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218-135
DATA SUBMITTAL COMPLIANCE REPORT 2125/2019 Permit to Drill 2181350 Well Name/No. KUPARUK RIV UNIT 3H-13AL1 917 • Operator CONOCOPHILLIPS ALASKA, INC. MD 10100 TVD 5980 Completion Date 11/20/2018 Completion Status 1 -OIL Current Status 1 -OIL REQUIRED INFORMATION Mud Log No✓ Samples No DATA INFORMATION List of Logs Obtained: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval Type Med/Frmt Number Name Scale Media No Start Stop Log C 30081 Log Header Scans 0 0 ED C 30081 Digital Data ED C 30081 Digital Data ED C 30081 Digital Data ED C 30081 Digital Data ED C 30085 Digital Data ED C 30085 Digital Data ED C 30085 Digital Data ED C 30085 Digital Data Log C 30085 Log Header Scans 0 0 Log C 30086 Log Header Scans 0 0 ED C 30086 Digital Data ED C 30086 Digital Data ED C 30086 Digital Data ED C 30086 Digital Data ED C 30087 Digital Data ED C 30087 Digital Data ED C 30087 Digital Data ED C 30087 Digital Data API No. 50-103-20089-60-00 UIC No Directional Survey Yes (from Master Well Data/Logs) OHI CH Received Comments 2181350 KUPARUK RIV UNIT 3H-13AL1 LOG HEADERS 12/10/2018 Electronic File: 3H-13AL1 EOW - NAD27.pdf 12/10/2018 Electronic File: 3H-13AL1 EOW - NAD27.txt 12/10/2018 Electronic File: 31-1-13AL1 EOW - NAD83.pdf 12/10/2018 Electronic File: 3H-13AL1 EOW - NAD83.txt 12/10/2018 Electronic File: 3H-13AL1 P81 EOW - NAD27.pdf 12/10/2018 Electronic File: 3H-13AL1P81 EOW - NAD27.txt 12/10/2018 Electronic File: 31-1-13AL1PB1 EOW - NAD83.pdf 12/10/2018 Electronic File: 31-1-13AL1PB1 EOW - NAD83.txt 2181350 KUPARUK RIV UNIT 3H-13AL1 PB1 LOG HEADERS 2181350 KUPARUK RIV UNIT 3H-13ALi P132 LOG HEADERS 12/10/2018 Electronic File: 3H-13AL1 PB2 EOW - NAD27.pdf 12/10/2018 Electronic File: 3H-13AL1 PB2 EOW - NAD27.txt 12/10/2018 Electronic File: 3H-13AL1 PB2 EOW - NAD83.pdf 12/10/2018 Electronic File: 3H-13AL1PB2 EOW - NAD83.txt 12/10/2018 Electronic File: 31-1-13ALV33 EOW - NAD27.pdf 12/10/2018 Electronic File: 31-1-13AL1PB3 EOW - NAD27.txt 12/10/2018 Electronic File: 31-1-13AL1PB3 EOW - NAD83.pdf 12/10/2018 Electronic File: 3H-13AL1PB3 EOW - NAD83.txt AOGCC Page l of 6 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181350 Well Name/No. KUPARUK RIV UNIT 31-1-13AL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20089-60-00 MD 10100 Log C ED C ED C ED C ED C ED C I ED C IED C ED C ED C ED C TVD 5980 Completion Date 11/20/2018 30087 Log Header Scans 30110 Digital Data 30110 Digital Data 30110 Digital Data 30110 Digital Data 30110 Digital Data 30110 Digital Data 30110 Digital Data 30110 Digital Data 30110 Digital Data 30110 Digital Data ED C 30110 Digital Data ED C 30110 Digital Data ED C 30110 Digital Data ED C 30110 Digital Data ED C 30110 Digital Data Completion Status 1 -OIL 0 0 7052 10100 ED C 30110 Digital Data ED. C 30110 Digital Data ED C 30110 Digital Data ED C 30110 Digital Data Log C 30110 Log Header Scans 0 0 Log C 30111 Log Header Scans 0 0 ED C 30111 Digital Data 7305 9085 Current Status 1-0I1- UIC No 2181350 KUPARUK RIV UNIT 31-1-13AL1 LOG PB3 HEADERS 12/13/2018 Electronic Data Set, Filename: 31-1-13AL1 GAMMA RES.Ias 12/13/2018 Electronic File: 31-1-13AL1 2MD Final.cgm 12/13/2018 Electronic File: 31-1-13AL1 51VID Final.cgm 12/13/2018 Electronic File: 31-1-13AL1 5TVDSS Final.cgm 12/13/2018 Electronic File: 31-1-13AL1 2MD Final.pdf 12/13/2018 Electronic File: 31-1-13AL1 5MD Final.pdf 12/13/2018 Electronic File: 31-1-13AL1 5TVDSS Final.pdf 12/13/2018 Electronic File: 31-1-13AL1 EOW - NAD27.pdf 12/13/2018 Electronic File: 31-1-13AL1 EOW - NAD27.txt 12/13/2018 Electronic File: 31-1-13AL1 Final Surveys TD 10100 (Confirmed).csv 12/13/2018 Electronic File: 31-1-13AL1 Final Surveys TD 10100 (Confirmed).xlsx 12/13/2018 Electronic File: 31-1-13AL1 Survey Listing.txt 12/13/2018 Electronic File: 31-1-13AL1 Surveys.txt 12/13/2018 Electronic File: 31-1- 13AL 1_25_tapescan_131-11 CTK.txt 12/13/2018 Electronic File: 31-1- 13AL1 _5_tapescan_BH I_CTK.txt 12/13/2018 Electronic File: 31-1-13AL1_output.tap 12/13/2018 Electronic File: 31-1-13AL1 21VID Final.tif 12/13/2018 Electronic File: 31-1-13AL1 5MD Final.tif 12/13/2018 Electronic File: 31-1-13AL1 5TVDSS Final.tif 2181350 KUPARUK RIV UNIT 31-1-13AL1 LOG HEADERS 2181350 KUPARUK RIV UNIT 3H-13AL1 LOG PBIHEADERS 12/13/2018 Electronic Data Set, Filename: 31-1-13AL'IPW GAMMA RES.las AOGCC Page 2 of 6 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181350 Well Name/No. KUPARUK RIV UNIT 3H-13AL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20089-60-00 MD 10100 TVD 5980 ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30111 Digital Data ED C 30112 Digital Data ED C 30112 Digital Data ED C 30112 Digital Data ED C 30112 Digital Data ED C 30112 Digital Data ED C 30112 Digital Data ED C 30112 Digital Data ED C 30112 Digital Data Completion Date 11/20/2018 Completion Status 1-0IL 7003 10535 Current Status 1-0I1- UIC No 12/13/2018 Electronic File: 31-1-13AL1PE1 2MD Final.cgm 12/13/2018 Electronic File: 31-1-13AL1 PB1 5MD Final.ogm 12/13/2018 Electronic File: 31-1-13AL11o61 5TVDSS Final.cgm 12/13/2018 Electronic File: 3H-13AL1PB1 21VID Final.pdf 12/13/2018 Electronic File: 3H-13AL1PB1 5MD Final.pdf 12/13/2018 Electronic File: 3H-13AL1PB1 5TVDSS Final.pdf 12/13/2018 Electronic File: 31-1-13AL1PB1 EOW - NAD27.pdf 12/13/2018 Electronic File: 3H-13AL1P131 EOW - NAD27.txt 12/13/2018 Electronic File: 31-1-13AL1 P131 Final Surveys 9085' TD.csv 12/13/2018 Electronic File: 31-1-13AL1 P61 Final Surveys 9085' TD.xlsx 12/13/2018 Electronic File: 31-1-13AL1PB1 Survey Listing.txt 12/13/2018 Electronic File: 3H-13AL1PB1 Surveys.txt 12/13/2018 Electronic File: 31-1- 13AL1 P131_25_tapescan_BHI_CTK.txt 12/13/2018 Electronic File: 3H- 13AL1 PB1_5_tapescan_BHI_CTK.txt 12/13/2018 Electronic File: 31-1-13AL1PB1_output.tap 12/13/2018 Electronic File: 3H-13AL1PB1 2MD Final.tif 12/13/2018 Electronic File: 31-1-13AL1P131 5MD Final.tif 12/13/2018 Electronic File: 3H-13AL1PB1 5TVDSS Final.tif 12/13/2018 Electronic Data Set, Filename: 3H-13AL1PB2 GAMMA RES.Ias 12/13/2018 Electronic File: 3H-13AL1PB2 2MD Final.cgm 12/13/2018 Electronic File: 31-1-13AL1 PB2 5MD Final.cgm 12/13/2018 Electronic File: 31-1-13AL1 PB2 5TVDSS Final.cgm 12/13/2018 Electronic File: 3H-13AL1 PB2 21VID Final.pdf 12/13/2018 Electronic File: 31-1-13AL1 PB2 51VID Final.pdf 12/13/2018 Electronic File: 31-1-13AL113K 5TVDSS Final.pdf 12/13/2018 Electronic File: 3H-13AL1PB2 EOW - NAD27.pdf AOGCC Page 3 of 6 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181350 Well Name/No. KUPARUK RIV UNIT 3H-13AL7 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20089-60-00 MD 10100 TVD 5980 Completion Date 11/20/2018 Completion Status 1-011- Current Status 1-0I1- UIC No ED C 30112 Digital Data 12/13/2018 Electronic File: 3H-13AL1PB2 EOW - NAD27.txt ED C 30112 Digital Data 12/13/2018 Electronic File: 31-1-13AL1 PB2 Final Surveys 10535.csv ED C 30112 Digital Data 12/13/2018 Electronic File: 3H-13AL1P82 Final Surveys 10535.xlsx ED C 30112 Digital Data 12/13/2018 Electronic File: 3H-13AL1PB2 Survey Listing.txt ED C 30112 Digital Data 12/13/2018 Electronic File: 31-1-13AL1 P132 Surveys.txt ED C 30112 Digital Data 12/13/2018 Electronic File: 31-1- 13AL1 PB2_25_ tapescan_BHI_CTK.txt ED C 30112 Digital Data 12/13/2018 Electronic File: 3H- 13AL1 P132_ 5_ tapescan_BHI_CTK.txt ED C 30112 Digital Data 12/13/2018 Electronic File: 3H-13AL1PB2_0utput.tap ED C 30112 Digital Data 12/13/2018 Electronic File: 3H-13AL1PB2 21VID Final.tif ED C 30112 Digital Data 12/13/2018 Electronic File: 3H-13AL1PB2 5MD Final.tif ED C 30112 Digital Data 12/13/2018 Electronic File: 31-1-13AL1 PB2 5TVDSS Final.tif Log C 30112 Log Header Scans 0 0 2181350 KUPARUK RIV UNIT 3H-13AL1 LOG PB2 HEADERS ED C 30113 Digital Data 7052 8810 12/13/2018 Electronic Data Set, Filename: 3H-13AL1PB3 GAMMA RES.las ED C 30113 Digital Data 12/13/2018 Electronic File: 3H-13AL1PB3 2MD Final.cgm ED C 30113 Digital Data 12/13/2018 Electronic File: 3H-13AL1PB3 51VID Final.cgm ED C 30113 Digital Data 12/13/2018 Electronic File: 