11/24/2018 11/24/2018 0.50 PROD1 DRILL WPRT P Wiper to 7" casing to circulate 11,550.0 10,699.0 10:00 10:30 bottoms up, pump 5x5 sweeps 11/24/2018 11/24/2018 0.80 PROD1 DRILL CIRC P Circulate bottoms up (allow sweeps to 10,699.0 10,699.0 10:30 11:18 exit), 1.88 bpm in, 1.5 bpm out, 11.8 ppg @ window (rate out increasing while in 7", likely pushing cuttings toward theif zone & healing) 11/24/2018 11/24/2018 0.50 PROD! DRILL TRIP P W/ backside cleaned up, RBIH to drill 10,699.0 11,550.0 11:18 11:48 in attempt to heal losses Stack on TOWS, PU, roll bit, get by clean log RA for+1.5' correction RIW = 14.7K 11124/2018 11/2412018 0.60 PROM DRILL DRLG P Drilling, FS = 994 psi @ 1.85 bpm in, 11,550.0 11,643.0 11:48 12:24 1.3 bpm out, CWT = 12K, WOB = 1.3K, BHP = 3638 psi, WHP = 98 psi, circ = 4555 psi 11,561' rate out drops to .8 bpm, builds to 1.25 bpm by 11,642', pull BHA wiper, PUW = 49K Page 5127 Report Printed: 1 212 612 01 8 operations Summary (with Timelog Lcpths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time EM Time Dur(hr) Phase Dip Code Activity Code Tune P -T -x Operation Slen Depth (flKB) End Depth(WEI) 11/24/2018 11/24/2018 1.00 PROD1 DRILL DRLG P Drilling, hit something hard, ROP 11,643.0 11,782.0 12:24 13:24 down to 12 fph (11,643'- 11,647'), CWT = 2K, WOB = 2K, BHP = 3577 psi, WHIP = 48 psi, circ = 4491 psi, -66% returns, avg ROP 139 fph 11/24/2018 11/24/2018 0.20 PROD1 DRILL WPRT P Wiperto fault at 11,550', PUW=51K, 11,762.0 11,782.0 13:24 13:36 RIW = 12K 11/24/2018 11/24/2018 1.20 PROM DRILL DRLG P Drilling, CWT= 10K, WOB= 1.81K, 11,782.0 11,940.0 13:36 14:48 BHP = 3660 psi, circ = 4971 psi, 1.85 bpm in, 1.38 bpm out, PUW = 58K @ 11,940', pump 5x5 sweeps, -72% returns, avg ROP = 132 fph 11/24/20111 11/24/2018 0.40 PROD1 DRILL WPRT P Wiper to window, PUW=49K, slight 11,940.0 10,690.0 14:48 15:12 heavy pull through window 11/24/2018 11/24/2018 0.90 PROD1 DRILL CIRC P Circulate bottoms up, 1.88 bpm in, 1.4 10,690.0 10,690.0 15:12 16:06 bpm out, with bottoms up, swap to hi - line (engineers on site), engineers see no anomolies 11/24/2018 11/24/2018 0.60 PROD1 DRILL WPRT P Wiper in-hole, log RA for+2' 10,690.0 11,940.0 16:06 16:42 correction, issues w/ hi -line, pull back into 7", swap back to generators, RIH, setdown @ BOW, PU, setdown again, spin bit, through clean 11/24/2018 11/24/2018 1.90 PROD1 DRILL DRLG P Drilling, FS = 1100 psi @ 1.88 bpm, 11,940.0 12,136.8 16:42 18:36 CWT = 2K, WOB = 2.3K, BHP = 3677 psi, WHIP = 78 pis, circ = 4845 psi 11/24/2018 11/24/2018 0.10 PROD1 DRILL WPRT P Pul short 100' wiper, PU Wt, 51, had 12,136.8 12,136.8 18:36 18:42 to start of a death spiral - diff sticking 11/24/2018 11/24/2018 1.20 PROM DRILL DRLG P Drilling 12,136.8 12,355.0 18:42 19:54 CT 4600 psi, FS = 1113 psi @ 1.9 bpm in 1.6 bpm out, CWT = 7K, WOB = 1.6 K, pump 5x5 ROP over interval - 182 ft/hr 11/24/2018 11/24/2018 0.30 PROM DRILL WPRT P PU as sweeps exit, PU Wt 49 k lbs 12,355.0 11,440.0 19:54 20:12 Chase sweeps up hole, 91 5'wiper to above the thief zone. Wiper#1 11/24/2018 11/24/2018 0.40 PROD1 DRILL WPRT P RBIH, 11,440.0 12,355.0 20:12 20:36 CT RIH Wt 11 it lbs 11/24/2018 11/24/2018 2.20 PROM DRILL DRLG P CT 4765 psi, @ 1.89 bpm in, 1.48 12,355.0 12,665.0 20:36 22:48 out, free spin 1149 psi, annular 3770 psi, CT Wt 10 k bs, WOB 1.3 it ROP over interval - 136 ft/hr PU's, 12,497 - 51 it, 12,550 51 k lbs, 12,595 60 k lbs, Starting to see weight transfer issues and more frequent pick ups, pump 5x5 in prep to pull wiper early. 11/24/2018 11/24/2018 0.30 PROM DRILL WPRT P PU as sweeps exit, PU Wt 49 k Ibs 12,665.0 11,864.0 22:48 23:06 Chase sweeps up hole, 800' wiper Wiper #2 11/24/2018 11124/2018 0.40 PROD1 DRILL WPRT P RBIH, 11,864.0 12,665.0 23:06 23:30 CT Wt 10 k lbs 11/24/2018 11/24/2018 0.30 PROM DRILL DRLG P CT 4822 psi, @ 1.88 bpm in, 1.53 12,665.0 12,721.0 23:30 23:48 out, free spin 1144 psi, annular 3742 psi, CT Wt 10 it bs, WOB 1.3k 11/24/2018 11/25/2018 0.20 PROD1 DRILL WPRT P PU Wt 55 it lbs 12,721.0 12,626.0 23:48 00:00 I short 200' wiper RBIH Page 6127 ReportPrinted: 12126/201i Uperations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SM Depen Slam TMEM Tena Our(hr) Phase Op Code Activity Code Time P -T -X Operation (N(B) End Depih(RKB) 11/252018 11/25/2018 0.20 PROM DRILL WPRT P Continue to RBIH 12,626.0 12,721.0 00:00 00:12 11/25/2018 11/25/2018 1.60 PROM DRILL DRLG P WH 0 psi, IA 767 psi, OA 125 psi 12,721.0 12,915.0 00:12 01:48 CT 4757 psi, @ 1.88 bpm in, 1.54 out, free spin 1079 psi, annular 3783 psi, CT Wt 7.8 k bs, WOB 1.1 k lbs. 11/25/2018 1125/2018 0.40 PROD1 DRILL DRLG P @ 12,915' returns rapidly fell from 12,915.0 12,941.0 01:48 02:12 1.54 bpm to 0.47 bpm Dril ahead watching returns hoping for healing PU'S 12913 - 52 k lbs 12939 - 56 k Itis 12,941 - 58 k lbs 11/2512018 11/252018 0.90 PROD1 DRILL WPRT P PU on early wiper to window for tie in 12,941.0 10,688.0 02:12 03:06 1k neg WOB pull @ 11,434' Returns healed in a linear manner from 0.47 bpm to 1.3 bpm ECD @ the windo tracked a similar trend from 11.1 ppg back to 11.6 ppg Drive by the RA tag for a +11' offset, did not reset counters. -2 k WOB tug @ 10,714 as we transited the window. 11/25/2018 11/25/2018 1.00 PROM DRILL CIRC P Jog the 7", pump5x5 and circ bottoms 10,688.0 10,663.0 03:06 04:06 up, Sweep didnt Cary much solids to he shaker. 11/25/2018 11/25/2018 0.30 PROD1 DRILL DLOG P RBIH, S/D @ 10,707 corrected to 10,663.0 10,758.0 04:06 04:24 10,719' PU to just above window, roll pump to 1.6 bpm, RBIH, window clean. Log RA tag for 11/252018 111252018 0.70 PROM DRILL WPRT P RBIH. RIW = 10.3K 10,758.0 12,941.0 04:24 05:06 11/25/2018 11/25/2018 1.00 PROD1 DRILL DRLG P Drilling, FS = 1078 psi @ 1.9 bpm, 1 12,941.0 13,021.0 05:06 06:06 bpm out, CWT = 4.3K, WOB = 1.2K, BHP = 3571 psi, circ = 4832 psi, drilling to heal losses 112512018 11/25/2018 0.50 PROD1 DRILL DRLG P Crew change, drilling, FS = 1025 psi 13,021.0 13,072.0 06:06 06:36 @ 1.77 bpm, 0.8 bpm out, CT = 6K, WOB = 1.3K, BHP = 3583 psi, circ = 4475 psi Returns @ 40% after 157' drilled, confer w/ town, decison made to drill on closed choke, pump 5x5 sweeps, await sweeps to bit 11/25/2018 11/252018 1.10 PROD1 DRILL WPRT P Wiper to window, PUW = 56K, clean 13,072.0 10,690.0 06:36 07:42 through window 11/25/2018 1125/2018 0.80 PROD1 DRILL CIRC P Circulate bottoms up (2 sets of sweep 10,690.0 10,690.0 07:42 08:30 exit), 1.87 bpm in, 1.24 bpm out in cased hole, Gose choke, bull -head 20 bbl (down coil) to theif zone @ 12,915', WHP up to 886 psi @ 1.6 bpm (11.9 ppg @ window) 11/25/2018 11/25/2018 0.90 PROD1 DRILL TRIP P RBIH to drill on closed choke, log RA 10,690.0 13,072.0 08:30 09:24 1 1 1 1 for +2' correction Page 7/27 Report Printed: 12126120181 operations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time Ertl Time Dur(hd Phase Op code Activity Code Time P-T-K Operation (ftKB) End Depth (ftK6) 11/25/2018 11/25/2018 0.90 PROM DRILL DRLG P Drilling, FS = 1101 psi @ 1.88 bpm, 13,072.0 13,171.0 09:24 10:18 WHP = 476 psi, CWT = 12.8K, annular = 3623 psi (11.6 ppg EMW), difficulty dropping inclination, allow weight to drill off, attempting to "wallow" small depression to allow downward progression (per DD), reduce WOB in attempt to drop 11/25/2018 11/25/2018 0.10 PROD1 DRILL WPRT P BHA wiper, PUW =52K, RIW=9K 13,171.0 13,171.0 10:18 10:24 11/25/2018 11/25/2018 2.40 PROD1 DRILL DRLG P Didling, FS = 1127 psi @ 1.85 bpm, 13,171.0 13,330.0 10:24 12:48 BHP = 3640 psi, WHP = 565 psi, circ = 4538 psi, closed choke Continue attempting to drop inclination @ reduced WOB & ROP per DD, begin succesffully dropping inclination, PLIW = 62K from 13,257' 11/25/2018 11/25/2018 0.90 PRODi DRILL DRLG P Drilling, BHP = 3675 psi (11.83 EMW), 13,330.0 13,386.0 12:48 13:42 WHP = 701 psi, circ = 4759 psi, CWT = -3.2K, WOB = 1.3K PUW = 50K @ 13357- 11/2512018 11/25/2018 0.40 PRODt DRILL WPRT P Wiper to above thief zone, PUW = 13,386.0 13,386.0 13:42 14:06 1 1 58K, RIW = 9K 11/25/2018 11252018 3.20 PRODt DRILL DRLG P Drilling, CWT =7K, WOB= 1.3K, BHP 13,386.0 13,600.0 14:06 17:18 = 3672 psi, WHP = 773 psi, circ = 4786 psi, PU off bottom from 13,332', allow geology to confer w/ town, go back to drilling 11/25/2018 11/25/2018 1.10 PROD1 DRILL WPRT P TD, pump sweeps while PUH into 7" 13,600.0 10,681.0 17:18 18:24 Saw -941 WOB tug as we puled past 12,922 - suspect theif zone. 11/25/2018 11125/2018 0.30 PROD1 DRILL DLOG P Park at 10681.88' MD, 5785.16 ND 10,681.0 10,681.0 18:24 18:42 Trap 3496 psi and watch fall to 3395 psi - 11.3 ppg EMW over 13 minute. Pressure trend is conliuning to drop. 11125/2018 11/2512018 0.30 PRODt DRILL DLOG P RIH, Tie into the RA lag for+4'foot 10,681.0 10,796.1 18:42 19:00 correction. Window clean. 11/25/2018 11/25/2018 0.90 PRODt DRILL TRIP P RIH, hole clean. 10,796.1 13,602.0 19:00 19:54 Trend change in annular pressure @ 12912', constant pressure jumpped to 3628 psi to 3655 psi 11/25/2018 11/25/2018 1.60 PROD1 DRILL DISP P PUH laying in liner running pill - 31.5 13,602.0 9,377.0 19:54 21:30 bbls., lop of pill @ 12,255' Panting flags, Yellow TO @ 12,383', slight -800 Ib WOB tug while pulling through the window @ 10707'. White window @ 9378' Open EDC, continue out of hole pumping mud @ 0.70 bpm, against a closed choke, replacing pipe voidage, holding 11.7 ppg EMW @ the window, losing -0.25 bpm. 11/25/2018 112520111 1.40 PROD1 DRILL TRIP P POOH, time out weighted liner running 9,377.0 95.0 21:30 22:54 1 1 pill prior to bumping up. 1125/2018 11/26/2018 1.10 PROD? DRILL DISP P Bullhead remaining LRP down coil @ 9,377.0 95.0 22:54 00:00 1 1.23 bpm, WH 1378 psi, CT 4205 psi, ECD @ the window 12.5 ppg. Page 8127 Report Printed: 12/26/2018 operations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log slant Tupe End Tmre Our (hr) Inhwe Op Code Activity Cotle Time P -T -X Operation Slant Depth (ftl(a) EM Depm (flKB) 11/26/2018 11/26/2018 0.80 PROD1 DRILL DISP P Complete bulhead kill. PJSM while 95.0 95.0 00:00 00:48 Wellhead bleeds down. Crack valve on riser to half drum, OWFF. no flow 11/26/2018 11/26/2018 1.20 PROD1 DRILL PULD P LD BHA#5 over a dead well, examine 95.0 0.0 00:48 02:00 pipe above connector - good. 4bbl per hr losses. Bit graded 1/2 broken reamers, plugged nozzle. 11/26/2018 11/26/2018 0.40 COMPZ1 CASING PUTB P Prep floor to PU and run liner - losses 0.0 0.0 02:00 02:24 Increased to 8 bbl/hr 11/26/2018 11/26/2018 2.50 COMPZI CASING PUTB P PU 40 joints 2-3/8" L-80 4.6 Vitt 0.0 1,244.2 02:24 04:54 slotted liner, 1244.18', under a shortly capped with a non ported bull nose, (1,245.4' LOA). #30 on the hook @ 4:18 ""Losses @ 8 bbl/hr 11/26/2018 11/26/2018 0.90 COMPZ1 CASING PULD P PU BHA #6 Liner Running Tools, slide 1,244.2 1,289.0 04:54 05:48 1 1 in cart, MU to coil, tag up, set counters 11/26/2018 11/26/2018 2.30 COMPZ1 CASING RUNL P RIH w/BHA #6, correct-0.2'to 1,289.0 11,755.0 05:48 08:06 window flag, PUW =46K, WOB =- 5.5K 11/26/2018 11/26/2018 0.10 COMPZ1 CASING DLOG P Log K1 for+6' difference, did not stop 11,755.0 11,779.0 08:06 08:12 pipe to correct 11/26/2018 11/26/2018 1.10 COMPZ1 CASING RUNL P Continue RIH, stack weight @ 11,779.0 13,012.0 08:12 09:18 12,513', PU & gel by, stack @ 13,030' multiple times, attempt differnt speeds, begin losing hole, PUH to 12,700', RBIH, stack @ -12,959', PU, make it to 13,012', PUW = 70K (-15K WOB), 11/26/2018 11/26/2018 0.70 COMPZ1 CASING RUNL P Unable to move liner up or down @ 13,012.0 13,012.0 09:18 10:00 13,012', Pull to 70K, -16K WOB, pull to 80K multiple times (-21 K WOB), no good, confer w/ town, decsion made to release off liner, bring up pumps, release off liner, PUW = 41K BOL = 13012'+ 6' correction to K1 = 13,018', TOL @ -11,772.6- 1112612018 11/26/2018 3.00 COMPZ1 CASING TRIP P POOH, tag up, flow check, PJSM, 225 13,012.0 45.0 10:00 13:00 1 1 1 bbl KWF arrives at rig, 11/26/2018 11/26/2018 0.80 COMPZ1 CASING PULD P LD liner running tools BHA #6, losses 45.0 0.0 13:00 13:48 - 24 - 28 bph 11/26/2018 11/26/2018 0.50 COMPZ1 CASING WAIT P Get on hi -line power, PJSM for PU 0.0 0.0 13:48 14:18 liner 11/26/2018 11/26/2018 2.30 COMPZ1 CASING PUTS P PU Liner Run #2 (ported BN, 2 10' 0.0 940.0 14:18 16:36 pups, 30 jnts slotted liner, shorty deployment sleeve) 11/26/2018 11/26/2018 0.40 COMPZ7 CASING PULD P PU liner running tools BHA V, slide in 940.0 1,004.0 16:36 17:00 cart, MU to coil, check packoffs, tag up, set counters 11/26/2018 11126/2018 2.80 COMPZ1 CASING RUNL P RIH w/ upper liner section, correct to 1,004.0 11,772.0 17:00 19:48 window flag +4.5', PUW = 47K, +1.5' offset from TD flag, arrive at setting depth, PUW =47K, RBIH, bring up pumps, release liner, PUW = 42K, TOL -10,812- Page 9127 Report Printed: 12/26/2018 Uperations Summary (with Timelog Depths) 2T-37 1 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log De Stan Depth Stan Time End Time Dur (Ir) Phase Op Code Activity Code Time P -T-% Operation (We) End Depth (Id(B) 11/26/2018 11/26/2018 1.50 COMM CASING DISP P Begin to displace well to DuoVis, 11,772.0 10,690.0 19:48 21:18 difficulty lifting KWF to surface, decision made to bull -head DuoVis down back -side, line back up down coil, circulate to evaluate losses, holding 11.6,-85% returns pumping 1.8 bpm Pre -load PDL w/ build BHA 11/26/2018 11/26/2018 1.90 COMM CASING TRIP P POOH, tag up, PJSM 10,690.0 45.0 21:18 23:12 11/26/2018 11/27/2018 0.80 COMPZ1 CASING PULD P PUD BHA#7 45.0 0.0 23:12 00:00 11/27/2018 11/2712018 COMPZ1 CASING PULD P PUD BHA #8 45.0 0.0 00:00 00:00 11/27/2018 11/27/2018 1.50 COMPZ1 CASING PULD P PU& PD BHA#8, Anchored liner top 0.0 52.0 00:00 01:30 billet. Checked pac offs - good 11/27/2018 11/27/2018 2.20 COMPZ1 CASING TRIP P RIH, holding 11.4 EMW, losses - 0.25 52.0 10,540.0 01:30 03:42 bpm 11/27/2018 11/27/2018 0.20 COMPZ1 CASING CLOG P Tie into the K1 for a + 5.5' correction. 10,540.0 10,570.0 03:42 03:54 ***Phase 3 called field wide 03:45 11/27/2018 11/27/2018 0.30 COMPZ1 CASING RUNL P PU Wt 42 k Itis @ 10,661, Close 10,570.0 10,795.0 03:54 04:12 EDC, RIH past window - clean, S/D 10,807' PU Wt 43 k lbs. S/D again, PU neutral wt 40 k, Verify oriented 30 ° ROHS, online w pump, sheared off at 3750 psi. S/D 2 k, PU Wt 44 k lbs, "' TOB @ 10795' Slips oriented 30° ROHS 11/27/2018 11/27/2018 2.00 COMPZ1 CASING TRIP P POOH replacing pipe void while 10,795.0 79.3 04:12 06:12 targeting 11.4 ppg EMW a@ the window. Losses -0.25 bpm 11/27/2018 11/27/2016 4.80 COMPZ1 CASING WAIT T Bump up, pump managed pressure 79.3 79.3 06:12 11:00 11.4 ppg EMW. - 10 bbls/hr loss rate "`Wait on weather 11/2712018 11/27/2018 1.20 COMPZ1 CASING PULD P Phase 2 called, PJSM, PUD BA # 8 79.3 0.0 11:00 12:12 11/27/2018 11/27/2018 0.40 PROD2 STK BOPE P Performs BOP function test 0.0 0.0 12:12 12:36 11/27/2018 11/27/2018 1.90 PROM STK PULD P PU & PD BHA#9, L1-01 build/turn 0.0 78.0 12:36 14:30 drilling assembly. BHA deployed on ODS PDL, assembly hung up multiple times while trying to deploy. Eventually worked through. Checked pack offs, good- but found some old pack off material above brass, cleaned and ensured oilier was functional. 11/27/2018 11/27/2018 2.00 PROM STK TRIP P RIH 78.0 10,530.0 14:30 16:30 11/27/2018 11/27/2018 0.20 PROM STK DLOG P Tie in for+6.0' correction, PU wt 44 k 10,530.0 10,600.0 16:30 16:42 lbs, Close EDC 11/27/2018 11/27/2018 0.20 PROM STK DLOG P continue to RIH 10,600.0 10,795.5 16:42 16:54 Page 10127 Report Printed: 1212612078 L,perations Summary (with Timelog bwpths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth De StartTime EM Tree Ow (hr) Phase Op Code AcWhr Code Time P -T -X Operslion (rt End Depth (fIKB) 11/27/2018 11/2712018 1.10 PROD2 STK DLOG P CT 3937 psi @ 1.89 bpm in 1.69 bpm 10,795.5 10,798.5 16:54 18:00 out, 3419 psi annular, holding 11.2 ppg EMW, 480 psi free spin, CT Wt 11.2 ppg, tag billet at 10795.5, stall @ 10795.8, PU, RBI, time mill, bottoms up has aluminum in it, mill 1, 2, and 3' as per RP. 11/27/2018 11/27/2018 0.89 PROD2 DRILL DRLG P Drill ahead, seems to be stacking 10,798.5 10,810.0 18:00 18:53 weight, back off on DHWOB, still making hole, continue attempting to drill ahead by WOB. 1112712018 11/27/2018 1.55 PROD2 DRILL DRLG P Increase ROP up to 60-80 fph, with 10,810.0 10,886.0 18:53 20:26 2.6 k DHWOB, pump pressure=4,013 psi, WHP=122, INMM=1.89 bpm, OMM=1.67 bpm, still maiintaining 11.2 ppg at the window. 11/27/2018 11/27/2018 0.80 PROD2 DRILL WPRT P TD build/turn, pump 5x5 sweep, pull 10,886.0 10,710.0 20:26 21:14 up hole, PUW 51 k, drift KOP, 1.4 k bobble at 10,810', billet is clean. POOH, PUW 48 k 11/27/2018 11/27/2018 2.00 PROD2 DRILL TRIP P Jog the 7", open EDC above window, 10,710.0 78.3 21:14 23:14 1 conliue POOH 11/27/2018 11/28/2018 0.77 PROD2 DRILL PULD P PUD, build/tum BHA# 78.3 0.0 23:14 00:00 11/28/2018 11/28/2018 1.80 PROD2 DRILL PULD P PD lateral drilling BHA#10 w/BH 0.0 80.3 00:00 01:48 P104 and ironside motor., check pac- offs (changed) 11/28/2018 11/28/2018 2.10 PROD2 DRILL TRIP P Tag up, reset counters depths, RIH w/ 80.3 10,540.0 01:48 03:54 BHA#10 (Ironside), surface test agitator 1.87 bpm at 5,092 psi, Diff -1,360 psi. 11/28/2018 11/2812018 0.20 PROM DRILL DLOG P Log the Kt formation marker 10,540.0 10,567.3 03:54 04:06 1 1 correction of plus 9.0' 11/28/2018 11/28/2018 0.20 PROD2 DRILL TRIP P Continue IH, set down 10,848', PUW 10,567.3 10,686.0 04:06 04:18 51 k, not correct TF, adjust TF RBIH past set down to bottom. 11/28/2018 11/28/2018 0.50 PROD2 DRILL DRLG P OBD, 1.9 bpm at 5,061 psi, DW ---1,265 10,886.0 10,888.0 04:18 04:48 psi, WHP=20, BHP=3,698, IA=757, OA=95, PUH, unable to drill ahead, DHWOB 1.05.0 k, heavy PU 63 k 11/28/2018 11/28/2018 2.00 PROD2 DRILL WPRT T PU to cased hole, circulate bottoms 10,888.0 10,622.0 04:48 06:48 up, jogged 7" while consulting with town. Clean black sand in the bottoms up. Increased the lubes in both hi and low vis pits to 2&2% 7761 lowtorque. 11/28/2018 11/28/2018 0.40 PROD2 DRILL WPRT T Load 5x5 sweep in the coil and RIH. 10,622.0 10,719.0 06:48 07:12 SID x5 times Q 10,719' PU's 42 - 45 k lbs, Pick up and spin the bit after each S/D. Last PU 55 k lbs, -5 k WOB. 11/282018 11/28/2018 0.20 PROM DRILL DLOG T PUH and tie into the Kt for a +3.5' 10,719.0 10,567.6 07:12 07:24 correction 11128/2018 11/28/2018 0.50 PROD2 DRILL TRIP T RBIH, S/D x210,722.5' 10,567.6 10,680.0 07:24 07:54 11/28/2018 11/28/2018 1.90 PROD2 DRILL TRIP T POOH for window dressing assembly, 10,680.0 88.4 07:54 09:48 MU new BHA w/o res tool and pre load drillers side PDL w window clean dressing assembly, park shallow, open EDC, bump up, space out. 11/28/2018 11/28/2018 1.00 PROD2 DRILL PULD T PUD BHA# 10, left BHA in ODS PDL. 88.4 0.0 09:48 10:48 Lay down Ironsides motor and agitator, Bit reamers werre hevily dammaged, graded 1/4. Page 11127 Report Printed: 1 212 612 01 8 AL A61 L,perations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SI(HKa)� $lal(Time End Time Dur(hr) Phase Op CoCeAcMM Code Time P -T -X Operation EMD NW8 ( ) 11/28/2018 11/28/2018 1.20 PROD2 DRILL PULD T PU and PD BHA#11, window dressing 0.0 65.0 10:48 12:00 assembly, Standard used window mill and string reamer, both 2.80 No Go. BH motor V AKO with the wear band turned in. 1.5' from tip of mill to bit box connection. 11/28/2018 11/28/2018 1.90 PROD2 DRILL TRIP T RIH 65.0 10,530.0 12:00 13:54 11/28/2018 11/28/2018 0.20 PROD2 DRILL DLOG T PU Wt 41 k lbs, Tie into the K1 for a - 10,530.0 10,557.0 13:54 14:06 5' correcion 11/282018 11/28/2018 1.40 PROD2 DRILL REAM T Close EDC, RIH, TF @ High Side 10,557.0 10,698.0 14:06 15:30 CT 3909 psi, @ 1.91 bpm in, 1.78 bom out, Diff 441 psi, 55% choke, WH 40 psi, 11.3 ppg EMW - annular 3415 psi, CT 13.5 k lbs, 10717.5 increase in WOB, +30-40 psi motor work. Te into the RA tag for+3' correction. Back ream @ HS from 10,474'to 10,716' RBIH, back ream @ 30° ROHS @ 1 ft/hr from 10,723' to 10,714' Flop HS RBIH, back ream @ 30° LOHS @ 1 ff/hr from 10,723'to 10715.3' flop HS RBIH, back ream @ 180'ROHS @ 1 ft/hr from 10,727'to 10,715' PUH Dry drift clean. 11128/2018 11/28/2018 1.90 PROD2 DRILL TRIP T POOH, open EDC 10,698.0 60.0 15:30 17:24 11/28/2018 11/28/2018 1.80 PROD2 DRILL PULD T Bump up, space out, inspect INJH 60.0 0.0 17:24 19:12 stripper (changeout pac-off), PUD BHA#11 11/2812018 11/28/2018 0.80 PROD2 DRILL PULD T PD, lateral drilling BHA#12 0.0 80.3 19:12 20:00 11/28/2018 11128/2018 0.20 PROD2 DRILL PULD T MU coil to CTT, perform surface test 80.3 80.3 20:00 20:12 (good -test), Tag up, reset counter depths. 