31-1-13AL1 P133 5TVDSS Final.cgm ED C 30113 Digital Data 12/13/2018 Electronic File: 31-1-13AL1 PB3 2MD Final.pdf ED C 30113 Digital Data 12/13/2018 Electronic File: 31-1-13AL1 PB3 5MD Final.pdf ED C 30113 Digital Data 12/13/2018 Electronic File: 3H-13AL1PB3 5TVDSS Final.pdf ED C 30113 Digital Data 12/13/2018 Electronic File: 3H-13AL1PB3 EOW - NAD27.pdf ED C 30113 Digital Data 12/13/2018 Electronic File: 3H-13AL1PB3 EOW - NAD27.txt ED C 30113 Digital Data 12/13/2018 Electronic File: 3H-13AL1PB3 Survey Listing.txt ED C 30113 Digital Data 12/13/2018 Electronic File: 31-1-13AL1 PB3 Surveys.txt ED C 30113 Digital Data 12/13/2018 Electronic File: 3H-13AL1 P133_Unconfirmed TD 8810.csv AOGCC Page 4 of 6 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181350 Well Name/No. KUPARUK RIV UNIT 3H-13AL1 MD 10100 TVD 5980 Completion Date 11/20/2018 ED C 30113 Digital Data ED C 30113 Digital Data ED C 30113 Digital Data ED C 30113 Digital Data ED C 30113 Digital Data ED C 30113 Digital Data ED C 30113 Digital Data Log C 30113 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report DY Production Test Infortnatiop ry NA Geologic Markers/Tops Y Interval Start Stop Operator CONOCOPHILLIPS ALASKA, INC. Completion Status 1-011- w -OIL 0 19 Sent Received API No. 50-103-20089-60-00 Current Status 1-0I1- UIC No 12/13/2018 Electronic File: 3H-13AL1PB3 Unconfirmed TO 8810.x1sx 12/13/2018 Electronic File: 31-1- 13AL1 PB3_25_tapescan_BHI_CTK.txt 12/13/2018 Electronic File: 31-1- 13AL1 PB3_5_tapescan_BHI_CTK.txt 12/13/2018 Electronic File: 3H-13AL1PB3_output.tap 12/13/2018 Electronic File: 3H-13AL1PB3 2MD FinaLtif 12/13/2018 Electronic File: 3H-13AL1PB3 5MD Final.tif 1211312018 Electronic File: 31-1-13AL1 P133 5TVDSS Final.tif 2181350 KUPARUK RIV UNIT 3H-13AL1 LOG P83HEADERS Sample Set Number Comments Directional / Inclination Data 19 Mud Logs, Image Files, Digital Data Y / ® Core Chips y' Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files (9 Core Photographs Y / Daily Operations Summary O Cuttings Samples Y C9 Laboratory Analyses Y / COMPLIANCE HISTORY Completion Date: 11/20/2018 Release Date: 10/23/2018 Description Date Comments Comments: AOGCC Page 5 of 6 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181350 Well Name/No. KUPARUK RIV UNIT 3H-13AL1 MD 10100 TVD 5980 Completion Date 11/20/2018 Compliance Reviewed8y: Y v \ Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20089-60-00 Completion Status 1-0IL Current Status 1-0IL UIC No Date: 3l 1 8 f I AOGCC Page 6 of 6 Monday, February 25, 2019 BAN( Co e- � �� nF xkun�s ER rrePRINT DISTRIBUTION LIST UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3H-13ALIPB3 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider( akerhughes.com STATUS Rev COMPANY ?1813 30113 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (INNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE November 19, 2018 TODAYS DATE March 8. 2019 Revision Replacement: CD/HCP Details: Fixed API Number Rev. Requested by: --- ADDRESS (FEDEK WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V t RP North Slope. — — _ _ LOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage. Alaska 99508 FIELD l FINAL CD/DVDFINAL 0 0 PRELIM LOGS (las, tills, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTSF Ur PRIN # OF COPIES # OF COPIES I# OF COPIES 1� is lu IG 4 IG 2 ConocoPhillips Alaska Inc. 0 Q 0 0 0 Attn: Ricky Elgarico AFO708 RECEIVED 700 G Street Anchorage, AK 99510 MAR 12 2019 3 Exxon Mobil, Alaska 0 QLIC 0 0 Attu: Lynda M. Vasiodl and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4State of Alaska -AOGCC 0 i i 0 Q .Attn: Natural Resources Technician II 333 W. 7th Ave, Suite 100 L Re 5vt� mf55r�r, Anchorage, Alaska 99501 1 5 DNR -Division ofOil&Gas *** Q 1 Q 0 0 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 **` Stamp "confidential" on all material deliver to DNR 6 RP Exploration (Alaska) Inc. Q 1 0 0 0 0 Petrotechnical Data Center, IR2-1 900 F Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 p BANSR "I V -e c,� -d API � s �ES PRINT DISTRIBUTION LIST a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3H-13AL1PB2 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. RiderCa)bakerhughes cam STATUS Revl COMPANY 21 81 35 30111 ie sign and return one copy of this transmittal form to: DcoPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. forage. Alaska 99510 LOG TYPE GR - RES LOG DATE November 19, 2018 TODAYS DATE March 8, 2019 Revision Replacement: CD/HCP Details: ADDRESS (FEDEX WILL 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. Menson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Ann: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExsonMobil, Alaska AM: Lynda M. Vaskell andtor Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska -AOGCC Attn: Natural Resources Technician II 333 W. 7th Ave, Suite 100 'Anchorage. Alaska 99501 Fixed API Number Requested by: -- FIELD I FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, I SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES 4 lu 4 4 4 4 RECEIVED �e5vth�Ni55(0.1 5 DNR - Division of0il &Gas *** 0 0 1 0 Ann: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential' on all material deliver to DNR 6 BP Exploration (Alaska) Inc. 0 0 0 0 0 Petrotechnical Data Center, IR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 BA ER cd Iv-,*c4cd ,A -PI r'' ^r° w -s FUGHES PRINT DISTRIBUTION LIST a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3H-13ALIPBI FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Ridergbakerhughes com 218135 3011 1 se sign and return one copy of this transmittal form to: 3coPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. forage, Alaska 99510 LOG TYPE GR - RES LOG DATE November 19, 2018 TODAYS DATE March & 2019 Revision STATUS Rev 1 Replacement: CD/HCP Details: Fixed API Number Rev. Requested by: COMPANY ADDRESS (FEDEX V/ILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V f BP North Slope. FOA, PBOC. PRB.20 (ONicc 109) D&GWO 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 ExxonMobil, 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 Il 333 W. 7th Ave, Suite 100 ,Anchorage, Alaska 99501 51DNR-Division ofOil&Gas *'* Attn: Resource Evaluation 550 West 7th Avenue. Suite 1100 Anchorage, Alasin 99501 *** Stamp "confidential' on all material deliver I 6 RP Exploration (Alaska) Inc. Pctrotechnical Data Center, IR2-1 900 E Benson Blvd Anchorage, Alasla 99508 TOTALS FOR THIS PAGE: FIELD I FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, I SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES I# OF COPIES 1# OF COPIES 4 4 4 lu is a RECENED E AOGCC 0 1 1 0 0 /Cn es61 "J YHtii/ J. -x. 0 0 0 0 0 0 1 2 0 0 STATE OF ALASKA Al ASKA 1711 ANn GAR rONSFRVATInN CnMMIRSInN WELL COMPLETION OR RECOMPLETION REPORT AND LOG Ia. Well Status: oil [2] Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class. 20 025.105 20a 025.110 Development Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: ConocoPhillips Alaska, Inc. Abend.: 11/20/2018 218-135 • 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 9951 M360 10/27/2018 50-103-20089-60-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 1182' FNL, 281' FWL, Sec 12, T12N, R8E, UM ' 11/15/2018 KRU 3H-13AL1/ 3H-13AL1P81/ r 3H-13AL1P62/3H-13AL1PB3 Top of Productive Interval: 9. Ref Elevations: KB: 71' 17. Field / Pool(s): 3447' FNL, 528' FEL, Sec 2, T12N, R8E, UM • GL: 34 BF: Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/iVD: 18. Property Designation: 398' FNL, 820' FEL, Sec 11, T12N, R8E, UM r NIA ADL25531 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MDfFVD: 19. DNR Approval Number: Surface: x- 498655 y- 6000475 Zone- 4 10100 MD/ 5980 TVD LONS 84-134 & LONS 84-149 TPI: x- 497844 y- 6003491 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MDRVD: Total Depth: x- 497553 y- 6001259 Zone- 4 N/A 1628 MD/ 1628 TVD 5. Directional or Inclination Survey: Yes ❑ (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MDRVD: Submit electronic and printed information per 20 AAC 25.050 NIA (ft MSL) I 7315' MD/ 5973' TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dometer, 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 WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16' 62.5 H-40 36' 110' 36' 110' 24" 245 sx AS 1 9-5/8" 36 J-55 35' 3072' 35' 2929' 12.25" 1300 sx ASIII, 400 sx G, 70 sx ASI T' 26 J-55 33' 5970' 33' 5173' 8.5" 300sx G, 175 sx ASI 3-1/2" 9.3 L-80 5808' 7755' 5808' 5983' 6.125" 311 sxG 2-3/8" 4.6 L-80 7462' 10100' 5992' 5980' 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) IPACKERSET (MD7fVD) Size and Number; Date Perfd): Slotted Liner 7462'-10100' MD and 5992'-5980' TVD I(Its IAB 3-1/2" 5836' 5808' MD/ 5050' TVD • • COMPLETION 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� DATE "I Zo-h Per 20 AAC 25.283 (i)(2) attach electronic and printed information VERIFIED DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 12/1/2016 Gas Lift Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 12/3/2018 14 Test Period 1 924 588 734 176 637 Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity -API (torr): Press. 