11/28/2018 11128/2018 0.30 PROD2 DRILL TRIP T RIH, perform surface test on agitator 80.3 1,650.0 20:12 20:30 11/28/2018 112812018 0.40 PROD2 DRILL SVRG T Inspect pac-off assembly and goose 1,650.0 2,224.0 20:30 20:54 neck alignment 1128/2018 11282018 1.50 PROD2 DRILL TRIP T Continue IH 2,224.0 10,540.0 20:54 22:24 11/28/2018 11/28/2018 0.50 PROD2 DRILL DLOG T Log Kt marker, missed marker, 10,540.0 10,567.0 22:24 22:54 PBUH, re -start logging marker from 10,520', plus 28.5' 11/28/2018 11/28/2018 0.30 PROD2 DRILL TRIP T Jog in casing, circlating lubed 5x5 10,567.0 10,700.0 22:54 23:12 sweep to bit. 11/28/2018 11/28/2018 0.30 PROD2 DRILL TRIP T RIH thru window (clean 13 k CTSW), 10,700.0 10,886.0 23:12 23:30 set down @ 10,875' @ 10,878', work down to bottom, 0.6 bpm, bring pump up to FS 1.9 bpm at 5,200 psi, 11/282018 11/29/2018 0.50 PROD2 DRILL TRIP T PUW 58 k, work back to bottom @ 0.6 10,886.0 10,886.0 23:30 00:00 bpm, bring pump again, 4-6 k DHWOB, 11/29/2018 11/29/2018 1.00 PROD2 DRILL TRIP T Slowly moving towards bottom w/high 10,886.0 10,882.0 00:00 01:00 DHWOB, PUH 75 k, come down on pump gel weight back, continue PUH 11129/2018 11129/2018 0.20 PRO02 DRILL TRIP T RBIH, stacking CTSW, high DHWOB, 10,882.01 10,886.0 01:00 01:12 park coil @ 10886', 4-6 k DHWOB. Diff=2.000-2.100 psi, unable to drill ahead, PUH make call to TT for plan forward. Page 12127 Report Printed: 1 212 612 01 8 Operations Summary (with Timelog Depths) v. 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depen Stan TX EndTM Dur(ho Phase Op Gotla AGivity Cade Time P -T -X Op eraEon (MB) End Depth (Poke) 11/29/2018 11/29/2018 0.50 PROD2 DRILL TRIP T PUH 58 k, make call to TT, discuss 10,686.0 10,750.0 01:12 01:42 plan forward. 11/29/2018 11/29/2018 2.20 PROD2 DRILL TRIP T POOH 10,750.0 80.3 01:42 03:54 11/29/2018 11/29/2018 1.80 PROD2 DRILL PULD T PUD, drilling assembly#12, LD motor 80.3 0.0 03:54 0542 agitator 11/29/2018 11/29/2018 0.30 PROD2 STK PULD T PU Anchored billet 0.0 0.0 05:42 06:00 11129/2018 11/29/2018 0.80 PROM STK PULD T Crew change, PJSM, Scribe, Stab, 0.0 0.0 06:00 06:48 QTS PT failed, top O-ring leaking by. 11/29/2018 11/29/2018 0.40 PROD2 STK PULD T PJSM, unstab, break tool, relace both 0.0 0.0 06:48 07:12 QTS 0 -rings. re scdve, stab, 11/29/2018 11/29/2018 0.90 PROD2 STK PULD T PD BHA#13, skid cart, stab inector, 0.0 83.0 07:12 08:06 tool test good, bump up, set counters. 11/29/2018 11/2912018 1.80 PROD2 STK TRIP T RIH, 83.0 10,550.0 08:06 09:54 11/29/2018 11/29/2018 0.20 PROD2 STK DLOG T Tie into the Kt for +6.5- 10,550.0 10,578.1 09:54 10:06 11/29/2018 11/29/2018 0.30 PROD2 STK WPST T PU Wt, 47k, Close EDC 10,578.1 10,802.0 10:06 10:24 RIH through window, two sharp WOB spikes @ 10,751', and 10763' PU just under neutral, 42k lbs, online w/ pump, sheared @ 4000 psi, S/D 3.8 k WOB @ 10802.8- 11/29/2018 11/29/2018 0.10 PROD2 STK TRIP T PU 55 k, pulled - 50 k slowly reduced 10,802.0 10,675.0 10:24 10:30 to 44k C Wt, no indication of dragging anything on WOB. 11/2912018 11/29/2018 1.80 PROD2 STK TRIP T Park, reset depth, drop off pup length, 10,675.0 78.5 10:30 12:18 save billet as place holder for rod length. POOH 11/29/2018 11/29/2018 1.50 PROD2 STK PULD T Bump up, space out, PUD BHA#13. 78.5 0.0 12:18 13:48 11/29/2018 11/2912018 1.70 PROD2 STK PULD T PU and PD BA#14, AL1 -01 build 0.0 78.0 13:48 15:30 drilling assembly. Check pack offs, reran. 11/29/2018 11129/2018 1.90 PROD2 STK TRIP T RIH 78.0 10,530.0 15:30 17:24 11/29/2018 11/29/2018 0.20 PROD2 STK DLOG T Tie nto the K1 for a +5.5' 10,530.0 10,574.8 17:24 17:36 11/29/2018 11129/2018 0.30 PROD2 STK TRIP T PU Wt 47 k lbs Close EDC. 10,574.8 10,780.9 17:36 17:54 Continue to RIH, dry tag TOB 1@10,780- 11/29/2018 11/2912018 0.50 PROD2 STK KOST T PUH, obtain pump parameters, 1.9 10,780.9 10,781.1 17:54 18:24 bpm at 4,150 psi, Diff --462 psi, BHP=3474, WHP=15, IA=755, OA=84, time mill off of billet as per RP 11/29/2018 11/29/2018 1.50 PROD2 STK KOST T Stall motor, PUW=46 k, RBIH, stall 10,781.1 10,783.0 18:24 19:54 motor again, PUW=46 k, 1.9 bpm at 4,198 psi, Diff --465 psi, WHP=14, BHP=3,480, IA=759 , OA=89 11/29/2018 11/29/2018 1.00 PROD2 DRILL DRLG T Drill Ahead, 1.9 bpm at 4,206 psi, 10,783.0 10,868.0 19:54 20:54 Diff=755 psi, WHP=15, BHP=3,515, IA=765, OA=102 11/29/2018 11/29/2018 0.30 PROD2 DRILL WPRT T TD build section w/24.68° DLGS off of 10,868.0 10,753.0 20:54 21:12 billet, PUW 48 k, PUH to drift billet area. 11/29/2018 11/29/2018 0.20 PROD2 DRILL WPRT -IT -[Perform dry drift past KOP (clean) 10,753.0 10,792.0 21:12 21:24 11/29/2018 11/29/2018 0.30 PROM DRILL TRIP T PUH though window, jog inside 7", 10,792.0 10,621.0 21:24 21:42 open EDC. PUW 46 k Page 13/27 Report Printed: 1212612018 operations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log StaM1Time EM Time Dur(ho Pham Op Code Acli�dy Code Time P -T -X O pe�ation Start CapM (flK a End OepM (fll(B) 11/29/2018 11/29/2018 2.20 PROD2 DRILL TRIP T POOH, PUW 43 k (12 k bobble @ 10,621.0 72.2 21:42 23:54 10,579'), jog @ 4,800' and 3,000' 11/29/2018 11/30/2018 0.10 PROD2 DRILL PULD T PJSM, for PUD 72.2 0.0 23:54 00:00 11/30/2018 11/30/2018 1.50 PROD2 DRILL PULD T PUD, build BHA#14 72.2 0.0 00:00 01:30 11/30/2018 11/30/2018 1.50 PROD2 DRILL SVRG T Inspect pac-off assembly (destroyed), 0.0 0.0 01:30 03:00 1 1 PJSM, repair stripper assembly 11/30/2018 1113012018 0.75 PROD2 DRILL SVRG T Complete upper brass removed, full of 0.0 0.0 03:00 03:45 debris, clean and prep for re- installation, install brass, PT 3,500 psi (good -test) 11/30/2018 11/302018 1.60 PROD2 DRILL PULD T PJSM, PU/PD, Lateral Drilling BHA 0.0 78.2 03:45 05:21 #15 11/30/2018 11/30/2018 2.10 PROD2 DRILL TRIP T RIH, 78.2 10,530.0 05:21 07:27 Shallow test agitator rate bpm diff press psi 1.0 396 1.5 812 1.9 1220 11/30/2018 111302018 0.20 PROD2 DRILL DLOG T Tie into K1 for+11.5' 10,530.0 10,574.0 07:27 07:39 11/30/2018 11/30/2018 0.40 PROD2 DRILL TRIP T Continue to RIH, pumping min rate, 10,574.0 10,864.0 07:39 08:03 start seeing WOB @ 10,844' up to 4.5 k by 10856', PU's 45-46 k at low pump rates, work Coil to 10864' S/D with 6.5 k WOB while coming up on the pump to drill. PU 68 k lbs. 11/302018 11/30/2018 0.40 PROD2 DRILL TRIP T Reduce rate to min, CT weight 10,864.0 10,763.0 08:03 08:27 returned to normal - 44 k lbs, normal WOB, PUH above billet @ 10780'. Increase rate to 1.9 pm while slowly pulling p hole and pumping a 5x5 4% lube pill to the bit while jogging between the bottom of the window and build. 11/30/2018 11/30/2018 0.60 PROD2 DRILL TRIP T RIH on sweep to 10,865', increase 10,763.0 10,654,0 08:27 09:03 pump rate to 1.8 immediate WOB spike to 5 k lbs. Motor stalled, PU 50 k lbs, -1 k WOB, Increased pump rate while pulling up hole and WOB increased to -4 k lbs, and stalled. Off the pump, WOB returned to -1 k lbs. Attempt to RBIH at lowered pump rate, 1.3 bpm, similar results, high WOB, stall, heavy pick ups. Consult w town engineering. 11/30/2018 11/30/2018 2.00 PROD2 DRILL TRIP T POOH for BHA swap. 10,654.0 81.0 09:03 11:03 11/30/2018 11/30/2018 1.30 PROD2 DRILL PULD T Bump up, space out, unstab, inspect 81.0 0.0 11:03 12:21 pack offs - replace, PUD BHA#16. Bit 1/1 11/30/2018 11/30/2018 1.10 PROD2 DRILL PULD T PU 7 PD BHA#17, new Coil track, 0.0 62.0 12:21 13:27 less Res tool and agitator. Re ran high bend from the build, re bent to 0.5 ° AKO. Reran above A2 bit. 11/302018 11/30/2018 1.90 PROD2 DRILL PULD T RIH 62.0 10,530.0 13:27 15:21 1 1 checked coil @ 2400'- 2.001" x 2.001" 11/30/2018 11/302018 0.20 PROD2 DRILL DLOG T Log the Kt for a +4.5' cerrection 10,530.0 10,571.2 15:21 15:33 1 Page 14127 ReportPrinted: 12/26/2018 Operations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time EndTim our (hr) Phase 0 Code Op AGivily Code Tim P -T -X Operation Slart Depth (ftKB) De EiM Deem (M(B) 11/30/2018 11/30/2018 0.70 PROD2 DRILL DRLG T CT Pu Wt 47 kl bs, Close EDC, 10,571.2 10,680.0 15:33 16:15 cenfinue to RIH Pass through window - Clean, Run past billet clean - pumping 0.5 bpm RIH SID @ 10749', stacked 4.5 k, PU, 49 k drug -2.5 k wob PUH above billet clean, captured drilling parameters CT 4228 psi, @ 1.89 bpm, 509 psi diff. Pull up hole into 7" while calling town. 11/30/2018 11/30/2018 1.30 PROD2 DRILL DRLG T RBIH, pump to 1.90 bpm @ 10,790' 10,680.0 10,844.0 16:15 17:33 Zero WOB as soon as pressures stabilize, RIH @ 5ft7min see spikes in WOB with motor work @ 10805.7, 10807.7, 10817.8, and 10821.6' WOB to 4.75 k Ibs, PU 53 k, clean RBIH, Similarly stack weight and drill to 10826.61, PU 53 k lbs. Work our way to 10,844' 11/30/2018 11/30/2018 0.75 PROD2 DRILL DRLG T Drill thru tight spot, 1.9 bpm at 4,240 10,844.0 10,869.6 17:33 18:18 psi, Diff --565 psi, WHP=15, BHP=3,369, IA=769, OA=113 11/30/2018 11/30/2018 0.50 PROD2 DRILL DRLG T Lost diff, PUW 48 k, spike in annular 10,869.6 10,640.0 18:18 18:48 pressure, keep pulling up hole into the casing 11/30/2018 11/30/2018 1.50 PROD2 DRILL WPRT T Perform jog 10,640'-10,685', circulate 10,640.0 10,685.0 18:48 20:18 BU with sweeps, WeIIWORC indicating 1.8 CR, sample is showing bigger cuttings (cavings) pictures uploaded to s:drive. 11/30/2018 11/30/2018 0.30 PROD2 DRILL WPRT T Open EDC, PUH PUW 46k 10,685.0 10,535.0 20:18 20:36 11/30/2016 11/30/2018 020 PROM DRILL DLOG T Log Kt marker correction of plus 3.5' 10,535.0 10,554.0 20:36 20:48 11/30/2018 11/30/2018 0.30 PROD2 DRILL WPRT T RIH, Gose EDC 10,554.0 10,700.0 20:48 21:06 11/30/2018 11/30/2018 0.20 PROD2 DRILL WPRT T At 10,720' bring pump up to 0.6 pm, 10,700.0 10,727.0 21:06 21:18 set down @ 10,727', PUW 48 k 11/30/2018 11/30/2018 1.00 PROD2 DRILL DRLG T Drill through tight spot @ 1.9 bpm, 10,727.0 10,800.0 21:18 22:18 pass through tight spot at 3 fph, work down to next tight spot @ 10,771', PUH, RBIH, clean to 10,800' 11/30/2018 11130/2018 1.50 PROD2 DRILL WPRT T Pump 5x5 sweep, pull up into the 10,800.0 10,650.0 22:18 23:48 cased hole, circulating BU w/5x5 sweep, 11/30/2018 12/1/2018 0.20 PROD2 DRILL TRIP T Open EDC, POOH 10,650.0 8,872.0 23:48 00:00 12/1/2018 12/1/2018 1.50 PROD2 DRILL TRIP T Continue POOH w/open EDC 8,872.0 62.6 00:00 01:30 12/1/2018 12/1/2018 1.50 PROM DRILL SVRG T At surface, spaceout 1.2', breakoff 62.6 62.6 01:30 03:00 INJH, inspect pac-off (damaged), pull upper and lower brass confirm P/N's (good), install parts. 1211/2018 12/1/2018 0.80 PROD2 DRILL PULD T PUD drilling BHA#16 62.6 0.0 03:00 03:48 1 12/112018 12/12018 1.50 PROD2 DRILL PULD T PD, OH Anchored Billet 0.0 85.2 03:48 05:18 12/1/2018 12/12018 2.00 PROD2 DRILL TRIP T RIH 85.2 10,530.0 05:18 07:18 E0.20 12/1/2018 12/1/2018 PROD2 DRILL TRIP T Tie into K1 for+4' correction 10,530.0 10,668.0 07:18 07:30 Page 15127 Report Printed: 12/26/2018 Operations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stert Depth StattTme End Tme Dur (hr) Phase Op code Activity Code Tlme P-T-X Operation (W) End Depth(ftKa) 12/1/2018 12/1/2018 0.30 PROM DRILL WPST T PU Wt 47 k lbs, close EDC, Continue 10,668.0 10,784.3 07:30 07:48 to RIH. Start seeing WOB @ 10,751'„ 5-6 k, ease in hole to 10,784 bit depth. Pull to neutral CT Wt, pump on, sheared @ 4500 psi, set 2 k WOB. "TOB 10760 bottom 10784.3 12/1/2018 12/112018 1.80 PROD2 DRILL TRIP T POOH 10,784.3 75.4 07:48 0936 12/1/2018 12/1/2018 1.40 PROD2 DRILL PULD T PUD & LD BHA# 17. Billet setting 75.4 0.0 09:36 11:00 assembly. PU BHA#18, short tool fill entierly in PDL. 12/1/2018 12/1/2018 0.60 PROD2 DRILL SVRG T Skid cart, inspect pack offs, they were 0.0 0.0 11:00 11:36 shot - replaced, mechanic inspected system and goose neck. No smoking gun found. New pack offs are 1018 vintage, olderr ones that appeared to be working were 2017 vintage. 112 drum was not full of oil on this trip indicating it is going to the well. Did confirm oiler is oiling. 1211/2018 12/1/2018 0.70 PROD2 DRILL PULD T PD BHA# 18, AL1-01 KO build I tum 0.0 62.0 11:36 12:18 dilling assemby, 1.7'AKO, RR P104 cutters. 1211/2018 12/1/2018 1.90 PROD2 DRILL TRIP T RIH 62.0 10,525.0 12:18 14:12 12/1/2018 12/1/2018 0.20 PROM DRILL DLOG T Tie into Kt for+4' correction, 10,525.0 10,549.0 14:12 14:24 12/1/2018 12/1/2018 0.60 PROD2 DRILL TRIP T PU Wt 47k lbs, Close EDC, continue 10,549.0 10,660.0 14:24 15:00 to RIH. WOB at 10,760'0.48 k lbs, increased to 0.8k lbs @ 10765' suspect pushing the billet to bottom. Alert town engineering, PUH, tie into the RA tag for no correction, Pull through window @ 10 ftthr pumping 0.4 bpm, - 1k WOB tug @ 10,709' while pulling through the window. 12/1/2018 12/1/2018 0.50 PROD2 DRILL TRIP T Consulted w town, RBIH, WOB 10,660.0 10,696.0 15:00 15:30 increased from 5lbs to 800 lbs @ 10765' whe we had left the billet last time, pushed it to 10,768' WOB broke bak to 360 Ibs Pulled out of hole, Pull through window @ 10 ft/hr pumping 0.4 bpm, - 636lb WOB tug @ 10,709' while pulling through the window. 12/112018 12/1/2018 0.90 PROD2 DRILL TRIP T Open EDC, PUH, change of plans, 10,696.0 10,700.0 15:30 16:24 park at 10,700' MD, 5806 TVD Shut choke trapping 3405 psi BHP, EMW 11.28 ppg Watch pressure fall to 3165 psi - 10.48 EMW in 20 minutes 12/1/2018 12/1/2018 3.70 PROD2 DRILL CIRC T Transfer fluids in the pits, build 11.0 10,700.0 10,700.0 16:24 20:06 ppg completion fluid. 12/1/2018 12/1/2018 0.40 PROD2 DRILL CIRC T Send 11.0 ppg down the coil, 10,700.0 10,675.0 20:06 20:30 12/1/2018 12/1/2018 2.00 PROD2 DRILL TRIP T POOH while displacing well to 11.0 10,675.0 72.2 20:30 22:30 ppg completion Mid 1211/2018 12/1/2018 0.50 PROD2 DRILL PULD T At surface, check well for flow, PJSM 72.2 72.2 22:30 23:00 12/1/2018 1211/2018 0.50 PROD2 DRILL PULD T LD drilling tools on a dead well 72.2 0.0 23:00 23:30 Page 16127 ReportPrinted: 12126/2018 Uperations Summary (with Timelog bwpths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Slah DepN Slart Time End Time Durh Dur(ho Phase Op Code Adiviry Cotla Time P -T -X Operatlen Me)tEle EM Depth (MB) 12/1/2018 12/1/2018 0.25 COMPZI CASING PUTB T Prep RF for liner Ops, PJSM, PU 2 0.0 63.2 23:30 23:45 joints of slotted liner and 4.03 pup joint. 12/1/2018 12/2/2018 0.25 COMPZ1 CASING PUTB T RD RF from liner Ops 63.2 63.2 23:45 00:00 12/2/2018 12/2/2018 0.50 COMPZI CASING PULD T PU/MU CoilTrak tools, perform surface 63.4 107.4 00:00 00:30 test (good -test) 12/2/2018 12/2/2018 0.40 COMPZI CASING RUNL T RIH with Ll Liner Segment#3 107.4 1,850.0 00:30 00:54 12/2/2018 12/2/2018 0.40 COMPZI CASING RUNL T POOH, at surface, check well for flow 1,850.0 103.4 00:54 01:18 12/2/2018 12/2/2018 0.45 COMPZI CASING PULD T Unstab INJH, MU 4.03'solid pup joint 103.4 107.4 01:18 01:45 - 12/2/2018 1212/2018 1.80 COMPZ1 CASING RUNL T RIH with Ll Liner Segment#3 107.4 10,580.0 01:45 03:33 12/2/2018 1212/2018 0.20 COMPZI CASING RUNL T Log the Kt marker correction of 3.5' 10,580.0 10,604.0 03:33 03:45 12/2/2018 12/2/2018 0.20 COMPZI CASING RUNL T Continue IH 10,604.0 10,768.0 03:45 03:57 12/2/2018 12/2/2018 0.20 COMPZI CASING RUNL T Set down wieghl 0.5 k DHWOB, bring 10,768.0 10,704.8 03:57 04:09 pump up to 1.7 bpm/1,546 psi Diff, PUW 43 k 12/2/2018 12/212018 1.60 COMPZI CASING TRIP T PUH, remove liner length from 10,704.8 47.0 04:09 05:45 counters, POOH 12/212018 12/2/2018 1.60 COMPZI CASING TRIP T Bump up, flow chwck, LD BHA 19 47.0 0.0 05:45 07:21 over a dead well. Losses - 10 bola per hr. 5-6 bbls fill up might be a balance point. 12/2/2018 12/2/2018 1.20 PROD2 WHDBOP CIRC P Slab back on, jet stack turning coil 0.0 0.0 07:21 08:33 1 1 lover to water. 12/2/2018 12/2/2018 0.45 PROD2 WHDBOP CTOP P Test and chart inner reel iron , Valve 0.0 0.0 08:33 09:00 crew service tree valves. 12/2/2018 12/2/2018 1.00 PROD2 WHDBOP CTOP P Grease surface valves and BOP stack 0.0 0.0 09:00 10:00 12/2/2018 12/212018 1.50 PROD2 WHDBOP CTOP P Flood up and attempt to get a shell 0.0 0.0 10:00 11:30 test. Struggle to get shell test, find leaking bleeder #4, replace, same issues, dumped SSV, blocked in everything, found MM 6 & 2 leaking. Found metal debris in valve, cleanout metal and re -test, (good -shell test) Note some double blocked valves behind MM2& 6 have to be leaking too. 12/2/2018 12/2/2018 11.50 PROD2 WHDSOP BOPE P Start BOPE test, 4 fail passes C7, B7, 0.0 0.0 11:30 23:00 B3 and R2. test witnessed by AOGCC Matt Herrera. (250/3500/2500) 121212018 12/2/2018 0.50 PROD2 WHDBOP CTOP P RD testing equipment 0.0 0.0 23:00 23:30 12/2/2018 12/3/2018 0.50 PROD2 RPEQPT CTOP T Slide cart forward, trim 15' of coiled O.0 0.0 23:30 00:00 tubing, prep for CTC 12/3/2018 12/3/2018 2.00 PROM RPEQPT CTOP T Dress coil for CTC, install and pull test 0.0 0.0 00:00 02:00 35 k 12/3/2018 12/3/2018 0.45 PROM RPEQPT CTOP T PJSM, head up a -line, PT 4,000 psi 0.0 0.0 02:00 02:27 (good -test) 12/3/2018 12/3/2018 0.20 PROM RPEQPT CTOP T Pump open SSV, install (useable cap 0.0 0.0 02:27 02:39 (left hand thread), confirm hgih side on HEW 12/3/2018 12/3/2018 1.10 PROM RPEQPT CTOP T Test return line (removed for BOP test 0.0 0.0 02:39 03:45 trouble shooting)Slide cart forward stab onto INJH, fill the hole Page 17127 Report Printed: 1 212 612 01 8 Uperations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time Dur(hr) Phase Op Code Acd%*Code Time P -T -x Operation (M(B) End Depth(flKB) 12/3/2018 12/3/2018 1.00 PROD2 RPEQPT PULD T PSJM, PU/MU CoilTrak tools PU/MU 0.0 73.5 03:45 04:45 NS HEW, stab onto tools, perform surface test (good -test) 12/3/2018 12/3/2018 2.20 PROD2 RPEQPT TRIP T Check pac-off (good -rerun), tag up, 73.5 10,535.0 04:45 06:57 reset counters, RIH 1213/2018 12/3/2018 0.20 PROD2 RPEQPT DLOG T Tie nto the K1 for a + 4.5' correction. 10,535.0 10,562.2 06:57 07:09 12/3/2018 12/3/2018 0.30 PROD2 RPEQPT WPST T RIH to 10688.8 clean, PU Wt 47k lbs 10,562.2 10,688.8 07:09 07:27 RBIH to bit depth 10688.8, close EDC, PU to neutral weight - 42 k lbs. HS, pump on, WOB 0.19 k Ib, Saw 2200 psi o nhe CT and 1700 psi diff. SD 5.2 k lbs, WS set. ****TOWS 10,680.02- 1213/2018 12/3/2018 2.20 PROD2 RPEQPT TRIP T PU Wt 45 k lbs, Open EDC, reset 10,688.8 76.0 07:27 09:39 depths, POOH 1213/2018 12/3/2018 1.00 PROD2 RPEQPT PULD T Bump up, flow check, Well on a vac, 76.0 0.0 09:39 10:39 losses the same, - 8-10 bbla/hr. LD BHA#20 over a dead well. Inspect pack offs. Perfect -re-ran. 12/3/2018 12/3/2018 1.40 PROD2 WHPST PULD T W/O Motor, late call out, PU motor, 0.0 76.0 10:39 12:03 milling pup, (verified motor 1'), MU BHA, skid cat, stab on, bump up, reset counters. 12/3/2018 1213/2018 2.00 PROD2 WHPST TRIP T RIH swapping coil over to milling fluid, 76.0 10,550.0 12:03 14:03 SID @ 10,054', 6 k WOB, 54 k lbs PU, close EDC, pump 112 bpm, running 70 ft/min. no issues. 12/3/2018 12/3/2018 0.20 PROD2 WHPST TRIP T Tie into K1 marker for+6.5' correction. 10,550.0 10,575.0 14:03 14:15 12/3/2018 12/3/2018 1.80 PROD2 WHPST DISP T Open EDC, tum well over to milling 10,575.0 10,685.3 14:15 16:03 fluid, close the EDC. RIH and dry pinch point of HEW 10685.28'. SID 1.4 k lbs WOB. PU Wt 48 k lbs. 12/3/2018 12/312018 0.20 PROD2 WHPST CIRC T PUH, Set rate, CT 4132 psi @ 1.90 10,685.3 10,664.8 16:03 16:15 bpm in and 1.55 bpm out, Free spin 630 psi, WH 13 psi, IA 749 psi, OA 81 psi, Annular 3424 psi, 11.38 ppg EMW, CT Wt 14.8 k lbs, 12/3/2018 12/3/2018 3.30 PROD2 WHPST MILL T See motor work and WOB @ 10684.8' 10,684.8 10,689.5 16:15 19:33 10686.12' - have metal at the shaker 10688'- Exit the casing - bottom of the window. 12/3/2018 12/312018 1.00 PROD2 WHPST MILL T Drill ahead @ 10689'to 10,705' TD 10,689.5 10,705.0 19:33 20:33 Formation in the sample 12/312018 1213/2018 3.30 PROD2 WHPST REAM T Ream window area 30 L, 30 R, HS. 10,705.0 10,682.0 20:33 23:51 clean, dry drift window e>at (clean) 12/312018 1214/2018 0.16 PROD2 WHPST WPRT T Dry Drift window exit (clean) 10,682.0 10,705.0 23:51 00:00 12/4/2018 1214/2018 0.50 PROD2 WHPST CIRC T Circulate sweep down coil 10,705.0 10,670.0 00:00 00:30 12/4/2018 12/4/2018 1.80 PROD2 WHPST TRIP T POOH, chasing sweep to surface 10,670.0 77.0 00:30 02:18 12/4/2018 12/4/2018 1.30 PROD2 WHPST PULD T At surface, space out, PUD milling 77.0 0.0 02:18 03:36 assembly 12/4/2018 12/4/2018 1.20 PROD2 DRILL PULD T PD Build Section BHA# 22, PU 0.0 72.2 03:36 04:48 CoilTrak tools, perform surface test (good -test) 12/4/2018 12/4/2018 2.00 PROD2 DRILL TRIP T Open Rams, tag up, reset counters, 72.2 10,530.0 04:48 06:48 RIH 1 Page 18127 Report Printed: 1 212 612 01 8 Operations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stag Tare End Time D" (hr) phase Op Code Activity Code Time P4A Operation (flKB) End Depth(MB) 12/4/2018 12/412018 0.20 PROM DRILL DLOG T Log the K1 marker correction of minus 10,530.0 10,558.0 06:48 07:00 3.51, PUW 46 k 12/4/2018 12/412018 0.40 PROD2 DRILL TRIP T Continue IH, close EDC, set down at 10,558.0 10,683.0 07:00 07:24 10,683', 10,682', and 10,661'. 