238 1053 24 -Hour Rate 1584 1008 1258 23.6 Form 10-407 Revised 5/2017 (/"f'L 217117 CONTINUED ON PAGE 2 13pMS ��� C,`� L ' 2u,8 Submit ORIGINIAL onl *&,0.2/:;g-fti 10 yl�l�9 G 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑Z If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1628 1628 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7315 5972 . information, including reports, per 20 AAC 25.071. Formation @ TPI - Kuparuk A-1 TD 3H-13AL1 10100 5980 3H-13ALiPB1 9085 5956 3H-13AL1PB2 10535 6028 3H-13AL1PB3 8810 5981 Formation at total depth: Ku aruk A 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, paleontological report, production or well test results, per 20 AAC 25.070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: Keith Herrin Authorized Title: Staff CTD Engineer Contact Email: keith.e.herrin ftco .com Authorized Contact Phone: 2634321 Signature: Date:f/or 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 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this 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 3H -13A Final CTD St shoe at 110' MD at 3072' MD Thematic r r- 3-1/2" Camco DS -nipple at 502' MD (2.813" min ID) L3-1/2'9.3# L-80 EUE Brd Tubing to surface 3-1/2" Camco KBUG gas lift mandrels 2720'. 4118', 8 5D77' MO 3-1/2" Camco MMM gas lift mandrel 5757' MD 3-1/2" Camco D -nipple at 5803' MD (2.750" min ID) Baker 3-1/2" GBH -22 seal assembly at 5812' MD (3" ID) Liner too F5970' 6#, J-55 Baker 5'x 7" ZXP liner top packer at 5808' MD mcked al MD (1997)IL 3H-13AL1-031 = 8243' MD 2-318" slotted linerwl deployeer4 sleeve TOL = 7258'M BOL = 7944' MO KOP 817315' MD C-seDtl perfs Baker 3-112" XL Monobora ✓' 3H-13AL1-02 TD =9473' MD 7229'-7249' MD whipstock 2-3/8" sloIted liner wl aluminum billet TOIL =7720'MD. BOL =947TMD TightsPol in 3-112" liner 7268'-7313' MID ; ' __-_ _ _ - • --' "-' ' "- - '- -" 3H-13AL1 TD - 10100' MD 2OL slotted O. O anchored aluminum billet BKOP aker 7349 , r✓ ✓ OL=7462'MD, BOL=101DD'MD Baker 3-1/2" XL MonoDOre 3H-13AL7P83 T0=88111'MD whipstock ,:. ___ __________ "' nchored billet = 7999'Y MD p3TH-1=7357'tELMD 10699'MD OA=7357' BHA stuck at INa A -sand arts A( P 268.39') 7256'-7308' MD - 2' 'Co COAetl BHA (DAL = tubing (DAL = 3031) T356'-7366'101) 7372-7380'1011)_____________-_____-__________. - 3H-03AL1P82 TD-10535'MD 2.318" slotted liner wt anchored aluminum billet TOL = 7730' MD, BOL = 10347 MD 3H-13AL1P81 TD=9085' MD 3-1/2", 9.3N, L-80 liner Anchoretl billet= 7745' MD 5808'-7755' MD -- Operations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SWM Dept SWrt Time EM Time Dur (hr) Phase op Code Acomty Code Time P -T -x Operation (ORB) End Dept (WB) 10/23/2018 10/23/2018 4.00 MIRU MOVE RURD P Work RD check list, prep injector & 0.0 0.0 09:30 13:30 reel for move, route inspection, coordinate pre -rig work 10/23/2018 10/23/2018 6.50 MIRU MOVE RURD P Continue RD checklist, trucks to arrive 0.0 0.0 13:30 20:00 -19:00 hrs, continued coordiantion w/ pre -rig OPS, DTH notified to break down tiger -tank line, disconnet hi -line power 10/23/2018 10/23/2018 0.40 MIRU MOVE RURD P Peak sows on location spot trucks, 0.0 0.0 20:00 20:24 PJSM 10/23/2018 10/23/2018 1.30 MIRU MOVE RURD P Jack service unit, attach sow and 0.0 0.0 20:24 21:42 move service unit to beginning of access road. 10 minutes to pickup service side mats, wind increasing sharply. Some issues with hydraulic systems at the outset, - 10-15 min troubleshoot. 10/23/2018 10/23/2018 0.40 MIRU MOVE RURD P Jack sub, attach sow and stage 0.0 0.0 21:42 22:06 behind service unit. Pull cellar sills, plywood, and herculite. Pad inspection with pad operator / company rep. Sign off on environmental form. 10/23/2018 10/23/2018 0.50 MIRU MOVE RURD P Drop sows, attach jeeps, reattach 22:06 22:36 tandem sows to service and sub. Performed final walk around. Notify security of eminent move. 10/23/2018 10/23/2018 0.60 MIRU MOVE MOB P Roll off pad @ 22:38 toward 3H-13 - 0.0 0.0 22:36 23:12 17.5 miles 10/23/2018 10/23/2018 0.30 MIRU MOVE MOB P 1.8 miles, at 2G access to spine road, 0.0 0.0 23:12 23:30 make sharp, off camber tum with service and sub & continue toward 3H. 10/23/2018 10/24/2018 0.50 MIRU MOVE MOB P Pass through CPF2, continue on 0.0 0.0 23:30 00:00 1 toward 3H-14. 10/24/2018 10/24/2018 5.30 MIRU MOVE MOB P Complete move from 2G -Pad to 3H- 0.0 0.0 00:00 05:18 Pad 10/24/2018 10/24/2018 1.00 MIRU MOVE MOB P Crew, change, drop jeeps, lay herculte, 0.0 0.0 05:18 06:18 pull tree cap 10/24/2018 10/24/2018 3.70 MIRU MOVE MOB P Begin spotting sub, remove platform 0.0 06:18 10:00 hand rails & raise BOP's to clear tree. Thermal siphon blocking dg landing, call out facilities w/crane, cut down thermal siphon, continue spatting sub, raise BOP's to max height to clear tree flange w/ BOP studs when selling down off jack. Spotted mats under sub 10/24/2018 10/24/2018 1.00 MIRU MOVE MOB P Spotted pits & laid mats, spotted TT 10:00 11:00 150' from dg 10/24/2018 10/24/2018 2.00 MIRU MOVE RURD P Begin RU check list, safe out walk 0.0 0.0 11:00 13:00 ways & landing, connect PUTZ, unlock reel & injector, begin NU BOPE Shop & 1/2 -Way House arrive on pad & spotted 10/24/2018 10/24/2018 1.50 MIRU WHDBOP NUND P Continue RU checklist, complete NU 0.0 0.0 13:00 14:30 BOPE, MU TT hard-line Rig Accept: 10/24 @ 14:30 hrs 10/24/2018 10/24/2018 2.00 MIRU WHDBOP RURD P Complte RU checklist 0.0 0.0 14:30 16:30 Page 1139 Report Printed: 11/20/2018 Operations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tme End Time Dur(hr) Phase Op Code AMAy Cotle Time P -T -X 0 eration p DOPM 3tart13) (111<13) End Depth (WS) 10/24/2018 10/24/2018 2.00 MIRU WHDBOP BOPE P Fluid pack, perform shell test, leak at 0.0 0.0 16:30 18:30 wing valve flange, valve crew attempting to solve issue, test gas alarms. S/I swab #1 in an attempt to bypass and move forward with BOP test, will attempt to blind while we cut coil. Crew change. Leek at bleeder on test, panel, repair. 10/24/2018 10/24/2018 3.50 MIRU WHDBOP BOPE P Re -attempt shell test, leak at bleeder 0.0 0.0 18:30 22:00 on the night cap, repair. Pressure up, leak at wing valve bonnet post valve crew tightening. Shut Swab 1 and attempt to move forward, Swab one leaking past, bleeding out bonnet on wing valve. Vac stack, pull wing valve, blind flow block, fluid pack. 10/24/2018 10/25/2018 2.00 MIRU WHDBOP BOPE P Shell test - good. Test BOPE's, 0.0 0.0 22:00 00:00 250/4900 psi 2500 psi annular, (witnessed by Lou Laubenstein of the AOGCC) -Start BOP test @ 22:00 Valve crew returned and grease locked swab #1 after test #1 --10 min Q startof test #4 pressures dropping fast, -re-grease stack -11:30 10/25/2018 10/25/2018 4.70 MIRU WHDBOP BOPE P Complete -re -grease stack, B1 0.0 0.0 00:00 04:42 Fail/Pass on re -grease. - 52 minutes total for Test #4 Had to exercise the annular a few time to get it to hold. Completed draw down. 10/25/2018 10/25/2018 1.30 MIRU WHDBOP BOPE P Clear floor, test inner reel iron 0.0 0.0 04:42 06:00 10/25/2018 10/25/2018 1.50 SLOT WHDBOP PRTS P PT PDL's & tiger tank line, clear floor, 0.0 0.0 06:00 07:30 slide in cart '•`BOP Test 9.5 him 10/25/2018 10/25/2018 1.00 SLOT WELLPR CIRC P PJSM, remove UQC, cut & seal a -line, 0.0 0.0 07:30 08:30 stab on, reverse circulate, up to 3.8 bpm, pop off 10/25/2018 10/25/2018 1.90 SLOT WELLPR CTOP P RU hydraulic cutter, cut off CTC, cut 0.0 0.0 06:30 10:24 500' of pipe, found a -line at 12', tested e -line 10/25/2016 10/25/2018 1.80 SLOT WELLPR CTOP P Ream coil, instal CTC, pull test to 0.0 0.0 10:24 12:12 25K, head a -line, inistall UQC, PT to 4200 psi 10/25/2018 10/25/2018 2.60 SLOT WELLPR CIRC P MU nozzle, stab on, circulate 1 coil 0.0 0.0 12:12 14:48 volume forward @ 2 bpm, begin PU tools, put mill & motor in hole, add 1' riser to stack for spacing out tools 10/25/2018 10/25/2018 0.60 SLOT WELLPR CIRC P Clear all SIMOPS around TT, bleed IA 0.0 0.0 14:48 15:24 down to 500 psi, climbs back to 950 psi, bleed OA down to 679 psi 10/25/2018 10/25/2018 1.60 SLOT WELLPR PULD P PJSM, PU/PD BHA#1 Milling 0.0 51.0 15:24 17:00 Assemlby (2.72" stabalizer, BOT straight motor, D331 ridge -set mill), SSV not fully open, resolve Mill 2.79" no go 10/25/2018 10125/2018 1.20 SLOT WELLPR TRIP P RN w/ BHA#1, EDC open, Getting 51.0 4,990.0 17:00 18:12 1 some gas back at surface. 10/25/2018 10/25/2018 0.20 SLOT WELLPR DLOG P Tie into unique peak above K1 for + 1' 4,990.0 5,014.0 18:12 18:24 1 correction Page 2139 ReportPrinted: 1112 012 01 8 Operations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Stent Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Opereeon (WD) End Depth (eKa) 10/2512018 10/2512018 0.10 SLOT WELLPR TRIP P Continue to RIH. 5,014.0 5,206.0 18:24 18:30 10/25/2018 10/2512018 0.10 SLOT WELLPR DLOG P Logging again to appease the Geo. no 5,206.0 5,245.0 18:30 18:36 correction. 10/25/2018 10/25/2018 1.50 SLOT WELLPR DISP P Continue in hole, slight CT Wt bottle, 5,245.0 5,777.0 18:36 20:06 @ 5803', RIH to 5815' sal down, 4 k WOB. PU 34 k lbs. PUH slowly, ramp up rate from 0.9 to 1.75 bpm. Current losses 1.25 bpm to the formation against an open choke. Turn coil and well over to milling fluid. 10/25/2018 10/25/2018 1.00 SLOT WELLPR MILL P Close EDC, PU Wt 35 k bs, ramp 5,777.0 5,794.0 20:06 21:06 pump to milling rate. CT 3014 psi @ 1.80 bpm in, 1.13 bpm out, free spin diff 427 psi, WH 1 psi, IA 922 psi, OA 770 psi. CT Wt 17 k lbs, RIH, clean @ 5803' no motor work or WOB. Stall @ 5815', PU 34 k Ibs, mill through obstruction to 5825'. Pick up through area, clea, no motor work 10/25/2018 10/2512018 0.50 SLOT WELLPR MILL P Drift with pumps off 5,794.0 7,037.0 21:06 21:36 10/25/2018 10/25/2018 0.40 SLOT WELLPR DLOG P Log the K1 for -10' correction. 7,037.0 7,104.0 21:36 22:00 10/25/2018 10/25/2018 0.20 SLOT WELLPR MILL P Continue to RIH dry, set down @ 7,104.0 7,263.8 22:00 22:12 7263.8', WOB 1.6, PU Wt 40 k lbs. " Bleed IA to 775 psi - gas 10/25/2018 10/25/2018 0.60 SLOT WELLPR MILL P Milling tubing issue @ 7263.8' 7,263.8 7,379.0 22:12 22:48 CT 2961 psi @ 1.75 bpm in, 1.10 bpm out, free spin 394 psi, IA 776 psi OA 787 psi, WH 1 psi CT Wt 19 k lbs, Mill through easily, PU, clean. Continue to RIH 10/25/2018 10/25/2018 0.40 SLOT WELLPR MILL P Set down @ 7379', PU 40 k lbs, RBIH, 7,379.0 7,400.0 2248 23:12 saw nothing tis time, mill to 7,400' - clean 10/25/2018 10/25/2018 0.20 SLOT WELLPR DLOG P PUH Wt 38 k lbs, PUH to 7082' and tie 7,400.0 7,099.0 23:12 23:24 into the K1 for a +1' correction 10/25/2018 10/26/2018 0.60 SLOT WELLPR DLOG P PUH to 5775' bit depth, logg CCL to 7,099.0 7,400.0 23:24 00:00 below planned WS set depth. 10/26/2018 10/2612018 1.50 SLOT WELLPR DLOG P Continue to log CCL to below planned 7,099.0 7,400.0 00:00 01:30 WS set depth. Time out 5x5 sweeps 10/26/2018 10/26/2018 1.60 SLOT WELLPR TRIP P Park, open EDC, PU Wt 38 k lbs, 7,400.0 45.0 01:30 03:06 chase sweeps to bit then POOH. 10/26/2018 10/26/2018 1.40 SLOT WELLPR PULD P Bump up, bleed off pumps, open up at 45.0 0.0 03:06 04:30 the stack, flood up, flowchec observed flow. Tag up, space out, PUD BHA#1 10126/2018 10/26/2018 1.70 PROD1 RPEOPT PULD P PU & PD BHA#2, 3.5 " monobore XL 0.0 73.0 04:30 06:12 whipstock, mill came out 2.79" no-go 10/26/2018 10/26/2018 1.40 PROD1 RPEOPT TRIP P RIH w/ BHA #2, EDC open 73.0 7,090.0 06:12 07:36 10/26/2018 1012612018 0.20 PRODt RPEOPT DLOG P Log K1 for -9' correction, PUW = 34K 7,090.0 7,130.0 07:36 07:48 10/26/2018 10/26/2018 0.40 PROD1 RPEOPT TRIP P Continue RIH, arrive at setting depth, 7,130.0 7,350.5 07:48 08:12 Gose EDC, PUW = 35K, bring up pumps, sheard off WS @ 3700 psi, set down 4K, TOWS -7340', oriented 30" ROHS, set down 5K, good, PUW = 36K Page 3139 ReportPrinted: 11/20120181 Operations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start DepN Start Time End Time Dur (ho Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (WB) 10/26/2018 10/26/2018 1.10 PRODt RPEQPT CIRC P Open EDC, pump 44 bbl 113K _SRV 7,350.5 7,342.0 08:12 09:18 pill, w/ 44 bbl out bit, bullhead 30 bbl into perfs, bleeding down IA & OA 10/26/2018 10/26/2018 1.70 PROD1 RPEQPT TRIP P POOH, park at 535', flow -check well, 7,342.0 73.0 09:18 11:00 have flow, swap tools, pre -load PDL (Unusual WOB values from DPS when POOH), PJSM 10/26/2018 10/26/2018 1.00 PROD1 RPEQPT PULD P PUD BHA#2 73.0 0.0 11:00 12:00 10/26/2018 10/26/2018 0.70 PROD1 WHPST PULD P PD BHA#3 Window Assembly (0.6* 0.0 74.0 12:00 12:42 AKO motor, 2.80 string reamer, 2.80" window mill), 10/26/2018 10/26/2018 0.80 PROD1 WHPST RGRP P Allow Peter Obden time to adjust PLC 74.0 74.0 12:42 13:30 software on injlreel (Rig Service) 10/26/2018 10/26/2018 0.80 PRODt WHPST PULD P Complete PD BHA #3, slide in car[, 74.0 74.0 13:30 14:18 changeout pack -offs, MU to coil, tag up, set counters 10/26/2018 10/26/2016 1.30 PROD1 WHPST TRIP P RIH w/BHA #3 74.0 7,105.0 14:18 15:36 10/26/2018 10126/2018 0.10 PROD1 WHPST OLOG P Log K1 for-9'correction, close EDC, 7,105.0 7,129.0 15:36 15:42 PUW = 36K 10/26/2018 10/26/2018 0.30 PROD1 WHPST TRIP P Continue RIH, dry tag TOWS at 7,129.0 7,341.5 15:42 16:00 7342.2', PUW = 37K, tag pumping at 7341.5' 10/26/2018 1012612018 1.00 PROD1 WHPST WPST P Milling window, 1.8 bpm, FS = 455 psi, 7,341.5 7,342.5 16:00 17:00 CWT = 18K, WOB = 1.3K, circ = 3335 psi, WHIP = 0 psi, losses -10 bph 10/26/2018 1012612018 3.00 PROD1 WHPST WPST P Milling window 1 ft/hr, 7,342.5 7,346.5 17:00 20:00 CT 3345 psi, 1.83 bpm in, 1.72 bpm out, FS = 455 psi, WH 9, IA 731 psi, OA 822 psi CWT = 13K, WOB = 2.3, WOB fell off sharply from 7345.5' with increase in moto work Losses 6 bph 10/26/2018 10/26/2018 3.40 PROD1 WHPST WPST P CT 3387 psi, 1.83 bpm in, 1.73 bpm 7,346.5 7350.5 20:00 23:24 out, FS = 455 psi, WH 9, IA 735 psi, OA871 psi CWT = 15K, WOB = 0.75, Estimate bottom of window 7347' Losses 6 bph 10/2612018 10/27/2018 0.60 PROW WHPST WPST P Start drilling open hole 7,350.5 7,357.4 23:24 00:00 CT 3546 psi, 1.83 bpm in, 1.73 bpm out, FS = 455 psi, WH 9, IA 738 psi, OA 900 psi CWT = 15K, WOB = 0.75, Losses 6 bph 10/27/2018 1012712018 0.60 PROD1 WHPST WPST P Drill rat hole @8-15 ft/hr. 7,3574 7,362.0 00:00 00:36 Losses 3 bph Bleed OA from 900 psi to 627 psi Bleed IA from 740 psi to 680 ps 10/27/2018 10/27/2018 1.80 PROD1 WHPST WPST P Performed reaming passes, as milled 7,362.0 7,362.0 00:36 02:24 30 'ROHS, HS, 60, and 210 " ROHS. Small, diminishing, spike in motor work @ -7342' on the first 4 passes. -515 Ib WOB tug at 7345' on up pass at 210 *ROHS. Dry drift - clean, tag rat hole bottom Losses 3 bph Page 4/39 ReportPrinted: 1112012018 Operations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our (m) Phase Op Code AC Ity Code Time P -T -X Operation (R(B) End Depth (ftK6) 10/27/2018 10/27/2018 0.40 PROD1 WHPST DISP P PU Wt 38k PUH, park, open EDC, 7,362.0 7,287.0 02:24 02:48 pump 10 bb! sweep, chase with new mud @ 2.20 bpm in, 2.06 bpm out, open choke, WH 16 psi. displace sweep to wellbore. 10/27/2018 10/27/2018 1.30 PROD1 WHPST DISP P POOH chasing sweep to surface while 7,362.0 60.0 02:48 04:06 displacing wellbore to new mud - System #1 Choke acting up, most likely window cuttings. 