12/4/2018 1214/2018 0.20 PROD2 DRILL TRIP T PUH 10,683.0 10,530.0 07:24 07:36 12/4/2018 12/4/2018 0.20 PROM DRILL DLOG T Log the K1 marker, missed marker. 10,530.0 10,500.0 07:36 07:48 1 1 1 PUH PUW 46 k 12/4/2018 12/4/2018 0.20 PROM DRILL CLOG T Log the K1 marker correction of plus 10,500.0 10,558.0 07:48 08:00 26.0' 12/4/2018 12/4/2018 0.25 PROD2 DRILL TRIP T Continue IH through window 10,558.0 10,705.0 08:00 08:15 12/4/2018 1214/2018 1.75 PROD2 DRILL DRLG T OBD, 1.9 bpm at 4,120 psi, Diff -468, 10,705.0 10,920.0 08:15 10:00 BHP=3,521, WHP=220, IA=768, OA=122 12/4/2018 12/4/2018 0.20 PROD2 DRILL WPRT T TD Build Section, PUH PUW 46 k 10,920.0 10,650.0 10:00 10:12 12/4/2018 12/42018 0.50 PROD2 DRILL WPRT T Jog the 7' Clean, Open EDC 10,650.0 10,654.0 10:12 10:42 12/4/2018 12/4/2018 2.00 PROM DRILL TRIP T POOH, performing 500' jog @ 2,200' 10,654.0 72.2 10:42 12:42 12/4/2018 12/42018 0.90 PROD2 DRILL PULD T PJSM, PUD build assembly with high 72.2 0.0 12:42 13:36 bend motor 12/4/2018 12/4/2018 1.30 PROD2 DRILL PULD T PD Lateral Drilling Assembly #23 0.0 78.2 13:36 14:54 12142018 1214/2018 2.00 PROD2 DRILL TRIP T Stab INJH, test CoilTrak tools (good- 78.2 10,530.0 14:54 16:54 test), tag up reset counters, RIH, surface test agitator @ 473' 12/42018 12/4/2018 0.20 PROM DRILL DLOG T Log the K1 marker correction of minus 10,530.0 10,563.0 16:54 17:06 5.5', PUW 44 k 12/4/2018 12/4/2018 0.10 PROD2 DRILL TRIP T Continue IH w/closed EDC 10,563.0 10,920.0 17:06 17:12 12/4/2018 12/412018 3.10 PROD2 DRILL DRLG T OBD, 1.9 bpm at 4640SI FS, 10,920.0 11,321.0 17:12 20:18 BHP=3519, New mud @ bit 10,933' 12/4/2018 12/4/2018 0.30 PROD2 DRILL WPRT P Pull wiper to bottom of build, 400' 11,321.0 11,321.0 20:18 20:36 wiper #I, PUW=52K 12/42018 12/4/2018 1.10 PROD2 DRILL DRLG P 11321', Drill, 1.9 BPM @ 4697 PSI FS, 11,321.0 11,485.0 20:36 21:42 BHP=3572 12/4/2018 12/4/2018 0.10 PROD2 DRILL WPRT P Pull 1 00'BHA wiper, PUW=55K 11,485.0 11,485.0 21:42 21:48 j 12/42018 12/42018 2.00 PROD2 DRILL DRLG P 11485', Drill, 1.9 BPM @ 4697 PSI FS, 11,485.0 11,720.0 21:48 23:48 BHP=3572 12/4/2018 1215/2018 0.20 PROD2 DRILL WPRT P 11720, Wiper to bottom of build, 11,720.0 11,323.0 23:48 00:00 PUW=56K 12/5/2018 12/5/2018 0.40 PROM DRILL WPRT P Continue wiper to bottom of build, 11,323.0 11,718.0 00:00 00:24 Clean trip up and down 12/5/2018 12/512018 1.30 PROD2 DRILL DRLG P 11,718', Drill 1.9 BPM @ 4745 PSI FS, 11,718.0 11,842.0 00:24 01:42 BHP=3670 12/5/2018 1215/2018 0.20 PROD2 DRILL WPRT P 11842 Pull 100' BHA wiper, PUW=55K 11,842.0 11,842.0 01:42 01:54 12/5/2018 12/52018 1.30 PROM DRILL DRLG P 11,842 Drill, 1.9 BPM @ 4840 PSI FS, 11,842.0 11,945.0 01:54 03:12 BHP=3623, Loosing surface weight. 12/5/2018 12/5/2018 0.10 PROD2 DRILL WPRT P 11945, Low ROP and srface weight, 11,945.0 11,945.0 03:12 03:18 Pull 1 00'wiper for low surface weight. Pump sweeps 12/5/2018 12/52018 0.30 PROD2 DRILL DRLG P 11945', Drill, 1.89 BPM @ 4760 PSI 11,945.0 11,965.0 03:18 03:36 FS, BHP=3660, RIW=-5K. DHWOB=1 K 12/5/2018 12/5/2018 1.00 PROD2 DRILL WPRT P 11,965', Sweeps coming out. Pull 11,965.0 10,675.0 03:36 04:36 I wiper to window, Jet 7 inch to tubing tail Page 19127 Report Printed: 12126120181 operations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tme Eq Tana our (hr) Pnese Op Code Activit' Coda Tune P -T -X Operation SWM DepN (WO) End DepN (WB) 12/5/2018 12/5/2018 0.30 PROD2 DRILL WPRT P Jet the 7" to the tubing tail 10,675.0 10,625.0 04:36 04:54 - 12/5/2018 12/5/2018 0.15 PROD2 DRILL WPRT P RIH 10,625.0 10,700.0 04:54 05:03 12/5/2018 12/5/2018 0.15 PROD2 DRILL DLOG P Log the RA marker correction of plus 10,700.0 10,723.0 05:03 05:12 4,5' 12/5/2018 12/5/2018 0.40 PROM DRILL WPRT P RBIH 10,723.0 11,965.0 05:12 05:36 12/512018 12/5/2018 0.50 PROD2 DRILL DRLG P BOBD, 1.9 bpm at 4,925 psi, Diff=425 11,965.0 12,006.0 05:36 06:06 psi, WHP=50, BHP=3,750, IA=776, OA=155 12/5/2018 12/5/2016 0.20 PROD2 DRILL WPRT P 200' wiper up hole, PUW 50 k 12,006.0 12,006.0 06:06 06:18 12/5/2018 1215/2018 0.20 PROD2 DRILL DRLG P BOBD, 1.9 bpm at 4,810 psi, Diff -733 12,006.0 12,008.0 06:16 06:30 psi, WHP=50, BHP=3,750, IA=776, OA=155 12/5/2018 12/512018 0.45 PROD2 DRILL WPRT P 500', Wiper up hole, PUW 55 k 12,008.0 12,008.0 06:30 06:57 12/5/2018 12/5/2018 1.00 PROD2 DRILL DRLG P BOBD, 1.9 bpm at 4,810 psi, Diff=730 12,008.0 12,047.0 06:57 07:57 psi, WHP=50, BHP=3,750, IA=776, OA=155 1215/2018 1215/2018 0.15 PROD2 DRILL WPRT P 200'. Wiper up hole, PUW 57 k 12,047.0 12,047.0 07:57 08:06 12/5/2018 12/5/2018 3.80 PROD2 DRILL DRLG P BOBD, 1.9 bpm at 4,815 psi, Diff --730 12,047.0 12,292.0 08:06 11:54 psi, WHP=50, BHP=3,750, IA=776, OA=155 12/5/2018 1215/2018 0.50 PROM DRILL WPRT P Wiper up to the window PUW 56 k 12,292.0 10,630.0 11:54 12:24 12/MO18 12/5/2018 0.45 PROD2 DRILL WPRT P Jog the 7" clean w/sweeps, circulate 10,630.0 10,530.0 1224 12:51 BU, Open EDC, PUH to logging depth 12/5/2018 12/5/2018 0.20 PROD2 DRILL DLOG P Log the Kt correction of plus 4.0' 10,530.0 10,563.0 12:51 13:03 12/5/2018 12/5/2018 0.20 PROD2 DRILL WPRT P Continue IH, close EDC 10,563.0 10,650.0 13:03 13:15 12/5/2018 12/5/2018 0.75 PROD2 DRILL WPRT P Continue wiper back in hale. RIW 11 k 10,650.0 12,292.0 13:15 14:00 12/5/2018 12/5/2018 2.75 PROM DRILL DRLG P BOBD, 1.9 bpm at 4,815 psi, 12,292.0 12,457.0 14:00 16:45 Diff -1,103 psi, WHP=17, BHP=3,771, IA=778, OA=156 12/5/2018 12/5/2018 3.35 PROM DRILL DRLG P BOBD, 1.9 bpm at 4,815 psi, 12,457.0 12,539.0 16:45 20:06 Diff -1,220 psi, WHP=17, BHP=3,771, IA=778, OA=158 12/5/2018 121512018 0.10 PROD2 DRILL WPRT P BHA Wiper, PUW=62K. Low surface 12,539.0 12,537.0 20:06 20:12 weight, Low ROP. Pump remaining screen clean from pill pit #1. No obvious improvement 12/5/2018 12/5/2018 1.10 PROD2 DRILL DRLG P 12537', Drill 1.87 BPM @ 5360 PSI 12,537.0 12,560.0 20:12 21:18 FS, BHP=3800 12/5/2018 12/5/2018 0.10 PROM DRILL WPRT P 12560, Stacking, 100' BHA wiper, 12,560.0 12,559.0 21:18 2124 1 PUW=65K 12/5/2018 12/5/2018 2.00 PROD2 DRILL DRLG P 12559', Drill. 1.66 BPM @ 5260 PSI 12,559.0 12,631.0 21:24 23:24 1 FS, BHP=3817, RIW=-3K, DHWOB=1.6, Prep for mud swap 12/5/2018 12/5/2018 0.10 PROD2 DRILL WPRT P 12631', BHA wiper, PUW=59K 12,631.0 12,631.0 23:24 23:30 12/5/2018 12/6/2018 0.50 PRO D2 DRILL DRLG P 12631', Drill, new mud at bit @ 12,631.0 12,651.0 23:30 00:00 12,640'.1.86 BPM @ 5070 PSI IF BHP=3790 12/6/2018 12/6/2018 1.60 PROD2 DRILL DRLGP Drilling, 1.88 BPM @ 4775 PSI FS, 12,651.0 12,692.0 00:00 01:36 BHP=3685, RIW -4.51K Page 20127 Report Printed: 1212612018 Operations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time EM Time our (hr) Phase Op Code Activity Cme Time P -T -X Operation S a Depth (@ Ka) Ertl Depth tftKa) 12/6/2018 12/6/2018 2.10 PROD2 DRILL WPRT P Pull wiper to end of build @ 10,920'. 12,692.0 12,692.0 01:36 03:42 Clean trip up. Stacked out @ 11,931 PUH. Stack out @ 11919. PUH and work pipe. Went through @ 1 BPM. Run down to 11,950. Bring pumps on @ 1.7 and back ream up to 11990. RBIH had to reduce rate to get through. Continue to bottom. Stack @ 11,969. PUH and work through. Geo calls this transition area between A2 andA3 lower silt. Below 12,100 back in A3 pay area bring rate up to 1.6 BPM. Stack out @ 12584. Pick up and work through 12/6/2018 12/6/2018 3.40 PROD2 DRILL DRLG P Get to bottom, Drill, 1.88 BPM @ 4775 12,692.0 12,742.0 03:42 07:06 PSI FS, BHP=3603, RIW=-5K, DHWOB=.92, ROP=20 FPH 12/6/2018 12/6/2018 0.15 PROD2 DRILL WPRT P BHA wiper up hole PUW 58 k 12,742.0 12,742.0 07:06 07:15 12/6/2018 12/6/2018 3.75 PROD2 DRILL DRLG P BOBD, 1.85 bpm at 4843 psi, 12,742.0 12,832.0 07:15 11:00 Diff -1,134, WHP=50, BHP=3,791, IA=787, OA=211 12/6/2018 12/6/2018 1.35 PROD2 DRILL WPRT P BHA wiper up hole PUW 62 k, pump 12,832.0 12,832.0 11:00 12:21 1 115 bbl screen clean and drillzone. 12/6/2018 12/6/2018 0.45 PROD2 DRILL DRLG P BOBD, 1.85 bpm at 4843 psi, 12,832.0 12,885.0 12:21 12:48 Diff --1,134, WHP=50, BHP=3,791, IA=787, OA=211 12/6/2018 12/6/2018 0.15 PROD2 DRILL WPRT P BHA wiper up hole PUW 61 k 12,885.0 12,885.0 12:46 12:57 12/6/2018 12/6/2018 0.50 PROD2 DRILL DRLG P BOBD, 1.85 bpm at 4843 psi, 12,885.0 12,902.0 12:57 13:27 Diff=1,134, WHP=50, BHP=3,791, IA=787, OA=211 12/6/2018 12/6/2018 2.75 PROD2 DRILL DRLG P BOBD, 1.85 bpm at 4843 psi, 12,902.0 13,050.0 13:27 16:12 Diff=1,134, WHP=50, BHP=3,791, IA=787, OA=211, pump 40 bbl (1 ppb alpine beads and 2% 776, and 2% Lo- torq) 12/6/2018 12/6/2018 1.70 PROD2 DRILL WPRT P Wiper up to the casing PUW 51 K, Jet 13,050.0 10,530.0 16:12 17:54 7" tibing to TT, PUH to Kt marker 12/6/2018 12/6/2018 0.20 PROD2 DRILL DLOG P Log K1 marker for+10', close EDC 10,530.0 10,565.0 17:54 18:06 12/6/2016 12/6/2018 1.20 PROD2 DRILL WPRT P Continue wiper trip back in hole. Set 10,565.0 13,056.0 18:06 19:18 down @ 11,978 and work through with reduced pump rate 12/6/2018 12/6/2018 3.70 PROD2 DRILL DRLG P 13056', Drill, 1.9 BPM @ 5280 PSI 13,056.0 13,130.0 19:18 23:00 FS, BHP=3905, RIW=-6K, DHWOB= 1.21K. Low ROP - 20 FPH. Pump 20 BBI beaded lube pill. No inprovement. 12/6/2018 12/6/2018 0.30 PROM DRILL WPRT P BHA Wiper, PUW=62K 13,130.0 13,130.0 23:00 23:18 12/6/2018 12/7/2018 0,70 PROD2 DRILL DRLG P 13130', Drill, 1.89 BPM @ 5310 PSI 13,130.0 13,141.0 23:18 00:00 FS, BHP=3880 12!7/2018 12/7/2018 0.10 PROD2 DRILL DRLG P 13141', drill, 1.88 BPM @ 5310 PSI 13,141.0 13,143.0 00:00 00:06 1 FS, BHP=3880 12/7/2018 12/7/2018 0.10 PROD2 DRILL WPRT P BHA short wiper, PUW=57K 13,143.0 13,143.0 00:06 00:12 1 12/7/2018 12/7/2018 1.30 PROD2 DRILL DRLG P 13143', Drill, 1.88 BPM @ 5310 PSI 13,143.0 13,178.0 00:12 01:30 FS, BHP=3910, RIW=-5.4K, DHWOB=1.2 12/7/2018 12/7/2018 2.50 PROD2 DRILL DRLG P 13178, Drilling, lube pill at bit, 1.88 13,178.0 13,234.0 01:30 04:00 BPM @ 5310PSI FS, BHP=5310, Frequent pick ups for weight transfer Page 21127 Report Printed: 12/26/2018 Operations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tme EM Time our (hr) Phase Op Cotle Activity code lime P-T-X Operation Start Depth(ftKB) End Depth(ftKB) 12/7/2018 0.85 PROD2 DRILL DRLG P 13234, Lube pill at bit. recip 100' 13,234.0 13,241.0 04:00 11217/2018 04:51 before lube reached bottom, PUW=57K 1.88 BPM @ 5310 PSI FS, BHP=3919 12/7/2018 12/7/2018 0.20 PROD2 DRILL WPRT P 200' wiper up hole, PUW 55 k 13,241.0 13,241.0 04:51 05:03 12/7/2018 12/7/2018 1.75 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 5,310 psi, 13,241.0 13,277.0 05:03 06:48 Diff-150 psi, WHP=138, BHP=3,943, IA=787, OA=250 12/7/2018 12/7/2018 0.15 PROD2 DRILL WPRT P BHA wiper up hole, PUW 62 k 13,277.0 13,277.0 06:48 06:57 12/7/2018 12/7/2018 0.55 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 5,310 psi, 13,277.0 13,285.0 06:57 07:30 Diff--150 psi, WHP=138, BHP=3,943, IA=787, OA=250 12/7/2018 12/7/2018 1.00 PROD2 DRILL WPRT P Wiper to the windoww/sweeps, PUW 13,285.0 10,657.0 07:30 08:30 59 k "' Note: Noticed some higher pulling weight thru EOB 12/7/2018 12/7/2018 0.50 PROD2 DRILL WPRT P Jet the 7" clean w/sweeps, function 10,657.0 10,657.0 08:30 09:00 1 1 1 open EDC 12/7/2018 12/7/2018 2.00 PROD2 DRILL TRIP P POOH, pumping 2.0 bpm @ 4,510 psi, 10,657.0 78.3 09:00 11:00 performing 500' jog from 1,500' 1217/2018 12/7/2018 1.25 1 PROD2 DRILL PULD P At surface, spaceout, PUD drilling 78.3 0.0 11:00 12:15 BHA#23 12/7/2018 12/7/2018 0.50 PROD2 DRILL PULD P Inspect BHA, check motor and agitator 0.0 0.0 12:15 12:45 (good) 12/7/2018 12/7/2018 1.75 PROD2 DRILL PULD P PJSM, PD drilling BHA #24 0.0 78.3 12:45 14:30 12/7/2018 12/7/2018 0.25 PROD2 DRILL PULD P Slab upper quick sub, surface test 78.3 78.3 14:30 14:45 Coikrak tools (good-test) 12/7/2018 12f7/2018 2.00 PR0D2 DRILL TRIP P RIH, w/lateral drilling BHA#24, 78.3 10,540.0 14:45 16:45 surface test agitator (good-test) 12/7/2018 12/7/2018 0.20 PROD2 DRILL DLOG P Log the K1 marker correction of minus 10,540.0 10,568.0 16:45 16:57 5.0', PUW 50 k 12/7/2018 12/7/2018 2.05 PROD2 DRILL TRIP P Continue IH, stacking out at 10,690', 10,568.0 13,285.0 16:57 19:00 PUH, roll pump attempt to pass thry window. Make it through window on third pump cycle. Continue in hole, Stack out multiple depths 11,903, 12266, 12,600 12!7/2018 12/7/2018 1.00 PROD2 DRILL DRLG P 13285', Drill, 1.88 BPM (415340 PSI 13,285.0 13,307.0 19:00 20:00 FS, BHP=3990, RIW=-7K, DHWOB=.8K. Low ROP, Poor weight transfer, Frequent pickups 12/7/2018 12/7/2018 0.40 PROD2 DRILL WPRT P 200' wiper, unable to get back to 13,307.0 13,307.0 20:00 20:24 bottom after pick up 12/7/2018 12/8/2018 3.60 PROD2 DRILL DRLG P 13307 OBD, 1.87 BPM @ 5395 PSI 13,307.0 13,348.0 20:24 00:00 FS, BHP=4030, Not making hole, work pipe, Pump Lubed sweeps, At bit @ 13324. Little if any improvement in drilling parameters. Frequent pick ups. Low ROP 12/8/2018 12/812018 2.10 PROD2 DRILL DRLG P 13348', Drill, 1.87 BPM @ 5300 PSI 13,348.0 13,390.0 00:00 02:06 FS, BHP=3950 12/8/2018 12/8/2018 0.70 PROD2 DRILL WPRT P 13390, BHAwiper, PUW=66K. Have 13,390.0 13,390.0 02:06 02:48 to work pipe back to bottom 12/8/2018 12/8/2018 0.70 PROD2 DRILL DRLG P 13390', drill, 1.87 BPM @ 5300 PSI 13,390.0 13,404.0 02:48 03:30 FS, BHP=3950, RIW=-.BK, DHWOB=1.3K. ROP=-20 FPH 12/8/2018 12/8/2018 0.20 PROD2 DRILL WPRT P BHA Wiper, PUW=64K, Work pipe to 13,404.0 13,404.0 03:30 03:42 bottom Page 22127 Report Printed: 12/2612018 Operations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log 6tart Time EEM Time Dur(hr) Phase Op Code AalrvitY CCOB Time Pd-% Operation start Depth (tlKB) End Depth (flKB) 12/8/2018 12/8/2018 3.00 PROW DRILL DRLG P 13404', Drill, 1.88 BPM @ 5350 PSI, 13,404.0 13,437.0 03:42 06:42 BHP=3960. Atl3417 send 20 BBI lube pill with Screen clean in it (no beads). Little to no change in drilling parameters. 12/8/2018 12/82018 0.60 PROD2 DRILL WPRT P Short wiper, PUW 62 k 13,437.0 13,437.0 06:42 07:18 12/8/2018 12/8/2018 1.75 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 5,358 psi, 13,437.0 13,457.0 07:18 09:03 Diff=1,181 psi, WHP=7, BHP=3,838, IA=791, OA=214 12/8/2018 12/8/2018 0.20 PROD2 DRILL WPRT P BHA viper, PUW 67 k, lower pump 13,457.0 13,457.0 09:03 09:15 rate to 1.0 bpm to RBIH 12/8/2018 12/8/2018 0.75 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 5,358 psi, 13,457.0 13,483.0 09:15 10:00 Diff=1,181 psi, WHP=7, BHP=3,838, IA=791, OA=214 12/8/2018 12/8/2018 0.15 PROD2 DRILL WPRT P BHA wiper, PUW 69 k, lower pump 13,483.0 13,483.0 10:00 10:09 rate to 1.0 bpm to RBIH 12/8/2018 12/82018 1.20 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 5,358 psi, 13,483.0 13,505.0 10:09 11:21 Diff=1,181 psi, WHP=7, BHP=3,838, IA=791, OA=214 12/812018 12/82018 0.15 PROD2 DRILL WPRT P BHA wiper, PUW 72 k, lower pump 13,505.0 13,505.0 11:21 11:30 1 1 rate to 1.0 bpm to RBIH 12/8/2018 12/812018 1.20 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 5,358 psi, 13,505.0 13,535.0 11:30 12:42 1 Diff--1,181 psi, WHP=7, BHP=3,838, IA=791, OA=214 1218/2018 12/8/2018 0.15 PROD2 DRILL WPRT P BHAwiper, PUW 69 k, lower pump 13,535.0 13,535.0 12:42 12:51 rate to 1.0 bpm to RBIH 12/8/2018 12/8/2018 3.00 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 5,358 psi, 13,535.0 13,625.0 12:51 15:51 Diff-1,181 psi, WHP=7, BHP=3,838, IA=791, OA=214 12/8/2018 12/8/2018 0.15 PROD2 DRILL WPRT P Short BHA wiper up hole, PUW 63k 13,625.0 13,625.0 15:51 16:00 12/8/2018 12/8/2018 0.75 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 5,358 psi, 13,625.0 13,641.0 16:00 16:45 Diff-1,181 psi, WHP=7, BHP=3,838, IA=791, OA=214 12/8/2018 12/8/2018 1.60 PROM DRILL DRLG P OBD, 1.87 bpm at 5,358 psi, 13,641.0 13,685.0 16:45 18:21 Diff=1,181 psi, WHP=7, BHP=3,838, IA=791, OA=214 12/8/2018 12/8/2018 1.00 PROD2 DRILL WPRT P Wiper trip, 800', PUW=56K, Smooth 13,685.0 13,685.0 18:21 19:21 trip up and down 12/8/2018 12/8/2018 1.20 PROD2 DRILL DRLG P 13685', Drill, 1.9BPM @ 4890 PSI FS, 13,685.0 13,735.0 19:21 20:33 BHP=3895, RIW -61K, DWOB=I.6K 12/812018 12/8/2018 0.20 PROD2 DRILL WPRT P Pull BHA wiper, get survey, PUW=56K 13,735.0 13,735.0 20:33 20:45 12/8/2018 12/8/2018 2.80 PROD2 DRILL DRLG P 13735', Drill, 1.89 BPM @ 5020 PSI 13,735.0 13,807.0 20:45 23:33 FS, BHP=3825, @ 13728 lower rate for heavy vibration, 1.8 BPM @ 4950 PSI FS, BHP=3820 PSI 12/8/2018 12/9/2018 0.45 PROD2 DRILL DRLG P 13807 drilling. Fluid returns drop off to 13,807.0 13,712.0 23:33 00:00 less then .9 BPM, BHP=4850. Notify town eng. 12/92018 12/9/2018 2.00 PROD2 DRILL WPRT P Expedancing fluid losses. Pull wiper to 13,712.0 10,525.0 00:00 02:00 window with 7" cleanout in preparation for possible choke shut in,PUW=59K. Oerpull with slight pack off @ 11960. Slight overpull in window, -1.47k DHWOB 1219/2018 12/9/2018 0.10 PROD2 DRILL DLOG P Log K1 correction plus 9.0' 10,525.0 10,563.0 02:00 02:06 12/9/2018 12/9/2018 2.00 PROM DRILL WPRT P Continue wiper trip to bottom. Set 10,563.0 13,815.0 02:06 04:06 down window, 10680 twice. Roll pump and pass through clean. Good trip to bottom Page 23127 ReportPrinted: 12/2612018 Operations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Our hr ( ) Phase Op Code Acivity Cotle Time P -T -X Operation Stan Depth (n e) End Depth (RKB) 12/9/2018 12/9/2018 1.80 PROD2 DRILL DRLG P 10,815', Drill 1.66 BPM @ 4840 PSI, 13,815.0 13,876.0 04:06 05:54 BHP=3720, Retums @ 1.39 BPM, RIW-8K, DHWOB=I.4K 12/9/2018 12/9/2018 0.30 PROD2 DRILL WPRT P BHA wiper up hole, PUW 56 k 13,876.0 13,876.0 05:54 06:12 Note: Return rate 0.9 bpm, close choke 12/9/2018 12/9/2018 1.15 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 4,948 psi, 13,876.0 13,925.0 06:12 07:21 Diff -187 psi,WHP=408, BHP=3,339, IA=762, 0A=1 25 1219/2018 12/9/2018 0.15 PROD2 DRILL WPRT P PU, PUW 58 k 13,925.0 13,925.0 07:21 07:30 12/9/2018 12/9/2018 2.50 PROD2 DRILL DRLG P 130813, 1.87 bpm at 4,948 psi, 13,925.0 14,035.0 07:30 10:00 Diff --187 psi,WHP=408, BHP=3,339, IA=762, OA=125 12/9/2018 1219/2018 0.15 PROD2 DRILL WPRT P PU, PUW 58 k 14,035.0 14,035.0 10:00 10:09 12/9/2018 12/9/2018 2.80 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 4,948 psi, 14,035.0 14,094.0 10:09 12:57 Diff -187 psi,WHP=408, BHP=3,339, IA=762, 0A=1 25 12/9/2018 12/9/2018 0.15 PROD2 DRILL WPRT P PU, ,PUW 51 k 14,094.0 14,094.0 12:57 13:06 12/9/2018 12/9/2018 1.60 PROM DRILL DRLG P BOBD, 1.87 bpm at 4,948 psi, 14,094.0 14,166.0 13:06 14:42 Diff=187 psi,WHP=408, BHP=3,339, IA=762, OA=125 ****Note: High API 150+@ 14,144- 14,155' 12/9/2018 12/9/2018 0.20 PROD2 DRILL WPRT P PU, ,PUW 53 k 14,166.0 14,166.0 14:42 14:54 12/9/2018 12/9/2018 1.00 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 4,948 psi, 14,166.0 14,187.0 14:54 15:54 Diff=187 psi,WHP=408, BHP=3,339, IA=762, OA=125 `— Note: Duo -Ys at the bit 14,164' 1219/2018 12/9/2018 0.30 PROM DRILL WPRT P 800' wiper up hole PUW 56 k 14,167.0 13,387.0 15:54 16:12 1219/2018 12/9/2018 0.60 PROD2 DRILL WPRT P Wiper back in hole 13,387.0 14,187.0 16:12 16:48 12/912018 12/9/2018 1.70 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 4,946 psi, 14,187.0 14,263.0 16:48 18:30 Diff --187 psi,WHP=408, BHP=3,339, IA=753, OA=101 12/9/2018 1219/2018 0.20 PROM DRILL WPRT P BHA Wiper, PUW=56K, BHP=3325 14,263.0 14,263.0 18:30 18:42 12/9/2018 12/9/2018 3.90 PROD2 DRILL DRLG P 14263',Drill, 1.89 BPM @ 4260 PSI 14,263.0 14,352.0 18:42 22:36 FS, RIW=-8K, DHWOB=I.1K 121912018 12/9/2018 0.50 PROD2 DRILL WPRT T Lost comms with tool, Pull wiper trip to 14,352.0 14,352.0 22:36 23:06 trouble shoot. Restart surface gear. All good 12/9/2018 12/9/2018 0.70 PROD2 DRILL DRLG P 14352', Drill, 1.89 BPM @ 4260 PSI 14,352.0 14,370.0 23:06 23:48 FS, BHP=3375, 12/9/2018 12/10/2018 0.20 PROD2 DRILL WPRT P Pull BHA Wiper, PUW=56K 14,370.0 14,371.0 23:48 00:00 12/10/2018 12/10/2018 0.10 PROD2 DRILL WPRT P 14,371.0 14,388.0 00:00 00:06 12/10/2018 12/10/2018 3.20 PROD2 DRILL DRLG P 14388', Drill, 1.89 BPM @ 4300 PSI 14,388.0 14,473.0 00:06 03:18 FS, BHP=3300. RIW=-9K, DHWOB=1.9K, Choke shut 12/10/2018 12/10/2018 0.20 PROD2 DRILL WPRT P 14473, BHA wiper/Shoot surveys. 