10/27/2018 10/27/2018 1.30 PRODi WHPST PULD P PJSM, Bump up, space out, PUD & 60.0 0.0 04:06 05:24 LD BHA#3, window milling assembly. 10/27/2018 10/27/2018 0.70 PRODt DRILL CIRC P Jet stack 0.0 0.6- 05:24 06:06 10/27/2018 10/27/2018 3.10 FROM DRILL PULD T PU & PD BHA #4, AL1 build/turn 0.0 0.0 06:06 09:12 drilling assembly (2.5 *AK motor with RB Baker bit), check pack offs Hung up high -bend motor working through stack & past swab/master, work to free BHA, pull back up into PDL, pop off lubricator, re -grease motor, index bit to correct orientation, pour 5 gal LVT down stack, complete PD 10/27/2016 10/27/2018 1.50 FROM DRILL TRIP P RIH w/ BHA #4 0.0 7,090.0 09:12 10:42 10/27/2018 10/27/2018 0.10 FROM DRILL DLOG P Log K1 for -8.5' correction 7,090.0 7,108.0 10:42 10:48 10/27/2018 10/27/2018 0.60 PROD1 DRILL TRIP P Continue RIH, Gose EDC, PUW = 7,108.0 7,362.0 10:48 11:24 37K, pull into cased hole to trouble- shoot DD's HSTF values, RBIH 10/27/2018 10/27/2018 1.60 PROM DRILL DRLG P Drilling, 1.8 bpm in, 1.66 bpm out, FS 7,362.0 7,512.0 11:24 1300 = 550 psi, CWl = 15.4K, WOB = 2.4K, circ = 3281 psi, BHP = 3469 psi, WHP = 160 psi, bump up from 11.2 ppg to 11.3 ppg, losses healing, returns = 95%, avg ROP = 93 fph .• RA tag = 7347', TOWS = 7340', BOW = 7347' 10/27/2018 10/27/2018 3.10 FROM DRILL DRLG P Drilling, 1.8 bpm in, 1.7 bpm out, 11.4 7,512.0 7,670.0 13:00 16:06 ppg at window, CWT = 11.8K, WOB = 1.8K, BHP = 3581 psi, circ = 3378 psi EOB called at 7670' 10/27/2018 10/27/2018 0.50 FROM DRILL DLOG P Log K1 for +1'correction, confirm RA 7,670.0 7,370.0 16:06 16:36 at 7347' 10/27/2018 10/27/2018 1.30 PRODt DRILL TRIP P POOH, EDC open 7,370.0 72.0 16:36 17:54 10/27/2018 10/27/2018 1.30 FROM DRILL PULD P Bump up, Space out, Crew change, 72.0 0.0 17:54 19:12 PUD BHA #4, AL1 build/turn drilling assembly. 10/27/2018 10/27/2018 1.00 PROD1 DRILL PULD P PU & PD BHA#5, AL1 lateral drilling 0.0 65.9 19:12 20:12 assembly, 0.5° AKO W HYC A2 RR bit, Check 7 replace pack offs. Bump up, set counters and away we go! 10/27/2018 10/27/2018 1.40 PROD1 DRILL TRIP P RIH, Park @ 500' and shallow test 65.9 7,090-0- 20:12 21:36 agitator,grab screen shots. BPM Diff psi Frequency Hz 1.0 380 20.4 1.5 800 15.0 1.8 1244 1244 Page 5/39 ReportPrinted: 1112 012 01 8 Uperations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth start Time EM Time Dur (hr) Phase Op Code AchAy Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/27/2018 10/27/2018 0.20 PROD1 DRILL DLOG P Tie into the K1 for a -9.5' correction. 7,090.0 7,114.5 21:36 21:48 10/27/2018 10/27/2018 0.30 PROD1 DRILL TRIP P PU Wt 35 k lbs, continue to RIH. 7,114.5 7,670.0 21:48 22:06 Widow & build clean. 10/27/2018 10/28/2018 1.90 PROD1 DRILL DRLG P CT 4183 psi @ 1.84 bpm in, 1.70 bpm 7,670.0 7,890.0 2206 00:00 out, Free spin diff 1470 psi, annular 3644 psi, WH 194 psi, IA684 psi, OA 666 psi. Mud conditioned down quickly, picked up to reacquire numbers CT 4017 psi @ 1.83 bpm in, 1.73 bpm out, free spin 1113 psi. CT Wt 11 k Ib, WOB 2.2 k lbs, ROP 100 ft/hr. 7920' PU Wt 39 k lbs, pump 5x5 low/high sweep Average ROP 115 f rnr 10/28/2018 10/28/2018 1.40 PROD1 DRILL DRLG P CT 4183 psi @ 1.84 bpm in, 1.70 bpm 7,890.0 8,070.0 00:00 01:24 out, Free spin diff 1470 psi, annular 3644 psi, WH 194 psi, IA684 psi, OA 666 psi. Mud conditioned down quickly, picked up to reaquire numbers CT 4017 psi @ 1.83 bpm in, 1.73 bpm out, free spin 1113 psi. CT Wt 11 k Ib, WOB 2.2 k lbs, ROP 100 ft/hr. 7920' PU W139 k lbs, pump 5x5 low/high sweep Average ROP 128 R/hr 10/28/2018 10/28/2018 0.20 PROD1 DRILL WPRT P PU W139 k lbs 8,070.0 7,673.0 01:24 01:36 400'wiper #1 10/28/2018 10/28/2018 0.20 PROD1 DRILL WPRT P RBIH 7,673.0 8,070.0 01:36 01:48 RIH Wt 16klbs 10/28/2018 10/28/2018 0.70 PROD1 DRILL DRLG P CT 4252 psi @ 1.83 bpm in, 1.73 bpm 8,070.0 8,235.0 01:48 02:30 out, Free spin diff 1261 psi, annular 3684 psi, WH 202 psi, IA691 psi, OA 724 psi. CT Wt 5.6 k Ib, WOB 2.7 k lbs, ROP 245 ftlhr. Average ROP 235 fl/hr 10/28/2018 10/28/2018 2.10 PRODi DRILL DRLG P Hit something hard 8235', PU and 8,235.0 8,425.0 02:30 04:36 restart, PU Wt 42 k lbs CT 4563 psi @ 1.83 bpm in, 1.74 bpm out, annular 3680 psi, CT Wt 5.8 k Ib, WOB 2.5 k lbs, ROP 16 -200 ft/hr Drilled through@ 8241'took a little influx, pinched in choke to 11.8 at the window. 1.83 bpm in , 1.72 bpm out Average ROP 90 ft/hr 10/28/2018 10/28/2018 0.20 PROD1 DRILL WPRT P PU Wt 41 k Ibis 8,425.0 7,680.0 04:36 04:48 745'wiper#2 10/28/2018 10/28/2018 0.20 PROD1 DRILL WPRT P RBIH 7,680.0 8,425.0 04:48 05:00 RIH Wt 16 k lbs 10/28/2018 10/28/2018 1.00 PROD1 DRILL DRLG P CT 4245 psi @ 1.79 bpm in, 1.69 bpm 8,425.0 8,512.0 05:00 06:00 out, 1,162 free spin diff, annular 3784 psi, CT Wt 8.8 k Ib, WOB 2 k lbs, ROP 135 ft/hr, PUW = 45K, crew change Page 6139 ReportPrinted: 11/20/2018 Operations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time EM Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (flKB) End Depth (Val 10/28/2018 10128/2018 2.00 PROM DRILL DRLG P Drilling, FS = 1138 psi, CWT = 0.5K, 8,512.0 8,600.0 06:00 08:00 WOB = 1.2K, BHP = 3753 psi, WHP = 240 psi, circ = 4313 psi, -93% returns, pump 5x5 sweeps, lower ROP through 125 API lithology (down to 40 fph), Avg ROP 44 fph 10/28/2018 10/28/2018 2.00 PROD1 DRILL DRLG P Drilling, CWT = 3.3K, WOB = 1.5K, 8,600.0 8,684.0 08:00 10:00 BHP = 3764 psi, circ = 4470 psi, -91% retruns, continued lower ROP (45 - 70 fph), drilling w/ negative CWT, PUW's _-44K-46K, Avg ROP 42 fph 10/28/2018 10/28/2018 0.60 PROD1 DRILL WPRT P Wiper up -hole to window, chasing 8,684.0 7,080.0 10:00 10:36 sweeps, PUW = 48K Pulled early to allow Peter O'brien chance to verify inj/reel changes & reboot software update prior to leaving slope, & clean up higher gamma silt interval 10/28/2018 10/2812018 0.20 PROD1 DRILL DLOG P Log K1 for+4' correction 7,080.0 7,120.0 10:36 10:48 10128/2018 10/28/2018 0.30 PROD1 DRILL SVRG P Peter verifies inj/reel changes& 7,120.0 7,120.0 10:48 11:06 reboots software, software install complete (shut -down pump, shut-in choke) 10/28/2018 10128/2018 0.90 PROM DRILL WPRT P Wiper in-hole, RM = 10.3K, BHP 7,120.0 8,684.0 11:06 12:00 spiked at 8687', PUW = 44K, line-up to choke A, RBIH, slacking weight beginning at 8625' up through [owe At silt 10/28/2018 10/28/2018 2.00 PROM DRILL DRLG P BOBD, CWT= -7K, W013=1.I K, BHP 8,684.0 8,920.0 12:00 14:00 = 3783 psi, WHP = 275 pis, circ = 4367 psi CWT coming back drilling past higher gamma interval, drilling break at -8760', Avg ROP 118 fph Blew -down choke B, medium sized silt cavings observed 10/28/2018 10/28/2018 1.70 PROM DRILL DRLG P Drilling, CWT = 4.3K,WOB = 1.8K, 8,920.0 9,085.0 14:00 15:42 BHP = 3830', circ = 203 psi, BHA wiper from 8955', PUW = 42K, pump 5x5 sweeps 10/28/2018 10/28/2018 0.30 PROD1 DRILL WPRT P Wiper up -hole, PUW =42K 9,085.0 8,265.0 15:42 16:00 10/28/2018 10/28/2018 0.80 PROD1 DRILL WPRT P Wiper in-hole, stack weight at 8349', 8,265.0 9,085.0 16:00 16:48 PU, RBIH, stacking weigt at 8390' to 8442', up to -2.7K WOB on PU's, pump H[V[s sweeps, continue stacking through to 8635', PUW = 52K Bore & annular climbing, begin packing off, PUH, pulling heavy through to 8500'(-5K WOB), reciprocate to work off packoff, pulled up to 65K 10128/2018 2.00 PRODt DRILL TRIP T Pull to window, building sweeps, 9,085.0 7,233.0 110/28/2018 16:48 18:48 circulate bottoms up, pump, large amounts off large cavngs returned to the shaker. Page 7139 ReportPrinted: 11120120181 Operations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start rime End Time Dur rv) Phase op Code Activity Code Time P -T -X Operation (aKB) End Depth(ftKB) 10/28/2018 10/28/2018 2.00 PRODt DRILL CIRC T RIH, window and build clean, turned 7,233.0 7,220.0 18:48 2048 around in middle of build, pulled to just below window, RBIH to EOB, clean, pull to just below window chasing 5x5 sweep, clean - sweep carried 1/8" caving's to surface, RBIH to 7780, trip in was clean. PU Wt, 36 k Ibs, clean, Pull -4k WOB @ 7760', RBIH, SID @ 7667' 4.5K WOB, PU 52 K, 4.5 k WOB, pop free. Tum around at 7737' RBIH to 7780' clean, PU 36 k lbs, 4.3 k lbs WOB @ 7759' again. Turn around @ 7579', RBIH, to 7781', pull 10 ft/min, pumping 1.8 bpm, -Clean! Build clean window clean. 10/28/2018 10/2812018 1.80 PROD1 DRILL TRIP T Continue out of hole, chase three 7,220.0 70.0 20:48 22:36 separate 5x5 sweeps timed to exit at window, 3000', and surface. Diminishing solids returns each time. Perform shallow jog at surface, Pre load PDL while POOH. Last sweep at surface was clean. 10/28/2018 10/29/2018 1.40 PROD1 DRILL PULD T Bump up, PUD and LD BHA# 5. Bit 70.0 0.0 22:36 00:00 graded 1,1, NO 10129/2018 10129/2018 1.40 PROD1 STK PULD T PU & PD BHA #6, Billet W open hole 0.0 70.0 00:00 01:24 1 1 anchors. 10/2912018 10/29/2018 1.30 PROD1 STK TRIP T RIH 70.0 7,090.0 01:24 02:42 10/29/2018 10/29/2018 0.20 PROD1 STK DLOG T Tie into the Kl marker for -8' 7,090.0 7,123.4 02:42 02:54 correction. 10/29/2018 10/29/2018 0.50 PROD1 STK WPST T Continue in hole, PU Wt 37 k @ 7,123.4 7,756.8 02:54 03:24 7285', park, down on pump, Close EDC, continue in hole, Window and build clean. Park on depth, PU 30k to neutral CT Wt, Online w pump, observe sheer @ 4600 psi. Stack 3 k WOB on billet, PU Wt 36 K 10/29/2018 10/29/2018 1.50 PROD1 STK TRIP T PU Wt 36 K 7,756.8 70.0 03:24 04:54 PUH, Open EDC, Continue out of hole. 10/29/2018 10/29/2018 1.40 PROD1 STK PULD T Bump up, PUD & LD BHA#6. Crew 70.0 0.0 04:54 06:18 change. 10/29/2018 10/29/2018 1.30 PROD1 STK PULD T PD BHA#7 KO/Lateral Assembly 0.0 73.0 06:18 07:36 (NOV agitator, 0.5° AKO motor, RB P104 bit), slide in cart, MU to coil, tag up, set counters 10/29/2018 10/29/2018 1.40 PROD1 STK TRIP T RIH w/ BHA#7, close EDC, shallow 73.0 7,090.0 07:36 09:00 test @ 645' & grab transducer screenshot, 1.8 bpm, circ = 4430 psi, FS = 1070 psi 10/29/2018 10/29/2018 0.20 PROD1 STK DLOG T Log K1 for -6' correction, PUW = 34K 7,090.0 7,134.0 09:00 09:12 10/29/2018 10/29/2018 0.70 PROD1 STK TRIP T Continue RIH, dry tag TOB at 7746.5', 7,134.0 7,745.8 09:12 09:54 PUW = 38K, pumping 1.8 bpm, milling at 7745.8' 10/29/2018 10/29/2018 0.30 PROD1 STK KOST T Milling, pumping 1.82 bpm, FS = 1070 7,745.8 7,754.4 09:54 10:12 psi, CWT = 16.21K, WOB =AK, BHP = 3608 psi, WHIP = 112 psi, circ = 4247 psi WOB & molorwork milling off immediatley, begin chasing to find any WOB, not seeing WOB or motorwork Page 8/39 ReportPrinted: 11120/2018 Uperations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Dur (hp Phase Op Code Activity Code Tim. Pi Operation Stan Dept, (ttK8) End Depm r1KB) 10/29/2018 10/29/20180.10 PROD? STK KOST T PUH, PUW = 37K, RBIH to dry tag 7,754.4 7,756.0 10:12 1018 billet & troubleshot issue, tag TOB 7752.8', a lot of aluminum over shakers 10/29/2018 10/29/2018 0.80 PROD? STK KOST T Go back to milling, stall getting going, 7,756.0 7,762.0 10:18 11:06 milling from 7756', CWT = 13K, WOB = 1.36K, dip = 1476 psi, chasing WOB to get away from billet, stall at 7758.4' (approx slips depth), PUW = 42K, drill to 7762' & stall (up to 115 fpr), PUW = 38K, begin dragging -4K WOB at 7755', RBIH & stall at 7758', RBIH, packing off, rate out falls to 0 bpm out 10/29/2018 10/29/2018 0.40 PROD1 DRILL CIRC T Packed off at MM beginning at 7752', 7,762.0 7,329.0 1106 1130 PUH to above billet w/ no returns, no over pull or negative WOB, large caving appear over shaker, pump 10x10 sweeps working PUH to cased hole, packed off again at 7617' (believe at surface), blow down choke B, swap over, packed off immediately in cased hole (believe packed off at surface). 10/29/2018 10/29/2018 0.80 PROD1 DRILL CIRC T Blow down, choke A & B, blowdown 7,329.0 7,030.0 11:30 12:18 MM & snake, back on choke B, packed off, BHP climbing, chokes by- passed as both are packed off, open MP lines to check pressures to determine pack -off location, see 1200 psi on MP line, pack -off likely in return line. Confer w/ town, decision made to reduce pump rate. 70/29/2018 10/2912018 1.00 PRO DRILL CIRC T Slowly PUH, formulate plan to reverse 7,030.0 6,856.0 12:18 13:18 circulate through return line: shutdown pumps, close lower 2" pipe -slip rams, close SR 1 & SR2, close R8, open RC1 & RC2, bleed off above rams through riser, MU 2" 90 on riser. Pump back & have communication through return line hose. Line up down coil, have returns, though quickly re -pack off 10/29/2018 10/29/2018 1.20 PROD1 DRILL CIRC T Bi -pass chokes & MM, pump at 1.9 6,856.0 6,841.0 13:18 14:30 bpm (11.14 ppg at window), pump sweeps, circulate bottoms up, blow down chokes A & B, snake MM & button back up. Have returns, chokes & MM are all cleared. 10/29/2018 10/29/2018 0.20 PROD? DRILL DLOG T Log, K7 for+.5' correction 6,841.0 7,340.0 14:30 14:42 10/29/2018 10/29/2018 0.80 PROD1 DRILL CIRC T RIH to TOB, pump 5x5 sweeps, chase 7,340.0 7,340.0 14:42 1530 to TOWS, circulate bottoms up 10/29/2018 10/29/2018 0.20 PROD? DRILL TRIP T RBIH to TOB, drop pumps, tag at 7,340.0 7,758.0 15:30 1542 7759', PUW = 35K (approximate depth of slips) 10/29/2018 10/29/2018 1.50 PROM DRILL TRIP T RBIH, 1.8 bpm at —3.5 fph, pass 7,758.0 7,762.4 15:42 1712 7758', continue in slow to 7762', BHP = 3775 psi, WHIP = 249 psi, CWT = 15.5K, WOB =.25K, increasing WOB & motorwork from 7761' Page 9/39 Report Printed: 11120120181 Operations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Tana our (hr) Phase Op Code Activity Code Time P -T -X Opeation (f1KB) End Depth(flKB) 10/29/2018 10/29/2018 1.30 PROM DRILL DRLG T Drilling from 7762.4', CWT = 16K, 7,762.4 7,772.0 17:12 18:30 WOB = 1.4K, dp = 1360 psi, WOB spiking to 2.4K, then falling off, increase ROP to 112 fph, seeing little WOB, PUH above billet, PUW = 44K, RBIH to tag bottom (If in old hole should now know) 10/29/2018 10/29/2018 0.60 PRODt DRILL DRLG T Drilling, CWT = 7K, WOB = 2.4K, BHP 7,772.0 7,848.0 18:30 19:06 = 3748 psi, WHIP = 152 psi, NBI indicates getting away from old hole 10/29/2016 10/29/2018 0.40 PRODi DRILL TRIP T Dry drift billet area up & down, clean, 7,848.0 7,848.0 19:06 19:30 PUW = 48K, short -1.8K WOB spike at 7805' 10/29/2018 10/2912018 2.20 PROD1 DRILL DRLG T Drilling, CWT = IOK, WOB = 1.7K, 7,848.0 8,181.0 19:30 21:42 BHP = 3721 psi, WHP = 138 psi, - 97% returns, pumps 5x5 sweeps, Avg ROP 151 fph Swap to mud system #2, new mud at bit 7912' 10/29/2018 10/2912018 0.30 PROD1 DRILL WPRT T Wiper up -hole, PUW = 38K 8,181.0 7,780.0 21:42 22:00 10/2912018 10/29/2018 0.30 PROD1 DRILL WPRT T Wiper in-hole, RIW = 16K 7,780.0 8,181.0 22:00 22:18 10/29/2018 10/30/2018 1.70 PRODi DRILL DRLG T Drilling, 1.8 bpm, CWT= 11 K, WOB = 8,181.0 8,486.0 22:18 00:00 2K, BHP = 3737 psi, WHIP = 335 psi, circ = 4500 psi, drop to 1.5 bpm to allow DD to grab survey 10/30/2018 10/30/2018 0.60 PROD1 DRILL DRLG T OBD, CT Wt 8 k bs, 1.6 k WOB, 8,486.0 8,565.0 00:00 00:36 holding 11.8 ppg @ the window WH 246 psi, IA 690 psi, OA 740 psi PU 8553'44 k Free spin on restart 1006 psi 10/30/2018 10/3012018 0.20 PRODt DRILL WPRT T PU Wt 37 k lbs, Wiper trip #2 - 800' 8,565.0 7,790.0 00:36 00:48 Drag neg WOB, -1.68 K lbs, @ 7800' 10/30/2018 10/30/2018 0.30 PROD1 DRILL WPRT T RBIH 7,790.0 8,565.0 00:48 01:06 Stack out 7792'4.7 K WOB, 7804'3.3 k WOB, and 7816'2.3 k WOB, bounced on don, didn't pick up. Clean the rest of the way to bottom. 10/30/2018 10/30/2018 1.00 PROD1 DRILL DRLG T CT 4200 psi @ 1.79 bpm in 1.74 bpm 8,565.0 8,704.0 01:06 02:06 out, free spin diff 1027 psi, CT RIH Wt 16 k lbs, annular 3800 psi OBD, CT Wt 6 k lbs, WOB 1.94 k lbs, 10/30/2018 10/30/2018 2.00 PROD1 DRILL DRLG T 8,706' PU WT 45k lbs - Something 8,704.0 8,770.0 02:06 04:06 hard, ROP fell to 23 ft/hr CT Wt 4.8 k lbs, WOB 2.30 k bs, ROP 33 ft/ hr - most likely found the fault Gamma climbed rapidly to 143 API max 153, seeing soft clay balls at the shaker. 10/30/2018 10/30/2018 0.70 PROD1 DRILL DRLG T Drilling break, Gamma claned up and 8,770.0 8,877.0 04:06 04:48 resistivity returned to normal. 