14,473.0 14,473.0 03:18 03:30 PUW=56K 12/10/2018 12/102018 0.30 PROD2 DRILL DRLG P 14473, Drill, 1.9 BPM @ 4300 PSI FS, 14,473.0 14,481.0 03:30 03:48 BHP=3315 Page 24127 Report Printed; 12/26/2018 Operations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depth Stan Time EMTime our(hp Phase Op Code Activfty Code Time P -T -X Operation (ftKB) EM Depth(ftKB) 12110/2018 12/10/2018 0.90 PROD2 DRILL WPRT T 14481, Computer issues. Pull off 14,481.0 14,481.0 03:48 04:42 bottom and reboot, PUW=58K 12110/2018 12/10/2018 3.65 PROD2 DRILL DRLG P Computers up and running, 14,481', 14,481.0 14,585.0 04:42 08:21 drill, 1.88 BPM @ 4294 PSI FS, BHP=3242 12/10/2018 12/10/2018 2.00 PROD2 DRILL WPRT P 800', wiper up hole, PUW 65 k, 14,585.0 14,585.0 08:21 10:21 fighting weight transfer on wiper back in hole, 12/10/2018 12/10/2018 2.40 PROD2 DRILL DRLG P BOBD, 1.89 bpm at 4,217 psi, 14,585.0 14,646.0 10:21 12:45 Diff --1,130 psi, WHP=290, BHP=3,204, IA=774, OA=172 12/10/2018 12110/2018 2.00 PROD2 DRILL DRLG P BOBD, 1.89 bpm at 4,217 psi, 14,646.0 14,650.0 12:45 14:45 Diff=1,130 psi, WHP=290, BHP=3,204, IA=774, OA=172 12/10/2018 12110/2018 0.15 PROD2 DRILL WPRT P BHA PU PUW 57 k 14,650.0 14,650.0 14:45 14:54 12/10/2018 12/10/2018 2.00 PROD2 DRILL DRLG P OBD, 1.78 bpm at 4,000 psi, 14,650.0 14,720.0 14:54 16:54 WHP=341, BHP=3,244, IA=775, OA=179 PU @ 14,704' PUW 52 12/10/2018 12/10/2018 2.00 PROD2 DRILL DRLG P OBD, 1.78 bpm at 4,000 psi, 14,720.0 14,760.0 16:54 18:54 WHP=341, BHP=3,244, IA=775, OA=179 PU @ 14,749' PUW 56 k 12/10/2018 12110/2018 2.00 PROD2 DRILL DRLG P OBD, 1.78 bpm at 4,000 psi, 14,760.0 14,763.0 18:54 20:54 WHP=341, BHP=3,244, IA=775, OA=179 PU @ 12/10/2018 12/10/2018 2.10 PROD2 DRILL DRLG P OBD, 1.78 bpm at 4,000 psi, 14,763.0 14,763.0 20:54 23:00 WHP=341, BHP=3,244, IA=775, OA=179 PU @ 12/10/2018 12/102018 0.30 PROD2 DRILL WPRT P 500' wiper up hole, PUW 56 k 14,763.0 14,263.0 23:00 23:18 12/10/2018 12111/2018 0.70 PROD2 DRILL WPRT P Wiper back in hole, work pipe at 14,263.0 14,389.0 23:18 00:00 14322 and 14369' 12/11/2018 12/11/2018 2.00 PROD2 DRILL WPRT P continue running back to bottom after 14,389.0 14,762.0 00:00 02:00 500' wiper, Multiple set downs / tool face changes to work though 12/11/2016 12/112018 5.40 PROD2 DRILL DRLG P ON bottom, hard to get drilling, low 14,762.0 14,771.0 02:00 0724 surface weight, low WOB, low differential pressure. Pump 30 BBI tubed bead pill. Unable to drill. Multiple pick ups. Run to bottom at speed. Attemp to stall motor 12/11/2018 12/11/2018 0.90 PROD2 DRILL WPRT P PUH while mixing 50 BBI beaded liner 14,771.0 14,773.0 07:24 08:18 running pill 12/11/2018 12/112018 1.90 PROD2 DRILL WPRT P Pill at bit, Wiper trip to window with K1 14,773.0 10,535.0 08:18 10:12 tie in 12/11/2018 12111/2018 0.10 PROD2 DRILL DLOG P Log Ki for+12' correction 10,535.0 10,561.0 10:12 10:18 12/11/2018 12111/2018 2.70 PROD2 DRILL WPRT P Continue wiper trip to bottom, clean 10,561.0 14,777.0 10:18 13:00 pass though window, good trip to 13,600 slowed to 30 FPm losing string weight. Reduce pump rate due to high WHIP. Continue in to bottom. Set down @ 14250 work to bottom 14777 12/11/2018 12/11/2018 2.70 PROD2 DRILL CIRC P Pit locked on fluids, Weigh up 14,777.0 14,777.0 13:00 15:42 completion fluid to 11.4 Build 50 BBI liner running pill. Recip pipe 12/11/2018 12/11/2018 0.70 PROD2 DRILL CIRC P Send liner pill down coil 14,777.0 14,777.0 15:42 1624 Page 25/27 Report Printed: 1 212 612 01 8 " Operations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log smrt cape, Stan Time End Time Our (ho Phase Op Code Activity Code Thee P-T-X Operation (WB) End Depm(WB) 12/11/2018 12/11/2018 1.90 PROD2 DRILL TRIP P POOH pumping beaded liner running 14,777.0 10,609.0 16:24 18:18 pill, PUW=58K, attempting to gel returns, difficulty achieving reasonable returns holding 11.4 ppg at window (0.5 bpm in, 0.23 bpm out @ 2 fpm dropping to 11 ppg at window) 12/11/2018 12/11/2018 2.30 PROD2 DRILL TRIP P POOH, pump minimum rate, prep to 10,609.0 107.0 18:18 20:36 bullhead LRP & KWF from surface 12111/2018 12/11/2018 1.30 PROD2 DRILL DSP P Bullhead 40 bbl LRP down to thief 107.0 78.0 20:36 21:54 zone (13,807'), followed by 11.4 ppg KWF to surface (2 bpm, WHP not exceeding -950 psi), tag up, PJSM 12/11/2018 12/11/2018 0.80 PROD2 DRILL PULD P Flow check, good, , UT coil, LD BHA 78.0 0.0 21:54 22:42 #24, losses - 25 bph, clear floor, bit came out a 1-1 (slight chip on reamer cutter) 12/11/2018 12/112018 0.30 COMPZ2 CASING BOPE P PU test jnt, function test BOP's, lay 0.0 0.0 22:42 23:00 1 1 down test jnl 12111/2018 12/122018 1.00 COMPZ2 CASING PUTB P PJSM, PU liner run #1 (ported BN, 24 0.0 400.0 23:00 00:00 jnts slotted liner, & shorty deployment sleeve) 12/12/2018 12112/2018 1.00 COMPZ2 CASING PUTB P Complete PU liner run #1 (ported BN, 400.0 700.0 00:00 01:00 24 jnts slotted liner, & shorty deployment sleeve), perform kick while running liner drill 12112/2018 12/122018 1.10 COMPZ2 CASING PULD P PJSM, PU BHA *25 Liner Running 700.0 750.0 01:00 02:06 Tools 12/12/2018 12112/2018 2.10 COMPZ2 CASING RUNL P RIH w/BHA #25(liner run#1),-3.16' 750.0 10,551.0 02:06 04:12 correctioin to window flag, PUW = 45K, continue RIH 12/12/2018 12/12/2018 0.10 COMPZ2 CASING DLOG P -3.16' comectioin to window flag, PUW 10,551.0 10,548.0 04:12 04:18 = 45K, continue RIH 12/12/2018 12/12/2018 1.80 COMPZ2 CASING RUNL P Continie in, Clean through window and 10,548.0 14,770.0 04:18 06:06 down to 14770, Pump off liner, PUW=49 K 12/12/2018 12/12/2018 3.40 COMPZ2 CASING RUNL P Trip out for next liner segment, Tie in 14,770.0 79.0 06:06 09:30 for+13.5', Paint EOP flags @ 12,900 & 9500 12/12/2018 12/12/2018 0.40 COMPZ2 CASING OWFF P Tag up, Flow check well, establish 79.0 79.0 09:30 09:54 1 1 1 static fluid loss rate @ 20 BPH 12/122018 12/12/2018 0.40 COMP72 CASING PULD P Lay down BHA#25 79.0 0.0 09:54 10:18 12/12/2018 12/12/2018 2.20 COMPZ2 CASING PUTB P PJSM, Prep floor. P/U AL1-01 0.0 1,007.0 10:18 12:30 intermediate liner segment with ported bull nose, 33 Jts 2 3/8" slotted liner with shorty deployment sleeve 12/122018 12/12/2018 0.60 COMPZ2 CASING PULD P Make up coil track to liner, Make up 1,007.0 1,051.2 12:30 13:06 coil to coiltrak and surface test. Check pack offs, Make up injector to well 12/12/2018 12/12/2018 2.00 COMPZ2 CASING TRIP P Tag up and set counters, RIH BHA 1,051.2 10,551.0 13:06 15:06 1 1 1#26 12/12/2018 12112/2018 0.30 COMPZ2 CASING TRIP P 11515 correct to flag, +2.6', Continue 10,551.0 11,515.0 15:06 15:24 in well 12/12/2018 12/122018 0.10 COMPZ2 CASING DLOG P Log K1 for+2'. Continue in well 11,515.0 11,565.0 15:24 15:30 without correcting 12112/2018 12/12/2018 1.00 COMPZ2 CASING TRIP P Continue in well, Tag up @ 14069. 14,069.0 14,061.0 15:30 16:30 14071 corrected. PUW=55K. Pumps on release from liner, PUW=47K, 121122018 12/12/2018 2.70 COMPZ2 CASING TRIP P Remove liner length left in hole, Trip 14,061.0 50.0 16:30 19:12 out 12/12/2016 12/12/2018 0.70 COMPZ2 CASING PULD P PJSM, flow check, good, LD BHA#26, 50.0 0.0 19:12 19:54 1 I clear floor, prep to PU tinier Page 26127 Report Printed: 1212612018 Operations Summary (with Timelog Depths) 2T-37 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log $IaM1Dapth Start Tigre Entl Time Dur hr ( ) Phase DP Code Activity Coda- Time P -T -X Operatlon (ft e) Fsa Depth (WB) 12/12/2018 12/13/2018 4.10 COMPZ2 CASING PUTS P PU liner run #3 (ported BN, 2' pup, 79 0.0 2,440.0 19:54 00:00 jnts slotted liner, & shorty deployment sleeve), clear floor Drill: kick while running liner 12/13/2018 12/13/2018 0.70 COMPZ2 CASING PULD P PU liner running tools, BHA #27 slide 2,440.0 2,488.0 00:00 00:42 in can, check pack -offs, MU to coil, tag up 12113/2018 12/13/2018 2.90 COMPZ2 CASING RUNL P RIH wl liner run #3 (BHA#27), -2.5' 2,488.0 10,064.0 00:42 03:36 correction to window flag, PUW = 47K, arrive at set depth, PUW = 57K, bring up pumps & release off liner, PUW = 41 K, TOL - 10,620- 12113/2018 12/13/2018 1.80 COMPZ2 CASING TRIP P POOH w/ BHA#27 10,064.0 60.0 03:36 05:24 12/13/2018 12/13/2018 0.40 COMPZ2 CASING PULD P PJSM, Lay down BHA on dead well 60.0 0.0 05:24 05:48 12/13/2018 12113/2018 1.30 COMPZ2 CASING PULD P Prep floor for gyro run, PJSM P/U 0.0 74.9 05:48 07:06 BHA#28 Gyro test. Make up to coil and srface test. Check pack offs. Tag up and set counters 12/13/2018 12113/2018 2.30 COMP72 CASING DLOG P Trip in hole. Stop @ 636' prep for 74.9 1,136.0 07:06 09:24 Gyrotrak test. Pull initial surveys @ 636, 961, 986, 1011, 1036, 1061, 1086, 1111, 1136 12/13/2018 12/13/2018 0.30 COMP72 CASING TRIP P Completed first seris of tests. PUH 1,136.0 636.0 09:24 09:42 while circulating 1.6 BPM 1211312018 12/13/2018 1.70 COMP72 CASING DLOG P Repeal survey points 636.0 1,136.0 09:42 11:24 12113/2018 12/13/2018 0.20 COMPZ2 CASING TRIP P Trip out 1,136.0 79.0 11:24 11:36 12/13/2018 12/13/2018 0.80 COMPZ2 CASING PULD P Flow check well, PJSM lay down BHA 79.0 0.0 1136 1224 #28 12/13/2018 12/13/2018 0.50 DEMOB WHDBOP PULD P M/U nozzle, Inspect packoffs, stab 0.0 0.0 12:24 12:54 injector on well 12/13/2018 12113/2018 1.20 DEMOB WHDBOP CIRC P Line up and bull head 100 BBIs 0.0 0.0 12:54 14:06 seawater down tubing, PJSM with LRS to pump 35 BBIs diesel in T 12/13/2018 12/13/2018 1.60 DEMOB WHDBOP CIRC P Well displaced to seawater, Shut in 0.0 0.0 14:06 15:42 well. Pump diesel into coil followed by seawater recovering 11.4 PPG completion fluid to pits. Open well and bullhead diesel down wellbore. 12/13/2018 12113/2018 2.30 DEMOB WHDBOP CIRC P Shut in well, jet stack and flush rig 0.0 0.0 15:42 18:00 surface lines, boroscope stack 12/13/2018 12113/2018 1.50 DEMOB WHDBOP RURD P Work RD checklist, freeze protect tree, 0.0 0.0 18:00 19:30 disconnect hi -line power, chain off reel, secure injector cart 12/13/2018 12/13/2018 1.50 DEMOB WHDBOP NUND P Continue RD checklist, ND BOP 0.0 0.0 19:30 21:00 "Rig Released: 12/13/18 @ 21:00 hrs Page 27/27 Report Printed: 12126/2018 ConocoPhillips ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kuparuk 2T Pad 2T -37L1-01 50-103-20227-61 Baker Hughes INTEQ Definitive Survey Report 28 December, 2018 BAKER 40 JUGHES GE ior,. viv r.. ConocoPhillips BT& ConocoPhilli ps DMnNive Survey Report Company: Conons iRips (Alaska) Inc. Local Coordinate Reference: Wb112T-37 Project: Kidamk River Unit TVD Reference: 2T-37 C 122.00usS(Parker 245) She: Kupamk 2T Pad MD Refinance: 2TJ7 ®122.00usX (Parker 245) Well: 2T-37 North Reference: True Wellbore: 2T-37 Survey Catculadon Mehlod: Minimum Curvature Design'. 2T-37 Database: EDT 14 Alaska Production Protect Kupamk River Unit, NOM Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Do..: Mean Sea Level Gen Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Me, Zone: Alaska Zone 04 Using geodetic scale factor Well 2T-37 Well POsitien -1414 0.00 ash Northing: 5,969,88246ush Latitude: 70°19'44,211N .EJ-W 0.00 u3S Eastlng: 498,944.62ush Longitude: 150°P 30414 Position Uncertainty 0.00 Ush Wellhead Elevation: unit Ground Level: 80.5) ..it Wellbore 2T-37L14?1 Magnetics Model Noma Sample pale Decimation Dip Angle Field Strength r) InT) BGGM2010 M/2018 16.75 00.85 57427 Design 2T-37u-01 Audit N0tes: Version: 1.0 Phase', ACTUAL 11e On Depth: 10,649.52 L cal Section: Depth From (TVD) aW3 4YV Direction (unit) (da0) (-am (') 4150 0.00 0.00 270.110 Surveypre9ram Data _... __. From To Survey Survey (uah) (usR) Survey(Wellbore) TaN W. Deradptlon Start Dab End Data 5000 3,739.00 ZT-37 G,reDina DT47) Copy Of GVD-0T-0MS Gyrations cont.casing We W512009 6/25/2009 4,06886 10,649.52 2T-37 QT-37) MI MWD-Standard W5/1995 81511995 10,680.00 14.777.00 2T-3711-01(273711-01) MWD MWD - Standard 1VIGOIS 12=18 12128R0f6 6:51..-18PM Pi 2 COMPASS 500014 Budd 60 Survey Conocolahillips ConocoPhillips Definitive Survey Report Company: Cono.Phillm(Alsaka) Inc. Local Coordinate Reference: Wa112T-37 Project: Kuparuk River Unit WD Reference: 2T37@ 122.00usn(Parker 245) am Kupamk 2T Pad MD Reference: 2737@ 122.00usn(PeMer245) Well: 3T37 North Reference: Tore Wolibore: 2T47 Survey Calculation McMod: Minimum Curvature Dem9n: 2TJ7 DaMease: EDT 14 Alaska Production Survey Vertical Section Survey Tpol Nemo 735557 MWD(3) ],3]652 AND (3) 7,395.70 MND(3) 7,418.35 MN➢(3) 7,45214 MWD (3) 7478.40 MD (3) 7,50760 IMD13) 7.537.89 M (3) 7,568.11 MND(3) 7.59664 MND (3) 7,621.64 MND(3) 7,64515 MWD (3) 7,671.14 MWD(3) 7,69572 MND(3) 71ID.38 MJUD(3) 7,746.21 MND(3) 7,772.33 MWD (3) 779896 MWD (3) 7,82499 MWD (3) 7,852,01 MPoD(3) 7`]9.54 MMD(3) 7,93788 MND (3) 7,936.35 MD (3) 7,965.27 MD (3) 7,99552 "D (3) 8.024.33 MMD(3) 6053.80 MND(3) 8,08336 MD (2) 8.113.34 "D (3) 8,142.63 MWD I31 Anrlotation TIP KOP I O 12126/1018 651: III Page 3 COMPASS WW. 146u0d BSD Map Map MD 1. Aal TVD TVD59 *NIS S. p No fa111) OLS (7 17 (malt) (usn) Juan) (usn) (ft) n) Jnl (•iloar) 10.64952 5120 241.913 5,72624 56]3.24 3610667,3555] 5,965.2730t 491,509.18 219 tOanpon 5104 242.05 5.814.37 5,6923) l M8 o0 -1,3]6.52 ^ 5,966261.88- X491.566.32 055 10]0.9] 58,15 240.. 588.93 5,70.93 -3,632.54 -],395.]0 5,986251.35 491549.14 26.91 10.]3602 ]1184 23900 5.642.50 5,]20.50 364578 -7,41935 5'.236tt 49153650 4307 10,7]6.]1 0730 23726 5,0502fi 5728.28 4.666,81 4,45214 5,966,217M 491,492.71 41,16 10,80715 9077 250.47 5,05a]. 588]8 -3,600.18 -7,479,40 5,966,20372 491`65.45 4406 1083623 M.31 2'2,16 5,051.01 S.Mol 3,88705 -7,5060 5,SMAM 5 49143725 41.14 10,a6661 08.40 27537 5,851.89 5.72aae 3887,69 Q537.89 ante Islam 49140.96 4340 10.aCS1 8]24 28899 5953.07 5,7310 1,601.211 -7,560.11 5,B6fi]02]1 01.3]6.]5 43.74 1007.67 0610 29792 5.854.30 5,]32.30 1,66928 4,595.64 595621463 491.349.22 30.15 10,957119 0928 301.94 5,05524 5,733.25 4.65431 4,82164 5,9E ,M,W 491,32 M 1340 10 91602 6943 305.82 560l0 5,734.06 4.63B.53 -7.645,15 5,80,24539 491 2W 1170 11,018.17 80.13 30.21 5.057.02 5.735.02 -3,619.64 -7,671,14 5,9668,4.29 4912]3]4 1.53 11046.ta 86.84 303.61 5,85934 5.7W,. 3,6@.48 -7,695,72 5,966,281.44 491249.16 9.66 11.07T53 88.31 301.. 595958 5,YA.58 1,58680 -7,720.311 5,966,29732 491224.51 753 11,10701 0062 300 5.650.39 5.738.39 4.9082 4,746.21 590.313,10 491199.69 374 11,1390 89,39 299.45 5.860,92 673692 4555aa -],7.2.33 5.966.32926 491,172.57 5.34 11,168,37 8954 27.60 5WlM 5,]39.20 3.541.11 -7,79698 5,986,34282 491,14594 549 1119743 88.43 29501 5,861.72 5,]39]2 -3,528.19 -7824,90 598635574 491.11892 M33 1128.09 0770 293.44 5,66272 5,740.8 3,51603 -7,852.01 5,96630.91 491,09290 5.03 1125691 9668 29185 5.864.10 5,742.18 1,5D460 -7.879.54 5966.37534 491265.38 690 11207.01 8843 289,14 5,865.99 5,743.99 -349414 -0,907.6,4 5,95638986 491,037.24 8.37 11,317.25 86.03 07.14 5,86790 5,745.98 4.484.]4 -],936,35 5,40,399.211 491009.57 6.73 11,347.36 87.05 284.4 5.8W.79 5.]4].80 -3476.55 -796527 5.986.407.40 490,99.66 952 11378.27 wa40 28199 5,071@ 5,74902 -3.469,47 -0,995,32 5,966,41449 40,94961 927 11407.81 09.11 27eM 691.86 5749.66 1,463,89 $024.33 5.9664200 493,920.61 792 11,437.9 8040 2964 5,9179 5.749.79 -,459.12 -8053.0 SaSd a. 490,891.14 5.8 11,46755 9203 27742 5.07116 5749.16 3454.95 -6,003.38 5,860.4299 490,86156 6.01 11 49773 Val 27567 5.869.92 574792 -3.451.51 -.113.34 5,90432.46 49083161 6,17 1152.23 91.87 2717 5,86875 5.]46.]5 -3,448.21 4,14163 5,553..576 40,80232 576 Vertical Section Survey Tpol Nemo 735557 MWD(3) ],3]652 AND (3) 7,395.70 MND(3) 7,418.35 MN➢(3) 7,45214 MWD (3) 7478.40 MD (3) 7,50760 IMD13) 7.537.89 M (3) 7,568.11 MND(3) 7.59664 MND (3) 7,621.64 MND(3) 7,64515 MWD (3) 7,671.14 MWD(3) 7,69572 MND(3) 71ID.38 MJUD(3) 7,746.21 MND(3) 7,772.33 MWD (3) 779896 MWD (3) 7,82499 MWD (3) 7,852,01 MPoD(3) 7`]9.54 MMD(3) 7,93788 MND (3) 7,936.35 MD (3) 7,965.27 MD (3) 7,99552 "D (3) 8.024.33 MMD(3) 6053.80 MND(3) 8,08336 MD (2) 8.113.34 "D (3) 8,142.63 MWD I31 Anrlotation TIP KOP I O 12126/1018 651: III Page 3 COMPASS WW. 146u0d BSD Survey Conocolahillips ConocoPhillips Definitive Survey Report Company: ConowPhiftipa (Alaska) Inc. Local Oo-ordinate Referenda: VVe62Ub7 Praia., Kupamk River Unk ND ReMrence. 2T87@ 122.00usn(Parker245) Site: Kuparuk 2T Pad MD Reference. 2T-31@ 122.00usg(Parker 245) Well: 2T47 North Ralerenee: Tme Wellbore: 2T-31 Survey Calculation Method Minimum Curvature Design: 2T-37 Dafahase: EDT 14 Alaska Pmduc80n Survey Annotation 121162016 651'l6PIM Paged COMPASS 500014 Bu1Yl 650 Map Map Manuel MD (-it) Inc AB PI tV0 TVD$$ HUS eel -W Northing Sued g OLS aedtlon Bunnell, Tool Name (uan) linen) (Man) (ural Inl (n) P1100) tltl 11557,62 91.20 2M72 S.SW C 5!45.94 -3,443.49 4,11263 5ma 4404B 4.90,]]232 1188 0,1]263 MJUD(3) 11,581.40 91.]2 284.40 5,80218 5,745.18 -3,43102 4201.88 5,966,480.63 49024327 12208 0,201.68 MMID(3) 11.619.33 91.. Man 5,8%,17 5,744.17 !,421.98 1=28 5,906,456.01 490,71266 1294 8,232.28 Main (3) 11.,84863 918 291.44 5865.24 5,74524 4411.95 -8, 9Ss 5.956.463,0] 490,6WA2 603 8.259.85 MD (3) It 677.07 91]5 294.11 5,064.20 5.14230 -3.406.91 8,28681 5,988.41/02 490.660.96 940 8.206,01 MWD (3) 11708,04 92.64 29580 5,853.20 5,741.20 -3,393.81 4,314.07 5966,49008 420,830.91 6.16 8,31407 MWO(3) 11741.9 94.27 29430 5&51.20 5,139.20 -337694 -0,343.95 5966,504.05 490,601,03 6.70 0,343.95 MMD(3) 1170.02 94.2 29263 5,85611 5.73111 -3,36841 -0,370.40 5,963615.58 490,514.56 524 8,370.40 Mudd) (3) 11.799.80 0298 29128 5.857.29 573530 -3,35.21 -839196 5.968.526.13 49054103 6.23 8.297.90 MID (3) 11,83045 9252 289.50 5,855,84 5133.84 4,346.89 $,IMaa 5668.53131 490618.63 an BAXM MD (3l 1185048 92.06 28746 586463 5,13263 -3.337.9 845511 S9.54694 420.489.89 714 8,455.11 MWD(3) 11890.70 93.51 285.40 5853.16 5.73146 -3.3289 448897 5.880.55573 490461.3 5.94 8,403.97 MWD(3) 11,920.17 93.11 284.62 5,851.46 5,729.46 -3,320.41 4,512.32 5966,56563 490,43260 6.18 0,51232 Mail)(3) 11,950.13 9298 20225 5.849,83 S,T .113 8,31532 1,54200 5,965,50.70 490,403,01 7.76 8.54200 MND(3) 11.980.52 94.80 20216 6,84781 SM.01 y307.03 -0.5105 5.906,67690 490373P6 6.12 0.51.05 BfiND(a) 12,01087 96.52 28241 6,844,84 5,12284 4300.64 8600.36 5,966583.38 490,344.65 SBO 8,600.36 MWD13) 12,4045 95.49 280111 5,641.47 5,71647 -3,294.5 862634 5,958,589.36 490,315.14 5.54 8,629,34 MWD(3) 12,070.14 94.36 27884 5830.66 5.716.66 -3,2.,62 4,658.46 5.59440 450,28.56 9]5 0,65848 MWD(3) 12100.73 61.32 2P.39 5.836.61 5,714.61 8285.32 -0,688.84 5.966,59872 49025635 5.82 8,69868 MAD (3) 12,130.30 SIM 21500 5,035.26 571526 8,28205 -87180 5.906.63108 490227.00 8.54 8,718.03 MVSD(3) 12dfi090 92.] 2n,. 5.03421 5,712.21 4279.76 -8,748.61 5968604.20 490.19643 S,% 8.748.61 MVVD(3) 12190&0 92.36 271.36 5,83507 5,71107 -3.278.57 -8.77826 5,968,605,48 490.16378 Sea 8.178.29 MWD(3) 1262052 93.60 269.76 5,831.62 5,709.52 827820 -0,80806 5966.60571 450.13898 6.70 8,00008 "D (3) 12251.21 92.98 271.65 5829.fi 5,707.76 -3,27790 4,830.69 59666MIS 490, IM35 6.47 8113869 MWD(3) 12280.82 WS7 27418 5828.30 5,706.30 8,27624 -0,858.22 5963,601.82 490016.83 10.61 8,85822 than p) 12.31063 81.14 21811 5,827.31 570,31 8,28.89 -0.89187 5963,811.9 490,04711 1226 8,697.87 MAD (3) 12,34052 Ban 280. 5827.08 5,76508 -3,260,19 4,92733 5.563.81507 490017]2 792 8.927.33 MMID(3) 12,3T156 SIM 28257 5,BMW 5,104.83 826232 -8.956 79 5W.621.75 489.963.27 697 8,96S.79 MWD(3) 12,40528 92.27 285.48 582576 5,703.76 -3,253.91 -0,99045 5,9666&16 489,9881 8.87 9,990.45 MWD(3) 12436.30 5.5 287.63 5,82458 5.702.59 -3,24508 8@016 5,91.16639.00 4068-190 6.96 9,02046 MAGOl 12.46520 890t 287,81 5,824.51 6.7M.5 8,236.28 -a04766 5,966841.79 489.89739 14.03 9,04768 MVAD(3) Annotation 121162016 651'l6PIM Paged COMPASS 500014 Bu1Yl 650 Survey ConocoPhillips COnOCOPhillips Definitive Survey Report Company: Can... Phllllps(Alaska) Inc. Local Co-ordinate Reference: WAN 2T-37 Project Kupamk River Unit TVD Reference: 2T-37®122.00usn(Parkr245) SM: Kupamk 2T Pad MD R.N....: 2T-37@ 122.00ustt(Parker 245) Well: 3T417 hunk Reference: Tore VINII pre: 2T-37 Survey Calculation Method Minimum Curvature Dssk,L 2T17 Database: EDT 14 Alaska Production Survey Annotation 12118!1010 6:51'10PM Page 5 COMPASS 500014 Budd 853 Mak, vertical MO luartl Ina AadTVD T Mll5 ♦RJAy Nordale, Eastt, OLS Section Survey Tool Neth, 1°1 l (deft) -am lu•rtl luenl loan j fail Inl 1°11ad Inj 12,1995.33 86.53 290.46 5.826.00 5,704.00 -3,226.42 407611 5,9F5,65].60 489,8689fi 100. 1 9,078.1, MWD (3) 12524.93 8634 2.280 5827.04 5)0584 1,215.51 -9,103.56 5911,66&50 48,841.51 B.25 9,103.56 MWD (3) ,255567 87.11 295,9 5829.56 5,767.56 1=27 4, Isom 5,96668&Ot 48,014.10 8.03 9,130.88 MWD(3) 12,5115.06 07.30 219,95 5.831.03 5.709.03 y189,61 -,151.71 5.96669447 480.].].30 12.51 9,15].]1 MW➢(3) 12615.,6 628 302.15 503'230 5,71030 $17433 -,183.60 5,966.]09.]6 40976149 1070 9,183.60 MMA) (3) 4.67520 8874 30463 5833.29 5.711.20 -3,157,81 4.208.67 5,98.72029 48&]36.42 871 9.208.67 MVM (3) 12,674.79 BBW 303.13 5,83360 571160 -3,14131 423323 5W,]42]0 488.]11.8] 6.00 9,23323 MD (3) 1270491 a" 30221 5,834,09 5,712.08 -3,12505 -9,259.59 5,f66j59W 489,689,52 5.10 925&59 MD (3) 12,]30.36 8797 30095 583488 5.71208 J.1H73 -9,280.2] 5,966.]83] 48.604.84 5.31 9,28027 MWD(3) 1275911 87.05 219.80 5.038,15 5,71416 40sa B, -9,36755 5,966,]8].19 488,679.