10/30/2018 10/30/2018 0.30 PROD1 DRILL DRLG T On another hard spot. ROP down to 8,770.0 8,878.0 04:48 05:06 1 1 10 f/hr. 10/30/2018 10/30/2018 0.50 PROD1 DRILL DRLG T Drilling break and losses, 1.78 in, 1.34 8,878.0 8,965.0 05:06 05:36 bpm out, slowly healing PU 39 k RBIH, 10/30/2018 10/30/2018 0.60 PROM DRILL WPRT T PU Wt 40 k lbs, Wiper trip #3 to 8,965.0 7,358.0 05:36 06:12 window for lie in. 10/30/2018 10/30/2018 0.20 PROD1 DRILL DLOG T Tie into the RA tag for+2' correction. 7,358.0 7,392.0 06:12 06:24 10/30/2018 10/30/2018 0.60 PROD1 DRILL WPRT T RBIH 7,392.0 8,965.0 06:24 07:00 Page 10139 ReportPrinted: 11/2012018 11 Operations Summary (with Timelog Depths) 3H-13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Tme End Time Dur (hr) Phew Do Code Acbvity Code Time P-T-X Operation (like) End Depth (ftKB) 10/30/2018 10/30/2018 0.90 PROD1 DRILL DRLG T Ct 4637 psi, @ 1.83 bpm in, 1.76 bpm 8,965.0 9,085.0 07:00 07:54 out, Free spin diff 1123 psi, annular, 3824 psi, IA 703, Oa 784 psi CT WT 7 k lbs, WOB 1.86 k lbs 9053' PU Wt 39 k lbs Average WOB. 10/30/2018 10/3012018 2.00 PRODt DRILL DRLG P Drill ahead 9,085.0 9,365.0 07:54 09:54 9191' PU Wt 52 k Ibs, pump 5x5 sweep and put BHA wiper, RBIH ROP increased from 100 to 240 as sweep exited, adding 1% 776 to high vis 10/3012018 10/30/2018 0.30 PROD? DRILL WPRT P PU W140 k Ibs, Wiper trip#1 -800' 9,365.0 8,565.0 09:54 10:12 10/30/2018 10/30/2018 0.30 PROD1 DRILL WPRT P RBIH, 8,565.0 9,365.0 10:12 10:30 S/D 8786', PU and try to work through x3, no luck Rolled TF from HIS to as drilled, RIH no issue 10/30/2018 10/30/2018 4.40 PROD1 DRILL DRLG P Ct 4784 psi, @ 1.82 bpm in, 1.76 bpm 9,365.0 9,765.0 10:30 14:54 out, Free spin diff 1219 psi, annular, 3838 psi, IA 703, Oa 797 psi CT WT 5 k lbs, WOB 1.58 k lbs 10/3012018 10/30/2018 0.30 PROD1 DRILL WPRT P PU Wt 39 k lbs, Wiper trip #2 - 800' 9,765.0 8,958.0 14:54 15:12 10/30/2018 10/3012018 0.30 PROD1 DRILL WPRT P RBIH, clean 8,958.0 9,765.0 15:12 15:30 10/30/2018 10/30/2018 4.00 PROD1 DRILL DRLG P Ct 4859 psi, @ 1.81 bpm in, 1.69 bpm 9,765.0 9,969.0 15:30 19:30 out, Free spin diff 1062 psi, annular, 3909 psi, WH 191, IA 707, OA 809 psi, CT WT 3 k lbs, WOB 1.1 k lbs - ROP 30 -100 R/hr 10/30/2018 10130/2018 0.60 PROD1 DRILL WPRT P Geo wiper, PUW = 43K 9,969.0 9,969.0 19:30 20:06 10/30/2018 10/3012018 1.90 PROD1 DRILL DRLG P Drilling, 1.8 bpm, CWT=-1.5K, WOB 9,969.0 10,062.0 20:06 22:00 = 1.35K, BHP = 3902 psi, WHIP = 162 psi, PU's to continue drilling, Avg ROP 49 fph Mud Swap to system #3, hit bit at 10,026' 10/30/2018 10/30/2018 1.50 PROD1 DRILL DRLG P Drilling, 1.8 bpm, CWT = 2K, WOB = 10,062.0 10,200.0 22:00 23:30 1.3K, BHP = 3890 psi, WHIP = 306 psi, circ = 4768 psi, pump 5x5 sweeps, 10/30/2018 10/31/2018 0.50 PRODt DRILL WPRT P Begin wiper to window, PUW=40K 10,200.0 8,775.0 23:30 00:00 10/31/2018 10/31/2018 1.50 PROD1 DRILL WPRT P Continue wiper to window, rate out 8,775.0 7,360.0 00:00 01:30 drops, packing off, RBIH, stack WOB at 8775', unable to move down or up, sit at just over PUW, pumphrig, allow pack-off to erode, pull free, silt-stone over shakers from lagged depth of 8775', slow down, pump 5x5 sweeps, circulate sweeps to surface. 10/31/2018 10/31/2018 0.10 PROD1 DRILL DLOG P Log RA for +4' correction 7,360.0 7,380.0 01:30 01:2 I 10/3112018 10/31/2018 1.20 PROD1 DRILL WPRT P in-hole, ran through trouble 7,380.0 10,200.0 01:36 02:48 interval 8750 - 8775' at min rate, saw JWiper 1.6K WOB at 8761', then fell off, RIW = 5K Page 11/39 ReportPrinted: 11/2012018 Uperations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (no Phase Op code Anivi Code ry Time P- T -X Operetion Start Depth n De End Depth (flKB) 10/31/2018 10/31/2018 2.20 PROD? DRILL DRLG P Drilling, 1.8 bpm, FS = 1090 psi, CWT 10,200.0 10,356.0 02:48 05:00 = 2K, WOB = 1 K, BHP = 3900 psi, WHIP = 259 psi, circ = 4736 psi, PUW = 48K from 10,293', PUW = 54 from 10,331' 10/312018 10/31/2018 4.80 PROD1 DRILL DRLG P Drilling, CWT= -0.5K, WOB=1K, 10,356.0 10,535.0 05:00 09:48 BHP = 3949 psi, WHIP = 289 psi, circa = 4822 psi 10/31/2018 10/31/2018 3.20 FROM DRILL WPRT P Geo called TD @ 10535' 10,535.0 78.0 09:48 13:00 PU WT 40 k lbs - launch 10x10 TD sweeps, while PUH slowly. Increase to normal POOH rate and chase sweeps to surface. Time tow additional 5x5 sweeps for the trouble area @ 8700' and the build. Saw some motor work @ 8713', continued out of hole Lots of very small but fresh ravings at 2300 bit depth, surged well near surface, quite a bit of aluminum and some larger, more rounded rocks at the shaker. 10/31/2018 10/31/2018 1.30 FROM DRILL TRIP P RBIH 398.0 7,080.0 13:00 14:18 10/31/2018 10/31/2018 0.20 PROD1 DRILL DLOG P Tie into K1 for -8.5' correcion. 7,080.0 7,163.0 14:18 14:30 10/31/2018 10/31/2018 0.20 FROM DRILL DLOG P Park @ 7326.09' CTMD, 5953.08' 7,163.0 7,326.0 14:30 14:42 TVD Trap 3763 psi 1 min 3683 psi 11.89 ppg 2 min 3632 psi 11.80 ppg 3 min 3632 psi 11.73 ppg 4 min 3612 psi 11.61 ppg 5 min 3588 psi 11.59 ppg 10/312018 10/31/2018 1.80 FROM DRILL TRIP P Continue to RIH, window, build, and 7,326.0 10,328.0 14:42 16:30 falut at 8700' clean To/3 1 //2518 10/312018 2.30 FROM DRILL DISP P POOH displacing well to liner running 10,328.0 78.2 16:30 18:48 pill - 52 bbls top of pill 4400'. Painted Yellow flag 8478.4' 10/31/2018 10131/2018 0.50 FROM DRILL OWFF P At surface, check well for flow (no- 78.2 78.2 18:48 19:18 flow), PJSM 10/31/2018 10/312018 0.45 FROM DRILL PULD P LD drilling assembly on a dead well 78.2 0.0 19:18 19:45 10/31/2018 10/31/2018 0.30 PROD1 DRILL OTHR P Perform Function test on BOP stack. 78.2 19:45 20:03 (good test), LD testjoint 10/31/2018 10/31/2018 0.40 COMPZ1 CASING PUTS P Prep RF for liner ops, PJSM 0.0 0.0 20:03 20:27 10/312018 10/31/2018 2.75 COMPZI CASING PUTB P PU 55 joints of slotted liner with non- 0.0 1,840.7 20:27 23:12 ported bullnose and shorty deployment sleeve. 10/31/2018 10/31/2018 0.25 COMPZI CASING PUTS P RD liner running equipment 1,840.7 1,840.7 23:12 23:27 10/31/2018 11/1/2018 0.55 COMPZI CASING PULD P PJSM, PU/MU CoilTrak tools, 1,840.7 1,884.9 23:27 00:00 (hanging rig hook -load 21.49 k), spaceout, close 2-318" on tool string, bring cart forward 11/1/2018 11/1/2018 0.45 COMPZI CASING PULD P Swap out float valves in UQC, stab 1,884.9 1,884.9 00:00 0027 INJH, surface test BHI CoilTrak tools (good -test), function open rams, tag up, reset counters 11/1/2018 11/1/2018 1.44 COMPZI CASING RUNL P RIH w/liner segment#1 1,884.9 7,296.1 00:27 01:53 Page 12/39 Report Printed: 11/20/2018 Operations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Anvity Code Time P -T -X Operation (ftKB) End Depth(flKB) 11/1/2018 11/1/2018 0.10 COMPZI CASING RUNL P Correct to the E0P flag minus 11.0', 7,296.1 7,296.1 01:53 01:59 PUW 11/1/2018 11/1/2018 0.30 COMPZI CASING RUNL P Continue RIH 7,296.1 8,166.0 01:59 02:17 11/1/2018 11/1/2018 1.75 COMPZI CASING RUNL P Start working liner towards bottom, 8,166.0 9,960.0 02:17 0402 PUW's 45-50k 11/1/2018 11/1/2018 0.20 C0MPZ7 CASING RUNL P Continue RIH to bottom 9,960.0 10,347.0 0402 04:14 11/1/2018 11/1/2018 2.00 COMPZI CASING TRIP P Off bottom, PUW 34 k, remove liner 10,347.0 58.0 04:14 06.14 length from depth, lined up across the top, POOH 11/1/2018 11/1/2018 0.60 COMPZI CASING PULD P Crew change, PJSM, bump up, flow 58.0 0.0 0614 0650 check, LD BHA#8, lower AL1 completion running assembly. 11/1/2018 11/7/2018 0.40 COMPZI CASING PUTB P Prep floor to run liner 58.0 0.0 06:50 07:14 11/7/2018 11/1/2018 0.50 COMPZI CASING SVRG P Lock out comy to repair hydralic weep 0.0 0.0 0714 0744 on HCR - B8, (recently replaced) 11/1/2018 11/1/2018 1.20 COMPZI CASING PUTB P Pick up and run 19 joints under an 0.0 763.7 07:44 08:56 anchored billet. (763.69' LOA) 11/1/2018 11/1/2018 0.90 C0MPZ1 CASING PUTB P PU BHA# 9, Upper completion 763.7 837.1 08:56 09:50 1 running assembly 11/1/2018 11/1/2018 1.60 C0MPZ7 CASING RUNL P RIH, Tie into the window flag for a -8.9' 837.1 8,062.0 09:50 11:26 correction, Close EDC. PU Wt 35k Ibs @ 7226' Encounter sharp WOB increase as bull nose approached the billet @ 7745'. Stack 10 k WOB @ 7877', slow running speed from 26 ft/min to 17 ft/min Stack 10.9 k WOB again at 8,062 bit depth, PU Wt 37 k lbs 11/1/2018 11/1/2018 1.60 COMPZI CASING PULL T PUH, park, open EDC, POOH, update 8,062.0 844.0 11:26 1302 window flag depth to account for planed BHA change. 