$ 502 9,305.55 MWD (3) 12.780.12 05.20 298.13 5,019.21 5,718.21 3,082.22 -8,332.09 6919,801.8', 48961302 019 9.332.09 uo➢(3) 12.821.52 64,04 29701 5,84 99 5718.99 -3,06].]4 -8,35Ba2 5985,818.38 489.5&531 390 9.359.82 Mad) (3) 12,85006 8369 294,69 5,84388 5,72199 3,055.36 4,385.37 5,966,828.74 48955&76 8,75 9,3&5.37 MD 12886.26 8274 28242 5,840.17 5,]251] 4l'041.00 -.418.32 5966.01311 489.52582 6.76 9,418.32 MD (3) 12915.33 8301 280.39 5.851.]8 5,72918 -3 M.47 -94454 596685364 419,499.97 6.99 9,445.17 MD (3) 12,84525 82.69 289.51 5855.50 5.13350 3,020.59 -9,49.16 5,966.063.53 489 471 6.33 9.473.16 "D (3) 12875190 0357 28,91 5.85911 5.73711 3,01148 .50160 5966872.64 488,4437 602 9.501.60 1010,013) 13,005.13 0405 265.04 5.86231 574031 -3.00330 4,53005 5966883.92 409,415.10 4.56 953005 MJuo(3) 1303561 84.46 2M Be 58836 5,]43.36 8,995.47 -6,559.37 598,898.8 489.38570 506 9,55937 M04) (3) 13,67569 B&M 2.67 5807.95 5,745.95 1,900.49 4,58.52 5,966895. se 409.350.64 4.81 9,58052 MND(3) 13[06,15 man 28351 5869.90 5,]4].90 -298174 -8,617.4 5.98.90240 409.328.04 4.17 9,61712 MAK) (3) 13,13060 8025 284.83 5.7144 5)49,44 -2,8]3.0] -9,05140 5.98.91107 489,293]1 557 9,65146 MWD(3) 13,183] soft 205.73 58]19] 5.74931 -2965,25 -968.08 5,900910.09 489,265.0. 5]2 9.600.08 MWD (3) 13,195.02 19.37 21.78 5,07195 5,74595 - !)67,84 -9,]14.5] 5.96.920,30 48230.61 327 9,71451 MWD(3) 13.72191 90.12 20260 587182 5,74982 -294032 -745.56 59883582 4818.62 L19 9,7458 akho(3) 13.28.00 8.83 288 507213 5,75D.13 3,84147 -,]]0.95 5,98842.68 4815024 654 9,718.95 wAn p) 13290.51 0046 2]].91 5888 5750.80 -2,936.87 -9,8207 5.98.W 28 409,13012 900 9.807.07 MVVD(3) 13,320.15 W27 276.17 587362 5,7518 -2,933.24 -8,836.48 598,96092 489,108]2 588 903&40 MWD(3) 13,35021 60.20 27499 5874.5D 5.75250 4930,32 -,86130 sossa6J04 481 3.94 9,056.30 "D (3) 13.301.19 8845 2751. 5,875.12 5,75312 -2.2757 -989]23 5,.8956,59 489 047d7 3.8 uW723 MWD(3) 1341151 90.21 27406 5875.21 5753.21 -2.925.13 -,927.45 5.989804 48.517,75 446 9,927.45 MWD(3) Annotation 12118!1010 6:51'10PM Page 5 COMPASS 500014 Budd 853 Annotation a%, A 12!182018 6:51:16 papa 6 COMMSS 501114 Buaa 050 ConocoPhillips ConocoPhillips Definitive Survey Report company: ConocoPhillips (Alaska) Inc. Local Conralnate Reference: 14b112T-37 Project: Kupamk Riva, Un6 ND Reference: 2T47122.00usn(Paarer 245) Site: Kuparuk 2T Paa MO Refirence: 2T-37122.00usB(Parker245) Well: 2T-37 North ReGrence: True Wellbore: 2T-37 S.1ay Calculation MetboR Minimum Curvature Design: 2T-37 Database: EDT 14 Moka Production Annotation a%, A 12!182018 6:51:16 papa 6 COMMSS 501114 Buaa 050 Map Map Venloal MID Waft) Iva Ina Atl TVO TVOSS .WS .04NNonbing Eagle, DU Seenon Survey Tool Name 1°1 PI Noll) luanl Neel loan I,p In) x1,6,7 (to 13 44 90]4 21509 5.0]4.95 5,]52.95 .292369 -9,9511.00 5,9.9fi?49 486,986 .20 3]8 8,950.00 MWD(3) 13,473.06 9221 27569 5.874.16 5]5246 -2.19.52 -9.998.73 5.98696466 490.95540 7.01 9,98073 signal) (3) 1386741 92,64 27919 5,872.70 5,]50]0 -2,91419 -10,0n,n 5,986.969.40 49692250 7,38 105022.73 MJUD(3) 13.540]0 9329 270.98 5,07O.BB 5.74598 -2,909.54 -10,05555 5,965,974.65 488.88967 2'. 10.05555 WD (3) 1357035 oul 27971 5869503 5,74504 -2,90474 -10,08432 ago 979A5 485060.50 630 10,06473 MND(3) 13,600.40 9504 281.86 SAI 5,744.20 -2,ol -10,11417 5,955,904as 480,831.06 "a 10,11417 MWD(3) 13 WDA1 85,81 28280 5.06337 5,]413] $893,15 -10,143.39 5.486.99105 480,001,84 656 10,14339 MO (3) 13,86085 9520 2&,as 5,86024 5,]3034 -2865.00 n0,1n.00 5,955,99612 486,]]323 6.89 10,1800 MSW(3) 13g%)N 9621 .76 5,055.94 5.73494 -20805 -10,201.01 5,967.00635 400 74423 6.23 10201.01 MAD(3) 13718.14 9533 289.00 5854.15 5,72]5 -2,81 -10,22723 5,97.0X84 488,]1].95 556 10227.29 M (3) 13746.21 94500 29093 5,851.7 6,n97] -2.859.82 -1026358 5,907,@489 489,691.67 7.1 1025350 MND(3) 13]73.90 9331 293.37 5,84997 5727,97 -2,04975 -10,27031 5,957.034,06 488,666.93 986 10.27631 MWD (3) 13.]9084 9350 284.]6 5,81544 5,726.44 -283922 -10.33180 5,967,D44.99 48084337 542 10,301.80 MWD(3) 13,03208 9DU 29513 6.84718 5,73548 -282521 -00332.00 5.967 058.00 406613.6 8,11 1D,33200 MWD(3) 11.1,18 88.99 29441 584733 5.73533 -281309 -10,350.6 5,96],0]143 4118,50080 7.23 10.35848 MWD(3) 13899.40 Wm 292.19 5,948.45 S.7XA5 -2.801.62 -00,38529 5,96],082.61 480,559.87 1153 10,386.29 mvvD(3) 13.92177 .87 29094 58`5034 5,73634 -2,79341 -10,41441 5,967,064,12 466,530.86 448 10,41441 MMD(3) 13,952.55 9031 291.14 5,85109 572909 -2,)]9.06 -10,44313 5,85],1061] 466,50272 1149 10,44313 MND(3) 13,97552 8046 2053 5,850.94 572894 -.noa9 -10A84.59 5957,11334 488.480.00 273 10,464.59 MND(3) 14,[05.8] 9003 288.83 5850.01 5720.81 1,]60,]4 -10.492.90 5,96],123.49 480,45230 502 10.9298 MYA(3) 14.03154 8050 28875 5,85057 6,7288T -2752.41 40,51]4] 5,967,131.83 48840,01 215 10,51].4] MWD(3) 14,053.18 91.28 292.04 5,05017 Sn8]] .274130 -10,54]43 5,96],14386 40039616 10.61 10,54713 MWD(3) 14,09219 90,48 284,78 5.848.n 5,72273 -272980 -10,5]3.]4 5967.15439 408,371,55 875 10,5]3]4 MVD(3) 14,120.53 90.]] 295.20 5,849.41 5.YAf -2717,90 40,599.43 5,867,16635 .g 6,07 1'84 10,599503 MMM (3) 14,15195 89.51 28802 5849.33 5,73]33 8,70.02 -1082].52 5.96748042 48931779 303 10.62TS2 MWD(3) 14,196.71 8920 300.16 584973 5,77.7 -26218113 -10657,09 5,96]49]32 48828742 622 10,657.09 MWO(3) 14,230.5] 9555 300.00 5,85120 5,729.20 -2669.95 -10,697.14 5,96721430 48035940 1070 10,80714 MWD(3) 14,25033 84,. 299.79 5,65363 5,]3183 -265530 40,71396 5,86],229.9] 40823236 540 1071285 MID 1420028 "'a. Mna 5.855.60 5,73460 -254141 -10,73930 5,96724285 40620502 5.69 10,73930 MWD(3) 1431281 8685 29601 $,858,97 5.73697 -2626. -10,76641 5,96]25739 496170.91 7..12 1076541 MND (3) 14.340.51 90.03 296.55 5,as. n 5]37]2 -261461 -10]9324 5,957269.65 488.15209 11.61 10,79324 MWD (3) Annotation a%, A 12!182018 6:51:16 papa 6 COMMSS 501114 Buaa 050 Survey ConocoPhillips ConocoPhillips Definitive Survey Report comPafry: ConoccPhII (Alaska) Inc Local Coordinate Reference: Viell2T-3T Pcohm: Kuparuk River Unit WD Reference. 2T4t7®122.00ush(Palker245) She: Kupamk 2T Pad MD Reference 2T-37®122.00us6(Parker 245) Well: 3T417 North Reference: True Wellbore: 2T4t7 Survey Calculation Method: Minimum Curvature Design: 2T-37 Database. EDT 14 Alaska Production Survey H4_I(ER WRES Annotation Projected to TD CW=118 6.51: i8PA1 Pape l COMPASS 5000, f4 9u6Je5D Map Ma MD (-am Inc, r) A61 19 TVD 1V836 H 4 aEim wortlnna ie, OL6 Section survey ram wme (def) luelll Ibael I-11,11(111 In) (.11n9l IDI 14.370.52 8843 29318 5860 t2 5]%t2 8,602.03 -10,820.37 5%].232.23 480,1248] 1247 10,020.37 MWD(a) 14401,47 67.M 291,8 5,861.12 5,739.12 -2,swm 40,840.96 5,867.39405 488,096.38 5,04 10,648.95 MWD(3) 1442990 87.69 290.74 5,862.22 57W.22 2,579.93 -10.075.44 5,967304.34 0.V,069.91 351 10, 87544 MPolI(3) 1445568 08.83 2911.% 6.80.00 5,74100 -257084 -10,89355 5.957.313,43 48d0toW 448 10,099.55 MMA)(3) 144%.84 07,02 289.41 5,864.13 5,742.13 .2590.a5 -1092860 5,991 48001845 9.02 10.828.93 MIND (3) 14519.76 no. 2889 5855.48 5,743.40 -2,550.14 -10,950.13 5.967,334 14 4870n 23 390 10.M.13 "D (3) 14553.22 8059 8639 5,066.39 574439 -2.SW.27 -10.99207 5,96738808 437,95389 5.40 10ER.07 WD (3) 14,513006 111 285.73 5'saai3 5744.93 -2,632,56 -11,018.62 596735 V3 487,926.74 3.25 1101062 MWD(3) 14613.33 87.9 294.98 S86 12 5]4M,12 -252263 -11054]9 5967.:8165 407.890.69 579 11,054]9 MAD(3) 14648.66 0586 285.44 5,86995 5,74795 -2.514.71 -1108395 5.957,369.50 401.88142 454 11,053.95 MAD(3) 1468.76 86.04 M8 83 5371,93 5}49.93 -2,507.85 -11,111.13 5.91 487,834.25 9.28 1111113 used (3) 14.87.W 85.57 280.19 567420 5.752,20 -2,WI,W -11,141.50 5,98730382 487.30388 861 11,14150 MWDC) 14.73338 85.48 278.23 5,8111 6754.20 -2.49760 -11,166.64 5,967305)0 487.77075 T.66 11,168.64 MVrD(3) 14 n7W 85.48 276.23 5,078W 5)57.64 -2491.38 -11,29.67 5887,39293 407,735.M 0.00 11.209.67 MAD (3) H4_I(ER WRES Annotation Projected to TD CW=118 6.51: i8PA1 Pape l COMPASS 5000, f4 9u6Je5D ConocoPhillips ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kuparuk 2T Pad 2T -37L1-01 PBI 50-103-20227-70 Baker Hughes INTEQ Definitive Survey Report 28 December, 2018 BA ER i UGHES 6Ecompagy ConocoPhillips q Conoc;Phill5 `� DefinitivSurvey Report Company'. ConocoPhlllips(Alaska) Inc Local Oourdlmda Reference: WAIT -37 Pmjecf: Kuparuk River Unit ND Reference: 2T-37 C 122.ODusR (Parkin 245) Stie: Kupamk 2T Pea MD Reference: 2TJ7®122.00usg(Parker 245) Wall. 2T-37 North Reference: Tine Wellborn 2T-37 Survey Calculation Method: Minimum Curvature Design: 2T-37 Database: EDT 14 Alaska Production Project Kupamk R'rvar Ung, Norah Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) system Datum: Mean See Level Gea Datum: NAD 1922 (NADCON CONUS) Using Well Pemmnce Point Map Zone: Alaska Zone 04 Using geodetic scale factor well 3TJ7 Well Position aw4 000 usit Northing: 5,969.882.48us0 Latitude: 70.19'44211N .044 000 cash Eaating: 498,944.62.0 Longdude: 150.0'30114W Position Uncertainty 0.00 rift Wellhead Elevation: us8 Ground Level: 00.50 usg Wellborn 2T-371.1-01 PBI Magnetlu Model Nems sample Data Doolhmtlon Dip Angle Fletd SDengtb M N (nT) BGGM2018 1211/2018 16.75 8085 57,427 Design 2T-371.1-01 PB1 Audit Notes: Version. 1.0 Phase: ACTUAL no On Depth: 10,771.05 Vertical sedum Depth From IWO) aMas aEUN Dimction (usN) (soft) fund" (') 41.50 0.00 0.00 270.00 Survey Program Date From To Survey sunray (ui (-ft) Survey(Wellbore) Taal Noma Description Start Daft End Dine 50.00 3,739.00 2T-37 GyneDam(2T-37) Copy of GYDLT-CMS Gymnaia cont.cnsng We 82512009 61252009 4,060.86 10,649.52 2T417 (2T47) MWD MWD -Standard 8/511995 81511995 10,710.00 10,771DS 2Ta71.1 MWIDONG QT41711) MWNNC ONLY MWD-ING ONLY FILLER 11122/2018 11222018 10,796.00 10,85734 2Ta71.141 PBI MM (2T -37L" 1 PB 1) MWD MWD -Southeast 112012018 1112912018 IWA2018 648:19PM Pap 2 COMPASS 5000.14 Bi 85D ConocoPhillips %� O ConocoPhillips Definitive Survey Report Company: ConccoPbilips(Alaska) Inc. Projost Kuparuk River llnn SHe: Kupamk 2T Pad Well: 2T -T7 Wellbore: 2T-37 Oesign: 2T417 Survey Local Loordlrn le Reference: TVD R<hrence: MD RebROte: North Reference: Survey Calculation Method: Database: Wb112T-37 2TJ7 ®122.00usg (Parker 245) 2T47 Q 122.00uefl (Parker 245) True Mniroum Curvature EDT 14 Alaska Production CN!W18 6:48: 19PM Page 3 COMPASS 500014 &bd 850 Map Map Vertical MD (usHl Inc (°) TVD TVO58 MdS Northing Eazting OLS Section eprn, Tool Wme ADnofation ('( (1 (YZM1( (usH( (ustl( Oaft) (usHl (H( IHI (°1100') (ft) 10771W 71.11 23421 5,86. 5,74206 365864 -7,442.68 5, 5kk.525 491,502.17 4260 744268 MNI34NC ONLY (3) Interpolated inyath-TIP 10)95.00 81.37 230.25 5,86.00 5.742.98 3.671.20 -7,463.37 5M.2126e 491401.48 41.20 7,45321] MWD(4) NOW 10,627.01 02.52 29.03 5,874.37 5.752.37 3,68282 -7.491.83 5,9620108 491,453.22 SON 7,49163 MWO(4) 10.357.24 88.TT 2685 5,876.67 5.75467 3586.48 -7,52148 5,665.19]43 49742337 4443 7,MIA0 MVHI(41 ID,e85.N @an 260.E6 5.87.33 57MA3 3WTU -7552.23 5968.19607 401. ]92.6a 06 1,552.23 PROJECTED to TO CN!W18 6:48: 19PM Page 3 COMPASS 500014 &bd 850 ConocoPhillips ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kuparuk 2T Pad 2T-37L1-01PB2 50-103-20227-71 Baker Hughes INTEQ Definitive Survey Report 28 December, 2018 BA ER 40 F�UGHES E- , �, 3kilips ConccoPhillips 1341(Ffta Conn DefiDdive Survey Report Company: Can ... Philips (Alaska) Inc. Local Coardin did Reference: M11 2T-37 Project: Kupamk River Unit TVD Reference: ZT-37@ 122.00usfl(Porker 245) Site: Ku"nuk 2T Pad MD Reference: 2TJ7 @ 122.00us6 (Parker 245) Well: ZT-37 Nonh Reference: True Wenbore: 2T-37 Survey Calculation Method: Minimum Curvature Design: 2T-37 Nubs.. EDT 14 Alaska Production Pm)ect Kupruk River Unit, North Slope Alaska, United States Map System: US State Plane 1924 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale Most Well 2T-37 Well Position +NIS 0.00 kid turthm, 5,969.882.48usR United.; 70°19'44.211N .Er -W 000 trap Fasting: 498,944.62 usfl Longitude: 150.0'30.814W Position Uncertainty 0.00uit Wellhead Elevation: art Ground Level: 80.50 use Wellbore 2T4l7L14i1PS2 Magnetic$ Model N.. Sample Data Oecllnatieo Dip Angle FIaM Strength r) (6n BGGM2019 12/112018 1615 00.65 57,427 Dodge 2T-37L1-01PB2 Audit Nates: Version: 1.0 Phu$: ACTUAL Tie On Depth: 10,771.05 Vertical Slone.: Depth F. (M) +WS aEfyy Dlradlon Net" loan) (IMS) 11) 41.50 a a0 ORD 270.00 Survey Program Data From To survey Survey )usn) (ush) Survey(Wellbord Tod Name Description Short Dab End Dale 50 DO 3.739.00 2T-37 GyroDa a (2T-37) Copy of GYD-CT-0MS Gymdda Contorting Ms 61262009 612512009 4,060.86 10,649.52 ZT47(2T-37) MWD MWD -Standard 01511995 815/1995 10.710.00 1017105 ZTd71-1 MVv¢INC(2T-37L1) MW INC ONLY MWD -INC ONLY_FILLER 111222018 11222018 10,780.00 10.84061 2T-371-1-01PB2 MM(2T-3711-01P82)MWD MWD -Standard 1112912018 iln=018 121162018 6:1 43jW Pags 2 COMPASS 5000.14 Budd 850 ConocoPhillips I&A • ConocoPhillips Definhilre Survey Report Company: CpnpcOPhillips (Alaska) Irc. Pmjecc Kupauk Rimr Lail Site: Kupamk 2T Pad Well: 2T47 Wellbore: 2T 37 Design'. 2T-37 Survey Local CoaMinate Reference: TIS Reference: MD Reference'. North Reference: Survey Calculation Metbed: Database: Wall2T-37 2T-37 @ 122.00usfl (Parker 245) 2T47 ®122.00usg (Parker 245) True Minimum Cunreame EDT 14 Alaska Production 12110!1018 548'43800 Page 3 COMPASS 5000 14 Budd 85D Map Map Vertical MD (uslry 1. (•) Ail (9 TVD TVOSS +NIS eEI-W Nanking Easting DLs Section survey Tool Nam. Mnotation (usn) (.SD) (..ft) (uso (D1 ("1 (•1100') (D) 10,]]1.05 71.11 239.21 5.864. C6 5.742.06 -3'.5664 -7,442.68 5,9658525 491,502 t] 4260 7 44268 MWD -NC ONLY (3) Interpolated Azimuth - TIP 10.]&1.00 ]4.]9 238,86 580668 5,]44.60 2,683.04 -],450.02 5,9Fb.220.85 481494.03 41297k050.02 MW 0.02 O(4) KOP 10,01241 7BW 24500 6 a 0 575180 -3,67].811 -7,471.80 5908.X6.02 491,486.97 2350 7,477.88 MD (4) 10,840.81 0489 249.32 5,071.70 5,]55]0 a,600.R -7,50362 5,966,195.19 491441.23 24.60 7,503.62 MWD(4) 10,869.00 8499 N9.32 5,800.18 5]58.18 .69670 -7,530.08 5,95518521 491 414J 0,00 7,530.00 PROJECTED W TO 12110!1018 548'43800 Page 3 COMPASS 5000 14 Budd 85D BA (ER HUGHES a GE company 21 81 20 30 19 8 Letter of Transmittal Date: --- -- _-- January 4, 2019 Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Michael Soper Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 2T -37L3 2T-37L3-01PB3 2T-37L1-01PB2 2T -37L3-01 RECEIVED JAN 0 4 2019 AQGCC (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Applications Engineer Michael.Soper@BakerHuehes.com ConocoPhillips ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kuparuk 2T Pad 2T -37L1-01 50-103-20227-61 Baker Hughes INTEQ Definitive Survey Report 28 December, 2018 BA ER I UGHES a GE company 21 81 20 30 19 8 ConocoPhillips 101, ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2T Pad MD Reference: Well: 2T-37 North Reference: Wellbore: 2T-37 Survey Calculation Method: Design: 2T-37 Database: Project Kuparuk River Unit, North Slope Alaska, United States Well 2T-37 2T-37 @ 122.00usft (Parker 245) 2T-37 @ 122.00usft (Parker 245) True Minimum Curvature EDT 14 Alaska Production BAER I UGNES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level ? Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2T-37 Well Position +N/ -S 0.00 usft Northing: 5,969, 882.48usft Latitude: 70'19'44.211N +E/ -W 0.00 usft Easting: 498,944.62usft Longitude: 150° 0'30.814 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 80.50 usft Wellbore 2T-3711-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (1) (nT) BGGM2018 12/1/2018 16.75 80.85 57,427 Design 2T -37L1 -01m_<..._.. - Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,649.52 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (�) 41.50 0.00 0.00 270.00 Survey Program Date � From To Survey 1 Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 50.00 3,739.00 2T-37 GyroData (2T-37) Copy of GYD-CT-CMS Gyrodam cont.casing m/s 6/25/2009 6/25/2009 4,068.86 10,649.52 2T-37 (2T-37) MWD MWD- Standard 8/5/1995 8/5/1995 j 10,680.00 14777.00 2T-3711-01 (2T-3711-01) MWD MWD - Standard 12/1/2018 12/7/2018 1228/2018 6: 51: 16PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. �...�..._~mm Local Coordinate Reference: Well 2T-37 vn=� Project: Kuparuk River Unit TVD Reference: 2T-37 @ 122.00usft (Parker 245) Site: Kuparuk 2T Pad MD Reference: 2T-37 @ 122.00usft (Parker 245) Well: 2T-37 North Reference: True Wellbore: 2T-37 Survey Calculation Method: Minimum Curvature Design: 2T-37 Database: EDT 14 Alaska Production Survey Annotation TIP KOP BqKHFS 12/282018 6.51: 16PM Page 3 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) (1) (1 Wait)(usft) lust) lush) Northing Easting (°1100') Section Surve Tool Name y (ft) (ft) (ft) 10,649.52 51.20 241.98 5,795.24 5,67324 -3510.86 -7,355.57 5,966,273.01 491,589.28 2.19 7,355.57 MWO(3) 10,680.00 51.04 242.05 5,814.37 5,692.37 -3,622.00 -7376.52 5,966,261 88 491,568.32 0.55 7,376.52 MM (3) 10,706.87 58.15 240.43 5,829.93 5,707.93 -3,632.54 -7,395.70 5,966,251.35 491,549.14 26.91 7,395.70 MWD (3) 10,736.02 7064 239.00 5,842.50 5,720.50 -3,645.78 -7,418.35 5,966,238.11 491,526.50 43.07 7,418.35 MWD (3) 10,776.71 87.30 23726 5,850.26 5,728.26 -3,666.81 -7,452.14 5,966,217.09 491,492.71 41.16 7,452.14 MM (3) 10,807.15 90.77 250.47 5,850.78 5,728.78 -3,680.18 -7,479.40 5,966,203.72 491,465.45 44.86 7,479.40 MM (3) 10,836.23 88.31 262.18 5,851.01 5,729.01 -3,687.05 -7507.60 5,966,196 86 491,437.25 41.14 7,507.60 MWD(3) 10,866.61 8840 275.37 5,851.89 5,729.89 -3,687.69 -7,537.89. 5,96.19622 491,406.96 43.40 7,537.89 MWD (3) 10,897.61 87.24 288.89 5,853.07 5,731.07 -3,681.20 -7,568.11 5,966,202.71 491,376.75 43.74 7,568.11 MWD (3) 10,927.67 88.10 297.92 5,854.30 5,732.30 -3,66928 -7,59564 5,966,214.63 491,349.22 30.15 7,595.64 MWD(3) 10,957.69 8828 301.94 5,855.24 5,733.25 -3,654.31 -7,621.64 5,966,22960 491,323.23 13.40 7,621.64 MWD (3) 10,986.02 88.43 305.82 5,856.06 5,734.06 -3,638.53 -7,645.15 5,966,245.39 491,29973 13.70 7,645.15 MWD (3) 11,018.17 88.13 30621 5,857.02 5,735.02 -3,619.64 -7,671.14 5,966,264.29 491,273.74 1.53 7,671.14 MWD (3) 11,048.18 86.84 303.61 5,858.34 5,736.34 -3,602.48 -7,695.72 5,966,28144 491,249.16 9.66 7,695.72 MWD (3) 11,077.53 88.31 301.96 5,859.58 5,737.58 -3,586.60 -7,720.38 5,96.297.32 491,224.51 7.53 7,720.38 MWD(3) 11,107.81 8862 300.87 5,860.39 5,738.39 -3,570.82 -7,746.21 5,966,313.10 491,198.69 3.74 7,746.21 MWD (3) 11,138.03 89.39 299.45 5,860.92 5,738.92 -3,555.64 -7,772.33 5,96.328.28 491,172.57 5.34 7,772.33 MWD (3) 11,168.37 89.54 297.80 5,861.20 5,739.20 -3,541.11 -7,798.96 5,96.342.82 491,145.94 5.46 7,798.96 MWD (3) 11,197.43 8843 295.01 5,861.72 5,739.72 -3,528.19 -7,824.98 5,966,355.74 491,119.92 10.33 7,824.98 MM (3) 11,227.09 87.70 293.44 5,862.72 5,740.72 -3,516.03 -7,852.01 5,96.367.91 491,092.90 5.83 7,852.01 MWD (3) 11,256.93 86.68 291.65 5,864.18 5,742.18 -3,504.60 -7,879.54 5,966,379.34 491,085.38 6.90 7,879.54 MWD (3) 11,28701 86.43 289.14 5,865.99 5,743.99 -3,494.14 -7,907.68 5,966,389.80 491,037.24 8.37 7,907.68 MWD (3) 11,317.25 86.03 287.14 5,867.98 5,745.98 -3,464.74 -7,936.35 5,966,39920 491,008.57 6.73 7,936.35 MWD (3) 11,347.36 87.05 284.52 5,869.79 5,747.80 -31476.55 -7,965.27 5,966,40740 490,979.66 9.32 7,965.27 MWD (3) 11378.27 8840 281.99 5,87102 5,749.02 -3,469.47 -7,995.32 5,96.41449 490,949.61 9.27 7,995.32 MM (3) 11,407.81 89.11 279.76 5,87166 574966 -3,463.89 -8,024.33 5,966,420.06 490,920.61 7.92 8,024.33 MM (3) 11,437.67 9040 278.64 5,871.79 5,749.79 -3,459.12 -8,053.60 5,965,424.84 490,891.14 5.72 8,053.80 MWD(3) 11,467.55 92.03 277.42 5,871.16 5,749.16 -3,454.95 -8,083.38 S,966,429.02 490,861.56 6.81 8,083.38 MM (3) 11497.73 92.67 275.67 5,86992 5,747.92 -3,451.51 -8,113.34 5,966,432.46 490,831.61 6.17 8,113.34 MWD (3) 11,527.23 9187 277.17 5,868.75 5,746.75 -3,448.21 -8,142.63 5,966,435.76 490,802.32 5.76 8,142.63 MWD (3) Annotation TIP KOP BqKHFS 12/282018 6.51: 16PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. Local Co-ordinate Reference: Well 2T-37 Project: Kuparuk River Unit TVD Reference: 2T-37 @ 122.00usft (Parker 245) Site: Kuparuk 2T Pad MD Reference: 2T-37 @ 122.00usft (Parker 245) Well: 2T-37 North Reference: True Wellbore: 2T-37 Survey Calculation Method: Minimum Curvature Design: 2T-37 Database: EDT 14 Alaska Production Survey 12/28/2018 6:51: 16PM Page 4 BAS ER UGHES Annotation COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W DLS _ (usft) V) V) (usft) (usft) (usft) (usft) Northing Easting (0(100') Section Survey Tool Name (ft) (ft) (ft) 11,55762 91.20 260.72 5,86794 5,745.94 -3,443.49 -8,172.63 5,96,44048 490,772.32 11.88 8,17263 MWD (3) 11,58240 91.72 284.40 5,867.18 5,745.18 -3,437.02 -,201.68 5,966,446.96 490,743.27 12.48 8,201 68 MM (3) 11,619.33 91.90 288.53 5,866.17 5,744.17 -3,427.98 -8,23228 5,966,456.01 490,712.68 12.94 8,23228 MWD (3) 11,648.68 91.72 291.44 5,865.24 5,743.24 -3,417.95 -8,259.85 5,966,46603 490,685.12 9.93 8,259.85 MWD (3) 11,677.07 9115 294.11 5,864.38 5,742.38 -3,406.97 -8,286.01 5,966,477.02 49,658.96 9.40 8,286.01 MM (3) 11,70804 9264 295.80 5,863.20 5,741.20 -3,393.91 -8,314.07 5,966,49008 490,630.91 6.16 8,314.07 MWD (3) 11,741.09 9,127 294.30 5,861.20 5,739.20 -3,379.94 -8,343.95 5,966,50405 490,601.03 6.70 8,343.95 MWD(3) 11,770.02 9402 292.80 5,859.11 5,737.11 3.36841 -8,370.40 5,966,51558 490,574.58 5.24 8,370.40 MWD (3) 11,799.80 92.98 291.26 5,857.30 5,735.30 -3,357.27 -8,397.96 5,966,526.73 490,547.03 6.23 8,397.96 MWD (3) 11,830.15 92.52 289.58 5,855.84 5,733.84 -3,34669 -8,426.36 5,966,53731 490,51863 5.73 8,426.36 MWD(3) 11,860.49 92.06 28746 5,854.63 5,732.63 -3,337.06 -8,455.11 5,966,54699 490,489.89 7.14 8,455.11 MWD (3) 11,890.70 93.51 286.40 5,853.16 5,731.16 -3,328.27 -8,483.97 5,96,555.73 490,461.03 5.94 8,483.97 MWD (3) 11,920.17 93.11 284.62 5,851.46 5,729.46 3,320.41 -8,512.32 5,96,63.60 490,432.68 6.18 8,512.32 MWD (3) 11,950.73 92.98 282.25 5,849.83 5,727.83 -3,313.32 -8,542.00 5,966,570.70 490,403.01 7.76 8,542.00 MWD (3) 11,980.52 94.80 282.16 5,847.81 5,725.81 -3,307.03 -8,571,05 5,966,576.98 490,373.96 6.12 8,571.05 MWD (3) 12,010.67 96.52 282.47 5,844.84 5,722.84 -3,300.64 -8,600.36 5,966,583.38 490,34465 5.80 8,600.36 MWD (3) 12,040.45 96.49 280.81 5,841.47 5,719.47 3,294.67 -8,629.34 5,96,589.36 490,315.68 5.54 8,629.34 MWD (3) 12,070.14 94.36 278.84 5,838.66 5,71666 3,289.62 -8,658.46 5,966,594.40 490,286.56 9.75 8,658.46 MWD (3) 12,100.73 93.32 277.39 5,83661 5,714.61 3,285.32 -8,688.68 5,966,598.72 490,256.35 5.82 8,688.68 MWD (3) f 12,130.30 91.90 275.30 5,835.26 5,713.26 -3,282.05 -8,718.03 5,966,601.98 490,227.00 8.54 8,718.03 MM (3) 12,160.98 92.03 273.26 5834.21 5,71221 3,279.76 -8,748.61 5,96,60428 490,196.43 6.66 8,74861 MWD (3) 12,19068 92.36 271.36 5,833.07 5,711.07 3,278.57 -8,778.26 5,96,605.48 490,16.78 6.49 8,77826 MWD (3) 12,220.52 93.6 269.76 5,831.52 5,709.52 3,278.28 -8,808.06 5,96,605.77 490,136.98 6.78 8,808.06 MWD (3) 12,251.21 92.98 271.65 5,829.76 5,70776 3,277.90 -8,838.69 5,96,606 .15 490,16.35 6.47 8,83869 MWD (3) 12,280.82 92.67 274.78 5,828.30 5,706.30 -3,276.24 -8,86.22 5,96,607.82 490,076.83 10.61 8,68.22 MWD (3) 12,310.69 91.14 278.11 5,827.31 5,705.31 -3,272.89 -8,897.87 5,96,611.17 490,047.17 12.26 8,897.87 MWD (3) 12,340.52 89.72 280.00 5,82708 5,705.08 3,26.19 -8,927.33 5,96,615.87 490,017.72 7.92 8,927.33 MM (3) 12,370.56 91.26 282.57 5,826.83 5,704.83 3,262.32 -8,956.79 5,96,621.75 489,96.27 9.97 8,96.79 MWD (3) 12,405.28 92.27 285.48 5,825.76 5,703.76 -3,253.91 -8,990.45 5,96,630.16 489,954.61 8.87 8,99045 MM (3) 12,436.30 92.06 287.63 5,824.58 5,702.59 -3,245.08 -9,020.16 5,96,639.00 489,924.90 6.96 9,020.16 MWD (3) 12,465.20 8801 287.81 5,824.57 5,702.57 -3,236.28 -9,04768 5,966,647.79 489,897.39 1403 9,047.68 MWD (3) 12/28/2018 6:51: 16PM Page 4 BAS ER UGHES Annotation COMPASS 5000.14 Build 85D ConocoPhillips St@ER ConocoPhillips Definitive Survey Report GM Company: Project: Site: Well: P Wellbore: Design: i��.__._._...._,..�. ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kuparuk 2T Pad 2T-37 2T-37 2T-37 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: _..-_.-.-__.-.._._._..-.,._.,,....__.��..._..�,,,......,.__....____...-.._- Well 2T-37 2T-37 @ 122.00usft (Parker 245) 2T-37 @ 122.00usft (Parker 245) True Minimum Curvature EDT 14 Alaska Production .... . --- ----...�.____..........,.�. Survey Map Map Vertical MD Inc Azl TVD TVDSS *E/ -W DLS I usft) (us (°) (°) (usft) (usft) lush) (usft) (usft) Northing Easting V/100') Section Survey Tool Name AODOtafi0n S (ft) (ft) (ft( 12,495.33 86.53 29046 5,826.00 5,704.00 -3,226.42 -9,076.11 5,966,65766 489,668.96 10.07 9,076.11 MWO(3) 12,524.93 86.34 292.90 5,827.64 5,705.84 -3,215.51 -9,103.56 5,966,66858 489,841.51 8.25 9,103.55 MM (3) 12,555.00 87.11 295.19 5,829.56 5,707.56 -3,203.27 -9,13098 5,966,680.81 489,814.10 8.02 9,130.98 MWD (3) 12,585.06 87.30 298.95 5,831.03 5,709.03 -3,189.61 -9,157.71 5,966,694.47 489,787.38 12.51 9,157.71 MWD (3) 12,615.16 87.85 302.15 5,832.30 5,710.30 -3,174.33 -9,183.60 5,966,709.76 489,76149 10.78 9,183.60 MWD (3) 12,645.20 88.74 30463 5,833.20 5,711.20 -3,157.81 -9,208.67 5,966,726.29 489,736.42 8.77 9,208.67 MWD (3) 12,674.79 8969 303.13 5,833.60 5,711.60 -3,141.31 -9,23323 5,966,742.78 489,711.87 6.00 9,233.23 MWO(3) 12,704.91 88.46 302.21 5,834.09 5,712.09 -3,125.06 -9,25859 5,966,759.04 489,686.52 5.10 9,258.59 MWD (3) 12,730.38 8297 300.95 5,834.88 5,712.88 3,111.73 -9,280.27 5,966,772.37 489,664.84 5.31 9,280.27 MWD (3) 12,759.71 87.05 299.80 5,836.15 5,714.16 3,096.91 -9,305.55 5,966,787.19 489,639.56 5.02 9,305.55 MWD (3) 12,790.12 85.20 298.13 5,838.21 5,716.21 -3,08222 -9,332.09 5,966,80168 489,613.02 8,19 9,332.09 MM (3) 12,821.52 8464 29761 5,840.99 5,718.99 -3,067.74 -9,359.82 5,966,81636 489,585.31 3.98 9,359.82 MWD (3) 12,850.06 8369 29469 5,843.89 5,721.89 -3,055.36 -9,385.37 5,966,828.74 489,559.76 8.75 9,385.37 MWD (3) 12,886.26 82.74 292.42 5,848.17 5,726.17 -3,041.00 -9,418.32 5,966,843.11 489,526.82 6.76 9,418.32 MWD (3) 12,915.33 83.01 290.39 5,851.78 5,729.78 3,03047 -9,445.17 5,966,853.64 489,499.97 6.99 9,445.17 MWD (3) 12,945.25 82.69 288.51 5,85550 5,733.50 -3,020.59 -9,473.16 5,966,86353 489,471.98 6.33 9,473.16 MWD (3) 12,975.40 83.57 286.91 5,859.11 5,737.11 -3,01148 -9,501.68 5,966,872.64 489,44347 662 9,501.68 MWD (3) 13.05.13 84.06 28564 5,862.31 5,740.31 -3,00320 -9530.05 5,966,880.92 489,415.10 r56 9,530.05 MM (3) 13,035.61 84.46 283.89 5,865.36 5,743.36 -2,99547 -9,559.37 5,966,88866 489,385.78 5.86 9,659.37 MWD (3) p 13,065.69 85.64 283.05 5,867.95 5,745.95 -2,98049 -9,588.52 5,966,895.64 489,35664 4.81 9,588.52 MM (3) It 13,095.15 86]8 283.51 5,869.90 5,747.90 -2,981.74 -9,617.12 5,966,902.40 489,328.04 4.17 9,617.12 MWD(3) 1 13,130.60 88.25 284.83 5,871.44 5,749.44 -2,973.07 -9,651A6 5,966,911.7 489,293.71 5.57 9,651.46 MWD (3) 13,160.27 89.69 285.73 5,871.97 5,749.97 -2,965.25 -9,680.08 5,966,918.89 489,265.09 5.72 9,680.08 MWD (3) 13,196.02 90.37 284.78 5,87195 5,749.95 -2,955.84 -9,714.57 5,966,928.30 489,230.61 3.27 9,714.57 MWD (3) 13,227.91 90.12 282.50 5,871.82 5,749.82 -2,948.32 -9,745.56 5,966,935.82 489,199.62 7.19 9,745.56 MWD (3) 13,262.00 88.83 28068 5,872.13 5,750.13 -2,941.47 -9,778.95 5,966,942.68 489,166.24 6.54 9,778.95 MWD (3) 13,290.51 88.46 277.91 5,872.80 5,750.80 -2,936.87 -9,807.07 5,966,94728 489,138.12 9.80 9,87.07 MWD(3) 13,320.15 88.37 276.17 5,873.62 5,751.62 -2,93324 -9,836.48 5;966,95092 489,108.72 5.88 9,836.48 MAD (3) 13,350.21 88.28 274.99 5,874.50 5,75250 -2,930.32 -9,866.38 5,966,953.84 489,078.81 3.94 9,866.38 MM (3) 13,381.19 89.45 275.18 5.875.12 5,753.12 -2,927.57 -9,89723 5,906,956.59 489,047.97 3.83 9,897.23 MWD(3) 13,411.51 90.21 274.06 5,875.21 5,753.21 -2925.13 -9,92745 5,966.95904 489017.75 4.46 9.92745 MWD (3) 1228/2018 6:51: 16PM Page 5 COMPASS Woo 14 Build 85D ConoCoPIIIIIIpS Company: ConocoPhillips (Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 2T Pad Well: 2T-37 Wellbore: 2T-37 Design: 2T-37 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2T-37 2T-37 @ 122.00usft (Parker 245) 2T-37 @ 122.00usft (Parker 245) True Minimum Curvature EDT 14 Alaska Production 122872018 6:51: 16PM Page 6 % 0 Annotation COMPASS 5000.14 Build 85D Map Vertical MD Inc Azi ND NDSS +N/-5 +E/ -W DLS (usft) (1) V) (usft) (usft) (usft) lush) Northing Eastn g (°/100') Section Survey Tool Name y (ft) (ft) (ft) 13,442.16 90.74 275.09 5,874.95 5,752.95 -2,922.69 -9,95800 5,966,96149 488,987.20 3.76 9,958.00 MWD (3) 13,473.06 92.21 276.68 5,674.16 5,752.16 -2,919.52 -9,988.73 5,966,964.66 488,956.48 7.01 9,98813 MWD (3) 13507.41 92.64 279.18 5,872.70 5,750.70 -2,914.79 -10,022.72 5,965,96940 488,922.50 7.38 10,022.72 MM (3) 13,54070 93.29 278.98 5,870.98 5,748.98 -2,909.54 -10,055.55 5,966,974.65 488,889.67 2.04 10,055.55 MWD (3) 13,570.35 95.01 279.71 5,668.83 5,746.84 -2,904.74 -10,084.72 5,966,97945 488,860.0 6.30 10,084.72 MM (3) 13,0640 95.04 281.06 5,866.20 5,749.20 -2,899.34 -10,114.17 5,966,984.85 488,831.06 4.48 10,114.17 MWD(3) 13,63041 95.81 282.88 5,863.37 5,741.37 -2,893.15 -10,143.39 5,966,991.05 488,801.84 6.56 10,143.39 MWD (3) 13,660.05 9628 284.88 5,80.24 5,738.24 -2,886.08 -10,172.00 5,90,998,12 488,773.23 6.89 10,172.00 MWD (3) 13,690.38 96.21 286.78 5,856.94 5,734.94 -2,877.85 -10,201.01 5,967,006.35 488,744.23 6.23 10,201.01 MWD (3) 13,718.14 95.33 289.00 5,854.15 5,732.15 -2,869.37 -10,227.29 5,967,014.84 488,717.95 8.56 10,227.29 MM (3) 13,746.21 9440 290.93 5,851.77 5,729.77 -2,859.82 -10,253.58 5,967,024.39 488,69167 7.61 10,253.58 MWD (3) 13,772.98 93.31 293.37 5,849.97 5,727.97 -2,849.75 -10,278.31 5,967,034.46 488,666.93 9.96 10,278.31 MWD (3) 13,798.84 93.0 294.76 5,848.44 5,726.44 -2,83922 -10,301.88 5,967,04499 488,643.37 5.42 10,301.88 MWD (3) 13,832.08 90.83 295.13 5,847.18 5,725.18 -2,825.21 -10,332.00 5,967,059.0 488,613.26 8.11 10,332.0 MWD (3) 13,861,19 88.99 294.11 5,847.23 5,725.23 -2,813.09 -10,358.46 5,967,071.13 488,586.80 723 10,358.46 MWD (3) 13,890.40 86.22 292.19 5,848.45 5,726.45 -2,801.62 -10,385.29 5,967,082.61 488,559.97 11.53 10,385.29 MWD(3) 13,921.77 86.87 29094 5,850.34 5,728.34 -2,790.11 -10,414.41 5,967,094.12 488,530.86 4,48 10,414.41 MWD (3) 13,952.55 90.31 291.14 5,851.09 5,729.09 -2,779.06 -10,443.13 5,967,105.17 488,02.15 11.19 10,443.13 MWD (3) 13,975.52 90.46 290.53 5,850.94 5,728.94 -2,770.89 -10,464.59 5,967,113.34 488,480.68 2.73 10,464.59 MM (3) 14,005.67 90.0 288.83 5,850.81 5,728.81 -2,70.74 -10,492.98 5,967,123.49 488,452.30 5.82 10,492.98 MWD (3) 14,01.54 90.58 288.75 5,850.67 5,72867 -2,752.41 -10,517.47 5,967,131.83 488,427.81 2.15 10,517.47 MWD(3) 14,053.19 91.26 292.04 5,850.17 5,728.17 -2,741.38 -10,54213 5,967,142.86 488,398.16 10.61 10,547.13 MWD (3) 14,092.19 90.49 294.76 5,849.72 5,727.72 -2,729.86 -10,573.74 5,967,154.38 488,371.55 9.75 10,573.74 MM (3) 14,120.53 90.77 295.20 5,849.41 5,727.41 -2,717.90 -10,599.43 5,967,166.35 488,345.87 1.84 10,599.43 MWD(3) 14,151.95 89.51 298.02 5,849.33 5,727.33 -2,70.82 -10,627.52 5,967,180.42 488,317.79 9.83 10,627.52 MWD (3) 14,186.71 89.20 30.16 5,849.73 5,727.73 -2,686.93 -10,657.89 5,967,197.32 488,287.42 6.22 10,657.89 MWD (3) 14,220.57 85.55 30.09 5,851.28 5,729.28 -2,669.95 -10,687.14 5,967,214.30 488,258.18 10.78 10,667.14 MWD (3) 14,20.33 Mall 298.79 5,853.83 5,731.83 -2,655.38 -10,712.96 5,967,22887 488,232.36 5.40 10,712.96 MWD (3) 14,20.28 84.80 297.09 5,856.60 5,734.60 -2,641.41 -10,739.30 5,967,242.85 488,206.02 569 10,739.30 MWD (3) 14,312.91 86.86 296.01 5,858.97 5,736.97 -2,626.86 -10,76841 5,967,25239 488,17691 7.12 10,768.41 MWD (3) 14,34061 90.03 296.55 5,859.72 5.73772 -2,614.61 -10,793.24 5,967,26965 488,152.09 1161 10,793.24 MWD(3) 122872018 6:51: 16PM Page 6 % 0 Annotation COMPASS 5000.14 Build 85D ConocoPhillips Company: ConocoPhillips (Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 2T Pad i Well: 2T-37 Wellbore: 2T-37 Design: 2T-37 ISurvey MD Inc Azi TVD TVDSS (usft) (°) (°) (usft) (usft) 14,37052 8843 293.18 5,860.12 5,738.12 14,401.47 87.88 291.72 5,861.12 5,739.12 14,429.90 8769 290.74 5,862.22 5,740.22 14,455.68 88.83 290.56 5,863.00 5,741.00 14,486.84 87.02 288.41 5,864.13 5,742.13 14,519.76 88.28 288.17 5,865.48 5,743.48 14,55322 88.59 286.39 5,856.39 5,744.39 14,580.86 89.20 28573 5,866.93 5,7*193 14,618.38 87.17 284.96 5,868.12 5,746.12 14,64866 85.88 285.44 5,869.95 5,747.95 14,676.76 8604 282.83 5,871.93 5,749.93 14,707.84 85.57 280.19 5,874.20 5,752.20 14,733.38 85.48 27823 5,876.20 5,754.20 14,77700 85.48 278.23 5,879.64 5,757.64 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: Norm Reference: Survey Calculation Method: Database: Well 2T-37 2T-37 @ 122.00usft (Parker 245) 2T-37 Q 122.00usft (Parker 245) True Minimum Curvature EDT 14 Alaska Production BA (ER UGRES Annotation Projected to TD 12282018 6.51.16PM Page 7 COMPASS 5000.14 Build 85D Map Map Vertical +N/ -S (usft) -E/-W Northing Easting DLS Section Survey Tool Name (usft) (ft) (it) (°flog•) (ft) -2,602.03 -10,820.37 5,967,282.23 488,124.97 12.47 10,820.37 MWD(3) -2,590.22 -10,848.96 5,967,294.05 488,095.38 5.04 10,848.96 MWD (3) -2,579.93 -10,875.44 5,967,304.34 488,069.91 3.51 10,875.44 MWD (3) -2,570.84 -10,899.55 5,967,313.43 488,045.80 4.48 10,899.55 MWD (3) -2,560.46 -10,928.90 5,967,323.81 488,016.45 9.02 10,928.90 MWD(3) -2,550.14 -10,960.13 5,967,334.14 487,985.23 3.90 10,960.13 MWD (3) -2,540.20 -10,932.07 5,967,344.08 487,953.29 5.40 10,992.07 MWD(3) -2,532.56 -11,018.62 51967,351.73 487,926.74 3.25 11,018.62 MWD (3) -2,522.63 -11,054.79 5,967,361.65 487,890.58 5.79 11,054.79 MM (3) -2,514.71 -11,083.95 5,967,369.58 487,861.42 4.54 11,083.95 MWD (3) -2,507.86 -11,111.13 5,967,376.43 487,834.25 9.28 11,111.13 MWD(3) -2,501.68 -11,141.50 5,967,38262 487,80388 8.61 11,141.50 MWD (3) -2,49760 -11,166.64 5,967.386.70 487,778.75 766 11,166.64 MM (3) -2,491.38 -1120967 5,96739293 487,73572 0.00 11,209.67 MWD (3) BA (ER UGRES Annotation Projected to TD 12282018 6.51.16PM Page 7 COMPASS 5000.14 Build 85D ea GI ES a GE company 218120 30199 Letter of Transmittal Date: ---- -----— January 4, 2019 Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Michael Soper Baker Hughes, a GE Company 795 East 94`h Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 2T -37L1 2T-371.3-01PB1 2T-371.3-01PB2 2T -37L1-01 RECEIVED JAN 042019 AOGCC (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Applications Engineer Michael.Soaer@BakerHughes.com ConocoPhillips ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kuparuk 2T Pad 2T -37L1-01 PB1 50-103-20227-70 Baker Hughes INTEQ Definitive Survey Report 28 December, 2018 BA ER F UGHES a GE company 21 81 2p 30 19 9 111� ConocoPhillips BArR ConocoPhillips Definitive Survey Report "I Company: �._____.-._.._--.._.... ConocoPhillips (Alaska) Inc. __.__ . _ .. Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2T Pad MD Reference: Well: 2T-37 North Reference: Wellbore: 2T-37 Survey Calculation Method: Design: 2T-37 Database: Project Kuparuk River Unit, North Slope Alaska, United States Tie On Depth: 10,771.05 Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) +N/ -S Map Zone: Alaska Zone 04 c Well 2T-37 I 70° 19'44.211 N Well Position +N/ -S 0.00 usft Northing: usft +E/.W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore Magnetics Design Audit Notes: Version: Vertical Section: 'q Survey Program f From (usft) 50.00 4,068.86 10,710.00 10,796.00 2T -37L1-01 PB1 Model Name Sample Date BGGM2018 12/1/2018 2T -37L1-01 PB1 Well 2T-37 2T-37 @ 122.00usft (Parker 245) 2T-37 @ 122.00usft (Parker 245) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Phase: ACTUAL Tie On Depth: 10,771.05 Using Well Reference Point Using geodetic scale factor Depth From (TVD) +N/ -S +E/ -W Direction c 5,969,882.48usft Latitude: I 70° 19'44.211 N 498,944.62usft Longitude: 150° 0' 30.814 W usft Ground Level: 80.50 usft 0.00 270.00 Declination Dip Angle Field Strength _ (nT) 16.75 80.85 57.42 7 1.0 Phase: ACTUAL Tie On Depth: 10,771.05 Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 41.50 0.00 0.00 270.00 Date...___-�-�.�..6....�—._�e,.�.�..,e........_�®._..._ _ ,.,.»�...-w. .-.. To Survey Survey (usft) Survey (Wellbore) Tool Name Description Start Data End Date 3,739.00 2T-37 GyroData (2T-37) Copy of GYD-CT-CMS Gyrodata cont.casing m/s 6/25/2009 6/25/2009 10,649.52 2T-37 (2T-37) MWD MWD- Standard 8/5/1995 8/5/1995 10,771.05 2T-3711 MWD-INC(2T-371-1)MWD-INC_ONLY MWD-INC–ONLY–FILLER 11/22/2018 11/22/2018 10,857.24 2T-3717-01 P131 MWD (2T-3711-01 PBl) MWD MWD - Standard 11/28/2018 11/292018 121282018 6:48:19PM Page 2 COMPASS 5000.14 Suild 85D Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. Local Co-ordinate Reference: Well 2T-37 jProject: Kuparuk River Unit TVD Reference: 2T-37 @ 122.00usft (Parker 245 1 Site: Kuparuk 2T Pad MD Reference: 2T-37 @ 122.00usft (Parker 245 Well: 2T-37 North Reference: True ! Wellbora: 2T-37 Survey Calculation Method: Minimum Curvature Design: 2T-37 Database: EDT 14 Alaska Production Survey Map Map Vertical — MD Inc Pad TVD TVDSS +N/ -S +E/ -W DLS (usft) (o) 0 (usft) (usft) (usft) (usft) Northing Easting (olloo.) Section Survey Tool Name (ft) (ft) (ft) 10,771.05 71.11 239.21 5,864.06 5,742.06 -3,658.64 -7,442.68 5,966,225.25 491502.17 42.80 7,442.68 MWD -INC ONLy(3) 10,796.00 81.37 238.25 5,869.98 5,747.98 -3,671 20 -7,463.37 5,966,212.69 491,481.48 41 29 7,463.37 MM (4) f C 10,827.01 82.52 257.03 5,874.37 5,752.37 -3,682.82 -7,491.63 5,966,201.08 491,453.22 60.07 7,491.63 MWD(4) I! 10,857.24 88.77 26896 5,876.67 5,754.67 -3,686.48 -7,521.48 5,966,197.43 491423.37 44.43 7,521.48 MWD (4) 10,888.00 88.77 26896 5,877.33 5,755.33 -3,687.04 -7,552.23 5,966,196.87 49139263 0.00 7,55223 PROJECTED to TD Annotation Interpolated Azimuth - TIP KOP 1228/2018 6:48:19PM Page 3 COMPASS 5000.14 Build 85D BA (ER I-,UGHES a GE company Date: January 4, 2019 Abby Bell AOGCC 333 West 71" Ave, Suite 100 Anchorage, Alaska 99501 21 81 20 30200 Letter of Transmittal Michael Soper Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 2T -37L1 2T-37L1-01PB1 2T -37L1 -01P62 2T -37L1-01 RECEIVED JAN 0 4 2019 AOGCC (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Applications Engineer Michael.SoperPBakerHuehes.com ConocoPhillips ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kuparuk 2T Pad 2T -37L1-01 PB2 50-103-20227-71 Baker Hughes INTEQ Definitive Survey Report 28 December, 2018 BAT(ER UGHES a GE company 21 81 2p 302U0 ConocoPhillips BA ER ConocoPhillips Definitive Survey Report tucHEs Company: ConocoPhillips (Alaska) Inc. Local Co-ordinate Reference: Well 2T-37 Project: Kuparuk River Unit TVD Reference: 2T-37 @ 122.00usft (Parker 245) i Site: Kupamk 2T Pad MD Reference: 2T-37 @ 122.00usft (Parker 245) Well: 2T-37 North Reference: True Wellbore: 2T-37 Survey Calculation Method: Minimum Curvature Design: 2T-37 Database: EDT 14 Alaska Production I Project Kuparuk River Unit, North Slope Alaska, United Statesm Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2T-37 Well Position +N7 -S 0.00 usft Northing: 5,969,882.48usft Latitude: 70° 19'44.211 N +E7 -W 0.00 usft Easting: 498,944.62usft Longitude: 150° 0' 30.814 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 80.50 usft Wellbore 2T -3711-01P132 i Magnetics Model Name Sample Date Declination Dip Angle Field Strength = (`) (') (nT) BGGM2018 12/1/2018 1675 80.85 57,427 Design 2T -37L1-01 PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,771.05 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) +. 41.50 0.00 0.00 270.00 Survey Program Date 1 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 50.00 3,739.00 2T-37 GyroData (2T-37) Copy of GYD-CT-CMS Gyrodata cont.casing m/s 6/25/2009 6/25/2009 4,068.86 10,649.52 2T -37 (2T-37) MWD MWD - Standard 8/5/1995 6/5/1995 10,710.00 10,771.05 2T-3717 MWD -INC (2T-3711) MWD -INC ONLY MWD -INC _ONLY _FILLER 11/22/2018 11/22/2018 t( I 10,780.00 10,840.61 2T-3711-01PB2MWD(2T-37L1-01PB2) MWD MWD -Standard 11/29/2018 11/30/2018 ? 1228/2016 6:48:43PM Page 2 COMPASS 5000.14 Build 850 ConocoPhillips ER ConocoPhillips Definitive Survey Report r!+�DxEs Company: ConocoPhillips (Alaska) Inc. Project Kuparuk River Unit Site: Kuparuk 2T Pad Well: 2T-37 Wellbore: 2T-37 Design: 2T-37 Local Co-ordinate Reference: Well 2T-37 TVD Reference: Survey (Parker 245) INTO Reference: 2T-37 @ 122.00usft -, MD Inc Azi TVD TVDSS +N/ -S (usft) (1) V) (usft) (usft) (usft) 10,771.05 71.11 239.21 5,864.06 5,742.06 -3,658.64 10,780.00 74.79 238.86 5,865.68 5,744.68 -3,653.04 10,812.41 79.50 245.00 5,873.90 5,751.90 -3,677.88 10,640.61 84.99 249.32 5,877.70 5,755.70 -3,688.72 10,869.00 84.99 249.32 5,880.18 5,758.18 -3,698.70 Local Co-ordinate Reference: Well 2T-37 TVD Reference: 2T-37 @ 122.00usft (Parker 245) INTO Reference: 2T-37 @ 122.00usft (Parker 245) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Map Map Vertical +E/ -W (usft) Northing Easting DLS Section Survey Tool Name Y (ft) (ft) (.1100.) (ft) -7,442.68 5,966,225.25 491,502.17 42.80 7,442.68 MWD-INC_ONLY (3) -7,450.02 5,966,220.85 491,494.83 41.29 7,450.02 MWD(4) -7,477.88 5,966,206.02 491,466.97 23.50 7,477.88 MWD(4) -7,503.62 5,966,195.19 491,441.23 2468 7,503.62 MWD (4) -7530.08 5,966,18521 491,41477 OAO 7,530.08 PROJECTED to TD Annotation Interpolated Azimuth - TIP KOP 12/282018 6:48:43PM Page 3 COMPASS 5000.14 Build 85D 21 u1--� BA ER PRINT DISTRIBUTION LIST 3 0 1 8 1 F�UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2T -37L1-01 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(a�bakerhughes.com STATUS Final Replacement: COMPANY ADDRESS PEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V I BP North Slope. FOA, PBOC, PRB-20 (Office 109) D&G WO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. .Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. AM: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 F.xxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Attn: Natural Resources Technician 11 333 W.7th Ave, Suite 100 Anchorage, Alaska 99501 en se sign and return one copy of this transmittal form to: xoPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. ioraze. Alaska 99510 LOG TYPE GR - RES LOG DATE December 11, 2018 TODAYS DATE January 2, 2019 Revision Details: Rev. Requested by: --- FIELD I FINAL CD/DVD FINAL PRELIM (las, dlis, PDF, META, I SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES I# OF COPIES I# OF COPIES V VV V V V 0 0 0 0 0 NOGUu 0 1 1 0 0 5 DNR- Division of Oil & Gas *** 0 1 0 0 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, IR2-I 900 E. Benson Blvd .Anchorage, Alaska 99508 0 1 0 1 1 1 0 10 TOTALS FOR THIS PAGE: 0 1 3 0 0 BA ER HE %' ' PRINT DISTRIBUTION LIST FUGS a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2T-37L1-01PBI FIELD Greater Kuparuk Area CD/DVD COUNTY North Slope Borough PRELIM BHI DISTRICT Alaska SURVEY AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider�hes.com 2 18 120 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 LOG TYPE GR - RES LOG DATE December 11, 2018 TODAYS DATE January 2, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY ADDRESS (FEDEX MLL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V t BP North Slope. EOA, PROC. PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarieo ATO 708 700 G Street Anchorage, AK 99510 3 Exxon Mobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska -AOGCC IAM: Natural Resources Technician It 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 FIELD FINAL CD/DVD FINAL PRELIM LOGS (las, rills, PDF, META, SURVEY REPORT LOGS 1 CGM, Final Suryeys) (Com)ass) 0 # OF PRINTSV OF PRIN # OF COPIES J# OF COPIES I# OF COPIES 4 4 4 9 4 a 5 DNR- Division ofOil & Gas *** 0 0 '1 0 Q Atm: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. 1 0 0 '1 0 0 Petrotechnical Dam Center, IR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 3 0 0 s 0 1 i 0 0 5 DNR- Division ofOil & Gas *** 0 0 '1 0 Q Atm: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. 1 0 0 '1 0 0 Petrotechnical Dam Center, IR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 3 0 0 BAN(ER 0 PRINT DISTRIBUTION LIST UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2T-37L1-01PB2 FIELD Greater Kuparuk Area CD/DVDFINAL COUNTY North Slope Borough PRELIM BHI DISTRICT Alaska SURVEY AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider@bakerhuahes.com 21 81 20 30180 se sign and return one copy of this transmittal form to: ocoPhillips Alaska, Inc. I Osterkamp (WNS Petroleum Technician) G Street. horage, Alaska 99510 LOG TYPE GR - RES LOG DATE December 11, 2018 TODAYS DATE January 2, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEX WILL NOT DELVER TO P.O. 90X) PERSON ATTENTION V I BP North slope. EOA, PBOC, PRB-20 (Office 109) D&G WO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 Exxon Mobil, Alaska Atm: Lynda M. Yaskell and/or Leonardo Elias 13201 C Street, Suite 505 Anchorage, AK 99503 FIELD I FINAL CD/DVDFINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRIN Ur MIN 901- COPIES I#QFCQPIES # OF COPIES is is 4 9 4 a Q`GG�`v� 4 State of Alaska - AOGCC 0 i i 0 Q Attn: Natural Resources Technician 11 1333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas *** 0 0 'I 0 Q Ann: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6'' BP Exploration (Alaska) Petrotechnical Data Cer 900 E. Benson Blvd .Anchorage, Alaska 9950 TOTALS FOR THIS PAGE: 0 1 3 0 0 THE STATE Alaska Oil and Cas °fALASKA Conservation Commission GOVERNOR BILL WALKER James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2T -37L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-120 Surface Location: 98' FNL, 556' FWL, SEC. 12, TI IN, R8E, UM Bottomhole Location: 2632' FNL, 240' FEL, SEC. 9, TI IN, R8E, UM 333 west 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.aogcc.claska.gov Dear Mr. Ohlinger: Enclosed is the approved application for the permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 195-101, API No. 50-103-20227-00- 00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair -k , DATED this t 2' day of October, 2018. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill ❑ Lateral ❑Q Redrill ❑ Reentry0l 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG LJ Service - Disp ❑ Stratigraphic Test ❑ Development -Oil ❑� • Service- Winj ❑ Single Zone E ' Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 1c. Specify if well. is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket Q • Single Well ❑ Bond No. 5952180 11. Well Name and Number: KRU 2T -37L1-01 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14900' TVD: 5881' 12. Field/Pool(s): Kuparuk River Pool / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 98' FNL, 556' FWL, Sec 12, Tl lN, R8E, UM Top of Productive Horizon: 3771' FNL, 1633' FEL, Sec 10, T11 N, R8E, UM Total Depth: 2632' FNL, 240' FEL, Sec 9, T11N, R8E, UM 7. Property Designation:2�L ADL 25568 r�DL ZSS 8. DNR Approval Number: LONS 84-133 /p"`Y'7� 13. Approximate Spud Date: 11/5/2018 9. Acres in Property: 2560 14. Distance to Ne ,s}t Propsj�v: �271Ti Tfd° K r' '"-1��vs is v( nr 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 498945 • y- 5969882 - Zone- 4 10. KB Elevation above MSL (ft): 122' GL / BF Elevation above MSL (ft): 81' • 15. Distance to Nearest Well Open to Same Pool: 120', 2T-38 16. Deviated wells: Kickoff depth: 10800' feel Maximum Hole Angle: 93 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 3392 Surface: 2808 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) 3" 2-3/8" 4.7# L-80 ST -L 4280' 10620' . 5777' 14900', 5881' Slotted 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 11080' 6067' N/A 10984' 6006' 10982' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 103 sx ASI 121' 121' Surface 4104' 9-5/8" 860 sx ASII I, 400 sx G, 240 sx ASI 4145' 2890' Production 11035' 7" 240 sx Class G 11074' 6066' Perforation Depth MD (ft): 10675'- 10698' Perforation Depth TVD (ft): 5811'- 5826' 10720'- 10740' 5839'- 5852' Hydraulic Fracture planned? Yes ❑ No ❑v P Sketch 20. Attachments: Properly Plat ❑ DiveOer Sketch 8 lling Program Dot Sleabed Report e Drilling ng Fluid Program av. Depth l m Shallow Hazard Analysis B✓ 20 AAC 25.050 requirements e✓ 21. Verbal Approval: Commission Representative: Dale 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: Keith Herring Authorized Name: James Ohlinger Contact Email: Keith. E. Herrin CO .com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4321 Authorized Signature: Dale: �O �� Commission Use Only Permit to Drill Number. G�jj l API Number: / / 50- j(j'3 '- ��7 (!3( ' Permit Approval Date: IU 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 as hydrates, or gas contained in shales: Other: ,FOP �� Samples req'd: Yes ❑ No [R Mud log req'd: Yes ❑ oLrj 5 t to 35 00 s �/ dYl n v:q✓ .. � 5 HzS measures: Yes LtQ No❑ Directional svy req'd: Yes No ❑ 1/ fJ (,%Vlv7 r r �-!S f jp 5(GGps�cSexception req'd: Yes ❑ Nov Inclination -only svy req'd: Yes❑ No[Z' A Vetr-Ia?J arc y"b �ofi%rC z� 0/je'b acr§ Post initial injection MIT req'd: Yes No [!I— /S 9rantrd io a!/ow the ��� �oFFpo7hf to bz any /001'n f &i 7 -he p4r5r"t /a 7Yva l APPROVED BY t Approved by: COMMISSIONER THE COMMISSION Date: �X\ y / u�%/1�1 D �111��� 11� L Submit Form and ARr 0'!ry evised 5/2017 Tis permit is valid for 4 R! ttotn � ire proval per 20 AAC 25.0 Attachments in Duplicate vC'1% I V ftAr l l /v,F 1 ,cz ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 04, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill two laterals out of the KRU 2T-37 (PTD# 195-101) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in early November 2018. The objective will be to drill two laterals KRU 2T -37L1 and 2T-371_1-01 targeting the Kuparuk A -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: - Permit to Drill Application Forms (10-401) for 2T-371_1 and 2T-371_1-01 - Detailed Summary of Operations - Directional Plans for 2T -37L1 and 2T-371_1-01 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals ' 2T-371-1 and 2T-371-1-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))...................................................................................................................2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005 (c)(4)) ............... ............................................................................................... --........................ ....... 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)) ................... _......... ............... ............................................................... _.. _.. _........................... 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 7. Diverter System Information ..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................ 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))........--....................................................................................................................................4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))......................................................................................................................................................6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 2T-371-1 and 2T-371-1-01 laterals... ......................................................................... 6 Attachment 2: Current Well Schematic for 2T-37............................................................................................................6 Attachment 3: Proposed Well Schematic for 2T-371-1 and 2T-371-1-01 laterals..............................................................6 Page 1 of 6 October 04, 2018 PTD Application: 2T -37L1 & 2T-371-1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 2T-371_1 and 2T -37L1-01. The laterals will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10401 form for surface and subsurface coordinates of the 2T-371_1 and 2T-371-1-01. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. Using the maximum formation pressure in the area of 3,392 psi in 2A-23 (i.e. 11.3 ppg EMW), the maximum potential surface pressure in 2T-37, assuming a gas gradient of 0.1 psi/ft, would be 2,808 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 2T-37 was measured to be 2,670 psi (8.9 ppg EMW) on 7/16/2018. The maximum downhole pressure in the 2T-37 vicinity is the 2A-23 at 3,392 psi (11.3 ppg EMW) measured on 3/15/2013. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) / The offset injection wells to 2T-37 have injected gas, so there is a possibility of encountering free gas while drilling the 2T-37 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) / The major expected risk of hole problems in the 2T-37 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 2T-37 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 October 04, 2018 PTD Application: 2T -37L1 & 2T -37L1-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 2T -37L1 10,800' 13,600' 5,752' 5,785' 2-3/8", 4.7#, L-80, ST -L slotted liner; 0' 121' 1640 670 Surface aluminum billet on to 2T-371-1-01 10,620' 14,900' 5,655' 5,759' 2-3/8", 4.7#1 L-80, ST -L slotted liner; 2890' , , Production 7" with deployment sleeve on to Existing Casing/Liner Information Category OD Weight _tpf Grade Connection Top MD Btm MD Top TVD Btm TVD Burst In Collapse psi Conductor 16" 62.5 H-40 Welded 0' 121' 0' 121' 1640 670 Surface 9-5/8" 40.0 L-80 BTC 0' 4145' 0' 2890' 5750 3090 Production 7" 26.0 L-80 BTC MOD 0' 11074' 0' 6066' 7240 5410 Tubing 3-1/2" 9.3 L-80 ABM EUE 0' 10626' 0' 5780' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based PowerVis mud (8.6 ppg) — Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and shale stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 2T-37 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 October 04, 2018 PTD Application: 2T-371_1 & 2T -37L1-01 Pressure at the 2T-37 Window 10720' MD, 5840' TVD Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 2T-37 is a Kuparuk A -Sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A -sands to the south and west of 2T-37. The laterals will recover resource to the south that has been hydraulically suppressed and recover production to the west from the long-term shut-in producer 2T -38A. CDR3-AC will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned kick off point of 10,720' MD. The 2T -37L1 lateral will exit through the 7" casing at 10,720' MD and TD at 13,600' MD, targeting the A sand to the south. It will be completed with 2-3/8" slotted liner from TD up to 10,800' MD with an aluminum billet for kicking off the 2T -37L 1-01 lateral. The 2T -37L1-01 lateral will drill to a TD of 14,900' MD targeting the A sand to the west. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 10,620' MD with a deployment sleeve. Pre -CTD Work 1. RU Slickline: Drift tubing with dummy whipstock and obtain S13HP. 2. RU Service Coil: Mill out "D" nipple and conduct FCO 3. Prep site for Nabors CDR3-AC rig. Page 4 of 6 October 04, 2018 Pumps On 1.8 bpm) Pumps Off A -sand Formation Pressure 8.8 2670 psi 2670 psi Mud Hydrostatic 8.6 2612 psi 2612 psi Annular friction i.e. ECD, 0.08psi/ft) 857 psi 0 psi Mud + ECD Combined no chokepressure) 3469 psi Overbalanced —799psi) 2612 psi Underbalanced —58psi) Target BHP at Window 11.8 3445 psi 3445 psi Choke Pressure Required to Maintain Target BHP 0 psi 833 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 2T-37 is a Kuparuk A -Sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A -sands to the south and west of 2T-37. The laterals will recover resource to the south that has been hydraulically suppressed and recover production to the west from the long-term shut-in producer 2T -38A. CDR3-AC will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned kick off point of 10,720' MD. The 2T -37L1 lateral will exit through the 7" casing at 10,720' MD and TD at 13,600' MD, targeting the A sand to the south. It will be completed with 2-3/8" slotted liner from TD up to 10,800' MD with an aluminum billet for kicking off the 2T -37L 1-01 lateral. The 2T -37L1-01 lateral will drill to a TD of 14,900' MD targeting the A sand to the west. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 10,620' MD with a deployment sleeve. Pre -CTD Work 1. RU Slickline: Drift tubing with dummy whipstock and obtain S13HP. 2. RU Service Coil: Mill out "D" nipple and conduct FCO 3. Prep site for Nabors CDR3-AC rig. Page 4 of 6 October 04, 2018 PTD Application: 2T-371_1 & 2T-371-1-01 ]illi Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2T -37L1 Lateral (A3 sand - South) a. Set top of high expansion wedge at 10,720' MD. b. Mill 2.80" window at 10,720' MD. c. Drill 3" bi-center lateral to TD of 13,600' MD. d. Run 2-3/8" slotted liner with aluminum billet from TD up to 10,800' MD. 3. 2T -37L1-01 Lateral (A3 sand -West) a. Kickoff of the aluminum billet at 10,800' MD. b. Drill 3" bi-center lateral to TD of 14,900' MD. c. Run 2-3/8" slotted liner with deployment sleeve from TD up to 10,620' MD. 4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 1. Return well to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA un -deployment, the steps listed above are observed, only in reverse. Liner Running — The 2T-37 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids' section for more details. — While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. Page 5 of 6 October 04, 2018 PTD Application: 2T-371-1 & 2T -37L1-01 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(6)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 2T-371-1 3900' r 2T -37L1-01 50' j 50-ttci -tv Distance to Nearest Well within Poolyp7 p , L: Lateral Name Distance Weilf 2T-371-1 265' 2A-17 2T -37L1-01 120' 2T-38 16. Attachments Attachment 1: Directional Plans for 2T -37L1 and 2T -37L1-01 laterals Attachment 2: Current Well Schematic for 2T-37 Attachment 3: Proposed Well Schematic for 2T -37L1 and 2T -37L1-01 laterals Page 6 of 6 October 04, 2018 ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 2T Pad 2T-37 2T-371-1-01 Plan: 2T-37L1-01_wp03 Standard Planning Report 03 October, 2018 BT�a GHES GE company Baker Hughes INTEQ BA ER 1 ConocoPhillips Planning Report F�UGHES a GE company Database: OAKEDMPI Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 2T Pad Well: 2T-37 Wellbore: 2T-37Li-01 Design: 2T-37L1-01_wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2T-37 Mean Sea Level 2T-37 @ 122.00usft(Parker 245) . True ' Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) • Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2T Pad Site Position: Northing: 5,970, 382.43 usft Latitude: 70° 19' 49.129 N From: Map Easting: 498,944.93 usft Longitude: 150° 0' 30.807 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.01 ° Well 2T-37 Well Position +N/ -S 0.00 usft Northing: Version: +El -W 0.00 usft Easting: Position Uncertainty Depth From (TVD) 0.00 usft Wellhead Elevation: Wellbore 2T-3711-01 Magnetics Model Name BGGM2018 Sample Date 12/112018 5,969,882.48 usft Latitude: 498,944.62 usft Longitude: usft Ground Level: Declination Dip Angle V) V) 16.75 70° 19'44.211 N 150° 0'30.814 W - 80.50 usft Field Strength (nT) 8085 57427 Design 2T-37L1-01_wp03 Audit Notes: Version: Phase: PLAN Te On Depth: 10,800.00 Vertical Section: Depth From (TVD) +NIS +El -W Direction (usft) (usft) (usft) (I -80.50 0.00 0,00 300.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°1100usft) (°/10ousft) (°(100usft) (°) Target 10,800.00 81.04 242.15 5,752.11 -3,669.72 -7,466.80 0.00 0.00 0.00 0.00 10,870.00 91.04 272.13 5,757.05 -3,684.96 -7,534.04 45.00 14.28 42.83 73.00 11,270.00 90.92 300.14 5,750.09 -3,574.91 -7,914.41 7.00 -0.03 7.00 90.00 11,670.00 90.34 272.14 5,745.62 -3,464.84 -8,294.81 7.00 -0.14 -7.00 269.00 12,070.00 90.30 300.14 5,743.35 -3,354.74 -8,675.23 7.00 -0.01 7.00 90.00 12,420.00 88.62 275.70 5,746.71 -3,247.86 -9,005.70 7.00 -0.48 -6.98 266.00 12,820.00 89.72 303.68 5,752.66 -3,114.43 -9,378.53 7.00 0.28 7.00 88.00 13,200.00 90.19 277.08 5,752.96 -2,983.28 -9,731.55 7.00 0.13 -7.00 271.00 13,500.00 90.18 298.08 5,751.97 -2,893.15 -10,015.93 7.00 0.00 7.00 90.00 13,800.00 93.74 277.37 5,741.61 -2,802.31 -10,299.90 7.00 1.19 -6.90 280.00 14,100.00 88.18 297.63 5,736.53 -2,712.56 -10,584.36 7.00 -1.85 6.75 105.00 14,500.00 88.40 269.62 5,748.71 -2,619.29 -10,969.06 7.00 0.05 -7.00 270.00 14,900.00 88.58 297.63 5,759.47 -2,526.02 -11,353.79 7.00 0.05 7.00 90.00 10/3/2018 12:06:51 PM Page 2 COMPASS 5000.14 Build 85 Baker HugheslNTEQ BA ER ConocoPhillips Planning Report F�UGHE$ aGE company Database: OAKEDMPI Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 2T Pad Well: 2T-37 Wellbore: 2T-371.1-01 Design: 2T-3711-01 wp03 Planned Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2T-37 Mean Sea Level 2T-37 @ 122.00usft (Parker 245) True Minimum Curvature Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/S +E/ -W Section Rate Azimuth Northing Easting (usft) (1) (.) (usft) (usft) (usft) (usft) (°1100usft) (°) (usft) (usft) 10,800.00 81.04 242.15 5,752.11 -3,669.72 -7,466.80 4,631.58 0.00 0.00 5,966,214.17 491,478.05 TIP/KOP 10,870.00 91.04 272.13 5,757.05 -3,684.96 -7,534.04 4,682.19 45.00 73.00 5,966,198.95 491,410.81 End 45 dls, Start 7 dls 10,900.00 91.04 274.23 5,756.51 -3,683.29 -7,563.99 4,708.96 7.00 90.00 5,966,200.62 491,380.87 11,000.00 91.02 281.23 5,754.71 -3,669.84 -7,663.00 4,801.43 7.00 90.04 5,966,214.08 491,281.87 11,100.00 91.00 288.24 5,752.94 -3,644.43 -7,759.64 4,897.83 7.00 90.16 5,966,239.51 491,185.25 11,200.00 90.95 295.24 5,751.24 -3,607.42 -7,852.46 4,996.71 7.00 90.29 5,966,276.52 491,092.44 11,270.00 90.92 300.14 5,750.09 -3,574.91 -7,914.41 5,066.63 7.00 90.41 5,966,309.04 491,030.50 3 11,300.00 90.88 298.04 5,749.62 -3,560.33 -7,940.63 5,096.62 7.00 -91.00 5,966,323.62 491,004.29 11,400.00 90.75 291.04 5,748.20 -3,518.83 -8,031.53 5,196.09 7.00 -91.03 5,966,365.13 490,913.40 11,500.00 90.60 284.04 5,747.02 -3,488.72 -8,126.81 5,293.67 7.00 -91.13 5,966,395.25 490,818.13 11,600.00 90.45 277.04 5,746.10 -3,470.44 -8,225.06 5,387.89 7.00 -91.21 5,966,413.55 490,719.89 11,670.00 90.34 272.14 5,745.62 -3,464.84 -8,294.81 5,451.10 7.00 -91.28 5,966,419.16 490,650.15 4 11,700.00 90.34 274.24 5,745.44 -3,463.17 -8,324.77 5,477.87 7.00 90.00 5,966,420.83 490,620.20 11,800.00 90.34 281.24 5,744.85 -3,449.71 -8,423.79 5,570.36 7.00 90.01 5,966,434.31 490,521.19 11,900.00 90.33 288.24 5,744.28 -3,424.28 -8,520.44 5,666.78 7.00 90.05 5,966,459.75 490,424.55 12,000.00 90.31 295.24 5,743.72 -3,387.26 -8,613.26 5,765.68 7.00 90.09 5,966,496.77 490,331.74 12,070.00 90.30 300.14 5,743.35 -3,354.74 -8,675.23 5,835.60 7.00 90.13 5,966,529.30 490,269.79 6 12,100.00 90.15 298.05 5,743.23 -3,340.15 -8,701.44 5,865.59 7.00 -94.00 5,966,543.89 490,243.58 12,200.00 89.66 291.06 5,743.39 -3,298.62 -8,792.34 5,965.08 7.00 -94.01 5,966,585.43 490,152.70 12,300.00 89.18 284.08 5,744.40 -3,268.45 -8,887.61 6,062.67 7.00 -94.00 5,966,615.61 490,057.44 12,400.00 88.71 277.10 5,746.24 -3,250.09 -8,985.83 6,156.91 7.00 -93.93 5,966,633.98 489,959.23 12,420.00 88.62 275.70 5,746.71 -3,247.86 -9,005.70 6,175.23 7.00 -93.80 5,966,636.21 489,939.37 6 12,500.00 88.82 281.30 5,748.51 -3,236.05 -9,084.77 6,249.62 7.00 88.00 5,966,648.03 489,860.31 12,600.00 89.08 288.29 5,750.34 -3,210.53 -9,181.38 6,346.04 7.00 87.87 5,966,673.56 489,763.71 12,700.00 89.37 295.29 5,751.69 -3,173.44 -9,274.17 6,444.94 7.00 87.75 5,966,710.66 489,670.94 12,800.00 89.66 302.28 5,752.55 -3,125.32 -9,361.75 6,544.85 7.00 87.65 5,966,758.79 489,583.36 12,820.00 89.72 303.68 5,752.66 -3,114.43 -9,378.53 6,564.83 7.00 87.59 5,966,769.68 489,566.59 7 12,900.00 89.81 298.08 5,752.98 -3,073.39 -9,447.16 6,644.78 7.00 -89.00 5,966,810.72 489,497.97 13,000.00 89.94 291.08 5,753.20 -3,031.82 -9,538.04 6,744.28 7.00 -88.98 5,966,852.30 489,407.11 13,100.00 90.07 284.08 5,753.19 -3,001.63 -9,633.31 6,841.88 7.00 -88.96 5,966,882.50 489,311.85 13,200.00 90.19 277.08 5,752.96 -2,983.28 -9,731.55 6,936.13 7.00 -88.96 5,966,900.87 489,213.63 8 13,300.00 90.19 284.08 5,752.62 -2,964.92 -9,829.78 7,030.38 7.00 90.00 5,966,919.24 489,115.40 13,400.00 90.19 291.08 5,752.29 -2,934.73 -9,925.05 7,127.98 7.00 90.02 5,966,949.44 489,020.15 13,500.00 90.18 298.08 5,751.97 -2,893.15 -10,015.93 7,227.47 7.00 90.05 5,966,991.03 488,929.28 9 13,600.00 91.39 291.19 5,750.60 -2,851.50 -10,106.76 7,326.96 7.00 -80.00 5,967,032.69 488,838.47 13,700.00 92.58 284.29 5,747.12 -2,821.07 -10,201.89 7,424.56 7.00 -80.09 5,967,063.13 488,743.35 13,800.00 93.74 277.37 5,741.61 -2,802.31 -10,299.90 7,518.82 7.00 -80.33 5,967,081.90 488,645.36 10 13,900.00 91.90 284.14 5,736.68 -2,783.69 -10,397.96 7,613.06 7.00 105.00 5,967,100.54 488,547.31 14,000.00 90.04 290.89 5,734.98 -2,753.62 -10,493.25 7,710.62 7.00 105.33 5,967,130.61 488,452.03 14,100.00 88.18 297.63 5,736.53 -2,712.56 -10,584.36 7,810.04 7.00 105.45 5,967,171.68 488,360.94 11 14,200.00 88.20 290.63 5,739.69 -2,671.72 -10675.51 7909.40 7.00 -90.00 5,967,212.53 488,269.80 10MO18 12:06:51PM Page 3 COMPASS 5000.14 Budd 85 Baker Hughes INTEQ BA ConocoPhillips Planning Report F GHES aGEmmpany Database: OAKEDMP1 Vertical Company: _ConocoPhillips Export Company Project: Kupamk River Unit +E/ -W Site: Kuparuk 2T Pad Azimuth Well: 2T-37 (usft). Wellbore: 2T-371-1-01 (°1100usft) Design: 2T-3711-01_wp03 (usft) Planned Survey -10,770,97 8,00678 Measured -89.78 TVD Below Depth Inclination Azimuth System (usft) (I V) (usft) 14,300.00 88.24 283.63 5,74281 14,400.00 88.30 276.63 5,745.83 14,500.00 88.40 269.62 5,748.71 12 -11,068.81 8,278.94 14,600.00 88.41 276.63 5,751.51 14,700.00 88,44 283.63 5,754.26 14,800.00 88.50 290.63 5,756.93 14,900.00 • 88.58 297.63 5,759.47 Planned TO at 14900.00 8,470.28 Casing Points Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method Well 2T-37 Mean Sea Level 2T-37 @ 122.00usft (Parker 245) True Minimum Curvature Measured Vertical Vertical Dogleg Toolface Map Map +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft). (usft) (usft) (°1100usft) (`) (usft) (usft) -2,642.30 -10,770,97 8,00678 700 -89.78 5,967,241.96 486,174.35 -2,624.74 -10,869.31 8,100.73 7.00 -89.56 5,967,259.53 488,076.03 -2,619.29 -10,969.06 8,189.83 7.00 -89.35 5,967,264.99 487,976.29 -2,613.85 -11,068.81 8,278.94 7.00 90.00 5,967,270.45 487,876.55 -2,596.29 -11,167.15 8,372.89 7.00 89.80 5,967,288.03 487,778.22 -2,566.86 -11,262.62 8,470.28 7.00 89.61 5,967,317.46 487,682.77 -2,526.02 -11,353.79 8,569.67 7.00 89.42 5,967,358.31 487,591.61 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 14,900.00 5,759.47 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth -NI-S +E/ -W (usft) (usft) (usft) (usft) Comment 10,800.00 5,752.11 -3,669.72 -7,466.80 TIP/KOP 10,870.00 5,757.05 -3,684.96 -7,534.04 End 45 dls, Start 7 dis 11,270.00 5,750.09 -3,574.91 -7,914.41 3 11,670.00 5,745.62 -3,464.84 -8,294.81 4 12,070.00 5,743.35 -3,354.74 -8,675.23 5 12,420.00 5,746.71 -3,247.86 -9,005.70 6 12,820.00 5,752.66 -3,114.43 -9,378.53 7 13,200.00 5,752.96 -2,983.28 -9,731.55 8 13,500.00 5,751.97 -2,893.15 -10,015.93 9 13,800.00 5,741.61 -2,802.31 -10,299.90 10 14,100.00 5,736.53 -2,712.56 -10,584.36 11 14,500.00 5,748.71 -2,619.29 -10,969.06 12 14,900.00 5,759.47 -2,526.02 -11,353.79 Planned TO at 14900.00 10/32018 12:06.51PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Bpl(ER ConocoPhillips Travelling Cylinder Report l*E HES a GEcompry Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Reference Site: Kuparuk 2T Pad Site Error: 0.00 usft Reference Well: 2T-37 Well Error: 0.00 usft Reference Wellbore 2T-371-1-01 Reference Design: 2T-37L1-01_WpO3 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2T-37 2T-37 @ 122.00usft (Parker 245) 2T-37 @ 122.00usft (Parker 245) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference 2T-3711-01 Wp03 Filtertype: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Date 9/28/2018 Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 10,800.00 to 14,900.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,685.85 usft Error Surface: Pedal Curve Summary Survey Tool Program Date 9/28/2018 From TO Reference Offset Centre to (usft) (usft) Survey (Wellbore) Tool Name Description 10.800.00 14,900.00 2T-3711-01_Wp03(2T-37LI-01) MWD MWD -Standard Measured Casing Points Distance Deviation Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 4,145.00 95/8" 9.625 12.250 14,900.00 5.881.47 2 3/8" 2.375 3.000 Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 2T Pad 2T -21 -2T -21-2T-21 11,762.01 11,325.00 738.16 210.57 547.14 Pass - Major Risk 2T -36 -2T -36-2T-36 13,260.81 12,650.00 1,229.49 464.19 902.12 Pass - Major Risk 2T -37 -2T -37-2T-37 10,813.92 10,825.00 30.45 19.80 30.04 Pass - Minor 1/10 2T-37-2T-371-1-2T-371-7_wp03 10,824.66 10,825.00 2.92 23.96 2.70 Pass - Minor 1/10 2T -38 -2T -38-2T-38 14,029.22 13,100.00 119.56 15.54 108.32 Pass - Mi nor 1/10 2T -38 -2T -38A -2T -38A 13,741.47 12,675.00 475.99 20.81 456.10 Pass - Minor 1/10 Offset Design Kuparuk 2T Pad - 2T-21 - 2T-21 - 2T-21 onansae Enor: ew..n Survey P"..: 50 -Copy of GVDATCMS, 5611 -GCT -MS Rubs,aah, ed:Major Risk Main MR E.I. 0.00 use Reference Onset Semi Major Aria Measured vertical Mcusurea Veronal Rare... offset Toolface+ Offset WalooreceOlM Casing- Canlre to Noes, Allowable Warrlily DepIM1 Depth Depth capon Arlmu[h aN/4 .iam Hole sort Centre Diaoxi,a Deviation (usft) (usft) roam (usft) (usft) (usft) r) jusm Rise) PN (usft) (use) (usft) 10.934.33 5,877.39 10,275.00 4.961 Al 2.90 43.11 -7570 y55996 -7.567,44 5400 92589 15793 805.21 Pass - Major Risk 10.95702 5,877.48 10,300.00 491105 300 4327 -74.75 -3,588.83 -7,588.49 5.000 914.43 158.16 79329 Pass - Major Risk 10,978.90 5,877.08 10325.00 4,980.45 3.19 4342 -73AH -3,578.37 -7,609.59 5.000 903.27 150.36 781.61 Pass - Major Risk 11000.20 5.076.70 10.350.0 4,989.72 3.43 4157 -7120 -3,587.96 4,630.74 5.000 892.33 150.50 770.11 Pass - Major Risk 11,020.67 5,876.34 10.375.00 4.990.91 3.72 43.73 42.56 -3,597.59 -01051.90 5.000 881.61 150.59 750.76 Pass - Major Risk 11.040.40 5,875.99 10,400.0 5,008.03 4.01 43.88 -72.04 -3,607.26 -7.673.07 5.000 871.11 150.77 747.60 Pass - Major Risk 11,059.39 5.875.65 1040500 5.017.11 4.31 44.04 -71.62 -3,616.94-7aU.26 6.000 860.85 150.90 730.62 Pass - Major Risk 11,077.80 5.875.33 10,45000 5,026.12 4.60 44.19 -71.31 -3,626.65 -7,715.48 5.000 850.87 159.12 725.66 Pass - Major Risk 11095.28 5,875.02 %475.00 5,035.00 4.88 44.35 -71.09 3,836.39 -7738.88 5.000 041.20 159.26 715.36 Pass - Major Risk 11,112.22 5,87473 10,500.00 5,043.95 5.15 44.51 -70.97 -3,646.13 -7,757.91 5.000 831.09 15437 705.15 Pass. Major Risk 11,128.53 5.874.45 10.525.00 5.05277 5,42 44.66 -70.95 -3,655.91 4,779.17 5.000 822.98 159.45 895.28 Pass - Malar Risk 11,144.21 5,874.18 10.550.00 5,061.51 5.67 44.82 -71.02 -3,665+71 4,800+44 5.00 814.47 159.52 685.74 Pass - Major Risk 11,159.30 5,973.92 10,575.00 5,070.22 5.92 44.98 .71.18 -3,675.51 4,82173 5.000 850.30 159.58 arse Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 9282018 6:19:59PM Page 2 COMPASS 5000.14 Build 85 PrOjeCt: Kapamk River Unit Site: Kupamk 2T Pad 0" Well: 2T.37 Wellbore: 2T.371-1.01 ConocoPhillips Plan: V47Ll4ll_wp03 (2`r-37W-371-1�1) MLLBORE DETAILS: 2T-371.1�1 Parent Wellbere: 2T-3711 T,eonMD 10800.00 -240C -2800 -3200 .3600 -4000 44N 4800 2 r-5600 0 �,6000 ,."00 0 .6800 -7200 .7600 -8000 REPERENCE NFORWTION C�irml MCN -are MHNVjm�N� RAr =RD) R�� Wa� -R U@ �&n (VS) R=. SM - PXN. OWE) 1HES W..W DM �W- 2T -V @ 122vNnft (ft,W, 29) ce�en �: m"... MEN WELL DETAILS: m 2T-37 +N1 -S +EI -VV Northing Easting Latitude Longitude 0.00 0.00 5969882.48 498944.62 70* 19' 44.211 N 150' 0'30.814 W Sac MID Inc Azi TVDSS -N/-S +E/ -W Dleg TFam VSect Annotation 1 10800.00 81.04 242.15 5752.11 -3669.72 -7466.80 UO UO 46311.58 TIPIKOP 2 10870.00 91.04 272.13 6757.05 -3694.96 -7534.04 46.00 73.00 4682.19 End 45 cls, Start 7 cls 3 11270.00 90.92 300.14 5750.09 -3574.91 -7914.41 7.00 90.00 5066.63 3 4 11670.00 90.34 272.14 5745.62 3464.84 -8294.81 7.00 269.00 5451.10 4 5 12070.00 90.30 300.14 5743.35 -3354.74 -8675.23 7.00 90.00 5835.60 5 6 12420.00 88,62 275.70 5746.71 .3247.86 -9005.70 7.00 266.00 6175.23 6 7 12820.00 89.72 303.68 5752.66 -3114.43 -9378.53 7.00 88.00 6664.83 7 8 13200.00 90.19 277.08 5752.96 -2983.28 -9731.55 7.00 271.00 6936.13 8 9 13500.00 90.18 298.08 5751.97 -2893.15-10015.93 7.00 90.00 7227.47 9 10 13800.00 93.74 277.37 5741.61 -2802.31-10299.90 7.00 280.00 7518.82 10 11 14100.00 88.18 29T63 5736.63 .2712.56 -10584.36 7.00 105.00 7810.04 11 12 14500.00 88.40 269.62 5748.71 -2619.29-10969.06 7.00 270.00 8189.83 12 13 14900.00 8&68 297.63 5759.47 -2626.02 -11353.79 7.00 90.00 8569.67 Planned TD at 14900.00 -240C -2800 -3200 .3600 -4000 44N 4800 2 r-5600 0 �,6000 ,."00 0 .6800 -7200 .7600 -8000 REPERENCE NFORWTION C�irml MCN -are MHNVjm�N� RAr =RD) R�� Wa� -R U@ �&n (VS) R=. SM - PXN. OWE) 1HES W..W DM �W- 2T -V @ 122vNnft (ft,W, 29) ce�en �: m"... (Aon 9 0 5 MEN m W 0 0 m -- ------ 0 I I - -- .- WON WEE 5250 No on NONE 0 MW 1111 NUNN 111111 MEN mom 0 No M No m NO (Aon 9 0 5 -- ------ � I I I - -- .- 51 00 5250 5400 5550 le, I 57 - - - - - - - - - - - 5850 6000 I nd 45 iNta t 7 d1s I Pl.� ��d Ti t 14� WOO i M37/ T -37L 1.01 6150 T-3 �t T-37 ZT 3812T -:BA - T-3812 r-38 - - - - - - - - - 6300 - - - - - - - 2 17.371.1 Ya.1t 21371.1- 1 F.Al �Tl 1,2 6450 - T 1. --H - - - - - - 6600 U. � �.. - - I 1 11 2 Vertical Section at 300.001 (150 ustVin) WO ConocoPhillips Project: K1lparuk River Unit Site: Kuparok 2T Pad n.,�,uunonw xonn weMla awn Is1s e Mpm4c F2m WELLBORE DETAILS: 2T -37L1 KFERENCE INFOFUAnoa Parent WelibMO 2064 CPmFak ( ) RNw el 2TT"e Well: 2T-3] -1600- sire"W� slas>°^r Tie On MD'. 10649.52 vemc4(1w) Retaence: 2ra]4y 1' en leatsr 245) w, [ Wellbore: 2T-3TL1 a>^re»: eo es seam (vsl aeMerce. W - Plan: 2T37LY_wp03(2T37/2T-97L1) ups 2 @ I VMA (FaNm 245) umee.I�'eooi Calwaim reeuwa. rrcn,-t��rn -96002 O O -40001 -44001 4800+ O -52001 -p -C -5600 p O � -6000 P -6400 -6800 n TZ001 - -76001 -8000 -8400 -8800 1 -92001 I West( -)/East(+) (400 usft/in) 2T-37 Q 122.00usft (Parker 245) 2T-10/2LIULI BAIUGHES .GE. ,, 'Y201hLIIp --2T41/2T4I 2T-12RTd2 -400- -800 er-14W.14 -INC, -1600- _ -2000- ,4:,^lCpi N,1 2400 . -2800 .� 3200.E -96002 O O -40001 -44001 4800+ O -52001 -p -C -5600 p O � -6000 P -6400 -6800 n TZ001 - -76001 -8000 -8400 -8800 1 -92001 I West( -)/East(+) (400 usft/in) 2T-37 Q 122.00usft (Parker 245) 2T-10/2LIULI BAIUGHES .GE. ,, 'Y201hLIIp --2T41/2T4I 2T-12RTd2 -24 U0 -2000 zr-ve �l-10 1401'111 er-14W.14 -24 U0 -2000 Q N O ' N N N � w W � O a o O �p N n. r om Yp vv N r p 'moo Yk - LI? IV o @ V o O M m n iN y m o N O N C of Z m y C Y � c m m Em um n .n � r m- Z Y o m of V 22 (E y Mm (n W Iq N m O O r5o m oa co O y p J J m O E m Ecru mr 3 �ro Q x U of U m s m o. m m N N N M c C y d N Q C M M M arp U Y m O ci Q N O ' N N N � w W � 0 m O �p N n. O� om Yp vv N r p 'moo Yk - LI? o @ V o Q N O G d O L 0 y N N n. r r ao N r p Q Loepp, Victoria T (DOA) From: Ohlinger, James 1 <James.J.Ohlinger@conocophillips.com> Sent: Friday, October 12, 2018 9:41 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL)FW: KRU 2T-37L1-0I(PTD 218-120) Anti -collision 2T-38 is abandoned (sidetracked) 2T -38A is Parallel to our proposed sidetrack — shut in since 2008 Center to Center distance is —475' to the north Passes our risked based scan We'll monitor our positional uncertainty while drilling, but no further action beyond our normal operations will be executed. From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, October 12, 2018 8:57 AM To: Ohlinger, James J <James.J.Ohlinger@conocophill ips.com> Subject: [EXTERNAL]FW: KRU 2T-37L1-01(PTD 218-120) Anti -collision Reference Offset Centre to No -00 Allowable Measured Measured Centro Distance Deviation Site Name '-T- S/27r-3 A Distance (usfl) from Plan Offset Well - Wellbore - Design (usft) (usft) (ustt) (uett) Kupan& 2T Pad \ f� 2T-21. 2T-21 - 2T-21 11,762.01 11,325.00 738-16 210.57 , I 13,260.81 12.650.00 1.229-49 464.19 902.12 F 2T-37 - 2T-37 - 2T-37 10,813.92 1, 30.45 19.80 30.04 F 2T-37-2T-37Ll-2T-37L1_wp03 10,824.66 10,825.00 2.92 23.96 2.70 F 2T -38.2T38 - 2T-38 14,029.22 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, October 12, 2018 8:57 AM To: Ohlinger, James J <James.J.Ohlinger@conocophill ips.com> Subject: [EXTERNAL]FW: KRU 2T-37L1-01(PTD 218-120) Anti -collision Reference Offset Centre to No -00 Allowable Measured Measured Centro Distance Deviation Site Name Depth Depth Distance (usfl) from Plan Offset Well - Wellbore - Design (usft) (usft) (ustt) (uett) Kupan& 2T Pad 2T-21. 2T-21 - 2T-21 11,762.01 11,325.00 738-16 210.57 547.14 F 2T -36 -2T -36.2T-36 13,260.81 12.650.00 1.229-49 464.19 902.12 F 2T-37 - 2T-37 - 2T-37 10,813.92 10.825.00 30.45 19.80 30.04 F 2T-37-2T-37Ll-2T-37L1_wp03 10,824.66 10,825.00 2.92 23.96 2.70 F 2T -38.2T38 - 2T-38 14,029.22 13,100.00 119.56 15.54 108.32 F 2T-38 - 2T -38A - 2T -38A 13,741.47 12,675.00 475.99 20.81 456.10 F From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, October 12, 2018 8:57 AM To: Ohlinger, James J <James.J.Ohlinger@conocophill ips.com> Subject: [EXTERNAL]FW: KRU 2T-37L1-01(PTD 218-120) Anti -collision From: Loepp, Victoria T (DOA) Sent: Friday, October 12, 2018 8:55 AM To: Herring, Keith E (Keith.E.Herring@conocophillips.com) <Keith.E.Herring@conocophillips.com> Subject: KRU 2T-371-1-01(PTD 218-120) Anti -collision Keith, KRU 2T -38/38A fails major risk with KRU 2T-371-1-01. What anti -collision mitigation measures will be in place to allow these wells to be minor risked? Thank, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeoo(rDalaska.cov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without First saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)7931247 or victoria. Loepp@alaska.aov_ TRANSMITTAL LETTER CHECKLIST WELL NAME: A;;&( PTD: Z(O - /� Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: Gc K l* 4'C� POOL: LC 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. i9 -- / API No. (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 ermit). 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 sam les are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, / composite curves for well logs run must be submitted to the AOGCC ✓ within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#:2181200 Company CONOCOPHILLIPS ALASKA, INC Initial Class/Type Well Name: KUPPAR )KBLVS1NI72T--37LI_01 Program DEV _ Well bore seg DEV/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.0300A.A)&ZA-1)) .. NA - .. _ _ _ . . . .. . . . . . . .. 1 Permit fee attached _ _ _ NA - - - - - _ _ _ ...................... . . _ ',2 Lease number appropriate. Yes Surface Location lies within ADL0025569; Top Prod Int & TD lie within ADL0925568.. . '.3 Unique well name and number Yes KUPARUK RIVER,_ KUPARUK RIV OIL .490100 4 Well located in. a. defined pool _ _ _ Yes _ Kuparuk River Oil Pool, governed by Conservation Order No. 432D 5 Well located proper distance from drilling unit. boundary Yes Conservation Order No. 432D has no interwell. spacing. restrictions. Wellbore will be more than 50V 6 Well located proper distance from other wells. _ Yes from an external property line. where. ownership or landownership changes. As proposed, well will....... _ 7 Sufficient acreage available in drilling unit Yes conform to, spacing requirements.. 8 If deviated, is wellbore plat. included _ - _ _ _ _ _ Yes 9 Operator only affected parb.. - - - - - - _ _ _ Yes 10 Operator hasappropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order. _ Yes 12 Permit can be issued without administrative_ approval _ _ _ Yes SFD 10/9/2018 13 Can permit be approved before 15 -day wait _ _ Yes 14 Well located within area and. strata authorized by Injection Order # (put 10# in comments) (For. NA 15 All wells. within 1/4. mite. area of reyiew identified (For service well only) ... . ..... NA ....................... ... 16 Pre -produced injector; duration of pre production less than 3 months (For service well only) _ _ NA 18 Conductor string _provided NA - Conductor set-in KRU 2T-37 _ Engineering 19 Surface casing protects all known USDWs _ _ _ _ _ _ _ _ _ NA. Surface casing set in KRU 2T-37 20 CMT vol adequate to circulate on conductor & surf csg NA... Surface casing set and fully cemented _ 21 CMT vol, adequate to tie-in.long string to.surf csg. NA 22 CMT. will cover all knownproductivehorizons.... _ _ No Productive. interval will be completed with uncemented liner 23 Casing designs adequate for C, T, B & permafrost. _ _ _ - _ Yes 24 Adequate tankage or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ Rig has steel tanks; allwasteto approved disposal well 25 If a. re -drill, has a 10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ NA. 26 Adequate wellbore separation proposed. _ ...... Yes Anti -collision analysis complete; Major risk failures KRU 2T -38/36A Abd/SI 27 If diverter required, does it meet regulations _ _ .... NA Appr Date 28 Drilling fluid program schematic & equip list adequate _ _ _ _ _ _ Yes _ Max formation pressure is 3392 psig(11..3 ppg.EMW); will drill, w/ 8.6. ppg EMW and maintain overbal w/ MPD VTL 10/12/2018 I29 BOPEs, do they meet regulation _ _ _ _ _ _ _ _ _ _ Yes 30 BOPE press rating appropriate; test to (put psig in comments).... _ _ _ Yes MPSP is 2808 psig; will test BOPS to 35Q0 psig 31 Choke manifold complies w/API. RP -53 (May 84) _ _ _ _ _ Yes 32 Work will occur without operation shutdown.. _ ... Yes 33 Is presence of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ H2S measures required_ 34 Mechanical condition of wells within AOR verified (for service well only) .............. NA _ _ . - - - - - - - - - _ -- _35 35 Permitcan be tssued w/o hydrogen- sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No.. _ _ _ Wells on 2T -Pad are KS -bearing, 1-12S measures required. .. _ Geology 36 Data. presented on potential overpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ Maximum potential reservoir pressure is 11.3 ppg. EMW;. expected reservoir pressure is 8.9 ppg EMW....... Appr Date 37 Seismic analysis of shallow gas zones ........ NA Well will be drilled using 8.6 ppg .mud, a coiled -tubing rig, and managed pressure drilling_ SFD 10/9/2018 38 Seabed condition survey (if off -shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ technique to control formation pressures and stabilize shale. sections. NOTE; Chance of 39 Contact name/phone for weekly.progress reports [exploratory only] ........ _ NA _ encountering gas while drilling this, wellbore due to gas. injection performed in this area. Geologic Engineering Public Date: Date Date Commissioner: Co issione . C r tll�j �t