11/1/2018 11/1/2018 0.80 COMPZI CASING PULD T Bump up, flow check, 0.4 bbls to fill 844.0 809.1 13:02 1350 stack, LD liner running tools. 11/1/2018 11/1/2018 0.90 C0MPZ1 CASING PULD T MU BHA#10, (drop off HOT, pick up 809.1 809.1 13:50 14:44 GS and make up shorty to liner) 11/1/2018 11/1/2018 1.80 COMPZI CASING RUNL T Bump up, set counters, RIH, 809.1 8,506.7 14:44 16:32 PU Wt 35 k lbs @ 7209', WOB -3 on pick up. RIH widow, billet clean, S/D 8506' PU Wt 36 k lbs, RBIH, S/D 8506.6'& 4.2 k WOB Pump 1.5 bpm, only built 104 psi diff, S/D, discuss, pump 1.7 bpm, max safe for BHP, built 3576 psi on CT and 27 psi diff 11/1/2018 11/1/2018 2.00 COMPZI CASING TRIP T PU, WOB-2.2 k lbs POOH with AL1 8,506.7 809.1 16:32 18:32 upper completion. Suspect EDC has failed. Park at 6884', cycle EDC open then closed, 11/1/2018 11/1/2018 0.45 COMPZI CASING PULD T At surface, check well for flow, unstab 809.1 764.9 18:32 1859 INJH, MU test plate to end of coil, PT 4,100 psi (good -test), move cart back, continue inspecting Coiltrak Tools, found EDC failure, PJSM for contengencies while swapping out tools, 11/1/2018 17/1/2018 0.50 COMPZt CASING PULD T Swap out upper section, 764.9 764.9 18:59 19:29 Page 13/39 ReportPrinted: 11/20/2018 n Operations Summary (with Timelog Depths) 3H -13A Il Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth SWM Tim I End Time Dur (hr) Phase Op cede A dy Cade Time P -T -X Operation (MB) End Depth (WS) 11/1/2018 11/1/2018 0.25 COMPZI CASING PULD T Move cart forward, MU Coil, perform 764.9 809.1 19:29 19:44 surface test (good -test) 11/1/2018 11/1/2018 OAA COMPZ1 CASING PULD T Stab on INJH, tag up reset counters, 809.1 809.1 1944 1950 RIH w/BHA#11 11/1/2018 11/1/2018 1.00 COMPZI CASING RUNL T RIH, w/19jts of slotted liner, ported 609.1 7,222.0 1950 2050 bullnose, and shorty deployment sleeve, BHA#11 liner segment #2 11/1/2018 11/1/2018 0.15 COMPZ1 CASING RUNL T Correct to the EOP flag plus 16.0', 7,222.0 7,222.0 20:50 20:59 PUW 35 k, minus 4.4 k DHWOB 11/1/2018 11/1/2018 0.20 COMPZI CASING RUNL T Continue IH 7,222.0 7,830.0 20:59 21:11 11/1/2018 11/1/2018 0.40 COMPZI CASING RUNL T Log the K1 for depth control, minus 7,830.0 7,830.0 21:11 21:35 25' (minus 9.0') 11/1/2018 11/1/2018 0.25 COMPZ1 CASING RUNL T Continue RIH 7,830.0 8,506.0 21:35 21:50 11/1/2018 11/1/2018 0.15 COMPZ1 CASING RUNL P Set down, 2.3 k, PUW 37 k, set back 8,506.0 7,730.0 21:50 21:59 down, 3.5 k, bring pump up to 1.4 bpm at 3,953 psi, 1,099 psi diff, PUW 32 k minus 2.2 DHWOB, liner released, park at remove liner length from counter depths 11/1/2018 11/1/2018 1.50 COMPZI CASING TRIP P POOH, pumping min rate down the 7,730.0 44.2 21:59 23:29 coil, PJSM @ 2,500' 11/1/2018 11/2/2018 0.51 COMPZI CASING PULD P At surface, check well for flow, LD 44.2 0.0 23:29 00:00 setting tools BHA#10 11/2/2018 1102018 0.75 COMPZI CASING PULD P PU/MU OHAnchored Billet, MU 0.0 73.4 00:00 00:45 CoiilTrak tools, MU UQC, surface test tools (good -test), stab and MU INJH, tag up, reset counter depths 11/2/2018 11/2/2018 1.20 COMPZI CASING TRIP P RIH, with OH Anchored Billet (open- 73.4 7,095.0 00:45 01:57 EDC), pumping min rate 0.35 bpm at 356 psi 11/2/2018 11/2/2018 0.30 COMPZ1 CASING DLOG P Log the K1 marker correction of minus 7,095.0 7,121.0 01:57 02:15 75, Gose EDC, PUW 35 k 11/2/2018 11/2/2018 0.20 COMPZ1 CASING TRIP P Continue IH 7,121.0 7,741.0 02:15 02:27 11/2/2018 11/2/2018 0.20 COMPZI CASING WPST P Set down 2.2 k DHWOB, PUH to 7,741.0 7,730.0 02:27 02:39 neutral weight, bring pump up at 0.5 bpm up to shear 2,600 psi, PUW 38 k 11/2/2018 11/2/2018 1.50 COMPZ1 CASING TRIP P POOH, pumping 0.72 bpm at 1,127 7,730.0 44.2 02:39 04:09 psi, PJSM @ 500' from surface 11/2/2018 11/2/2018 0.50 COMPZI CASING PULD P At surface, LD setting tools on a dead 44.2 0.0 04:09 04:39 well. 11/2/2018 112/2018 1.00 PROD2 STK PULD P PU BHA# 13, AL1 -01 drilling 0.0 78.2 04:39 05:39 assembly, 0.7° AKO w HYC A2 bit, bump up, set counters. 1122018 11/2/2018 1.00 PROW STK TRIP P RIH, 78.2 7,091.0 05:39 06:39 11/2/2018 11/2/2018 0.20 PROD2 STK DLOG P Tie into the K1 marker for -8' 7,091.0 7,122.0 06:39 06:51 correction 11/2/2018 11/2/2018 1.40 PROD2 STK DISP P Continue to RlH 7,122.0 7,730.0 06:51 08:15 Tag TOB @ 7730.4', PUH while displacing drilling mud to surface. 11/2/2018 11/2/2018 1.50 PROD2 STK KOST P Time mill off billet 7,730.0 7,732.2 08:15 09:45 CT 4305 psi @ 1.80 bpm in 1.80 bpm out, free pinn 1075 psi, CT WT 16.7 k lbs, WOB 0.4 k lbs WH 275 psi IA 694 psi, OA 719 psi. 11/2/2018 112/2018 0.60 PROD2 STK KOST P Start targeting 0.5 k WOB, step up to 7,732.2 7,740.8 09:45 10:21 1 1 1 1 5, 10 and 15 ft,hr Page 14139 ReportPrinted: 11/20/2018 Operations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sian Depth Stan Time End Tme Dur (hr) Phase Op Code Activity Cade Time P -T -X Operation (fti<a) End Depen (ftM) 11/2/2018 11/2/2018 0.80 PROD2 DRILL DRLG P Drilling ahead 7,740.8 7,792.0 10:21 11:09 Ct Wt 13 k lbs, WOB 2 k lbs, ROP 100 - Whir Drill to 7790', PU W141 k IDS, PUH, slight over pull at bilet, 0.8 k Ibs WOB RBIH, driy, drift, billet clean 11/2/2018 11/2/2018 0.80 PROD2 DRILL DRLG P OBD 7,792.0 7,891.0 11:09 11:57 CT Wt 13.6 k lbs, WOB1.6 k lbs, ROP 200 ft/hr 11/2/2018 11/2/2018 0.40 PROD2 DRILL WPRT P PU for DD wipers, dirty surveys and 7,891.0 7,891.0 11:57 12:21 threading the needle betwen AL1, PB1. Disscussed w town, PUH and shot checkshot above billet. RBIH 11/2/2018 11/2/2018 1.00 PROD2 DRILL DRLG P CT 4451 psi, @ 1.81 bpm in, 1.80 7,891.0 8,046.0 12:21 13:21 bpm out, free spin diff 1205 psi, annular 3731 psi. CT 12.8 k lbs, WOB 2.1 k lbs, ROP 200 f/hr Average ROP over interval 155 11/2/2018 11/2/2018 0.80 PROD2 DRILL DRLG P Having difculty getting turned down 8,046.0 8.074.0 13:21 14:09 PU 44 k lbs, RBIH slowlly PU 39k lbs, RBIH slowly Time drill 11/2/2018 11/2/2018 1.70 PROD2 DRILL DRLG P PU Wt 38 k lbs, adjust rale back to 1.8 8,074.0 8,300.0 14:09 15:51 CT 4435 psi, 1.79 bpm in, 1.79 bpm out, free spin 1181 psi, annular 3747 psi, WH 188 psi, IA 697, OA 760 CT 8.4 k lbs, WOB 2.4 k lbs, ROP 200 R/hr. 11/2/2018 11/2/2018 0.20 PROD2 DRILL WPRT P PU, 41 k lbs -1 MOB coming oft 8,300.0 7,764.0 15:51 16:03 bottom slight negWOB overpulls @ 7928, and 7780' 11/2/2018 11/2/2018 0.20 PROM DRILL WPRT P RBIH 7,764.0 8,300.0 16:03 16:15 S/D @ 7764' and 7776' reduce pump rate and RIH 11/2/2018 11/2/2018 1.20 PROD2 DRILL DRLG P CT 4435 psi, 1.79 bpm in, 1.79 bpm 8,300.0 8,529.0 16:15 17:27 out, free spin 1193 psi, annular 3747 psi, WH 180 psi, IA 699, OA 780 CT 8.4 k lbs, WOB 2.4 k lbs, ROP 200 ft/hr. PU Wt 37 k lbs, adjust rate to 1.9 CT 4704 psi, 1.90 bpm in, 1.90 bpm out, free spin 1298 psi, annular 3732 psi, WH 150 psi CT 8.6 k lbs, WOB 2.2 k lbs, ROP 200 tUhr. 11/2/2018 11/2/2018 1.60 PROD2 DRILL DRLG P OBD @ 228 fph, 1.9 bpm at 5,206 psi, 8,529.0 8,700.0 17:27 19:03 Diff --1,315 psi, WHP=36, BHP=3,805, IA=701, OA=800 11/2/2018 11/2/2018 0.50 PROD2 DRILL WPRT P Wiper up hole with sweeps, PUW 35 k 8,700.0 7,760.0 19:03 19:33 11/2/2018 11/2/2018 0.45 PROD2 DRILL WPRT P Wiper back in hole, RIW 16 k 7,760.0 8,700.0 19:33 20:00 11/2/2018 11/2/2018 2.30 PROD2 DRILL DRLG P BOBD, 1.9 bpm at 3,796 psi, 8,700.0 9,101.0 20:00 22:18 Diff=1,325 psi, WHP=166, BHP=3,809, IA=702, OA=806 11/2/2018 11/2/2018 1.10 PROD2 DRILL WPRT P Wiper up hole, PUW 39 it 9,101.0 7,360.0 22:18 23:24 1 1 11/2/2018 11/2/2018 0.20 PROD2 DRILL DLOG P Log RA marker correction of plus 2.0' 7,360.0 7,362.0 23:24 23:36 I I I I Page 15139 Report Printed: 1112012018 Uperations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SmM1Tme EM Time Dur (hr) Phase Op Code Aavity Code Time P -T-% Opetatlon Start Depth (ftKB) End Depth (f1KB) 11/2/2018 11/3/2018 0.40 PROD2 DRILL WPRT P Wiper back in hole, RIW 10 It 7,362.0 8,823.0 23:36 00:00 11/3/2018 11/3/2018 0.15 PROD2 DRILL WPRT P Continue wiper in hole, RIW 10 k 8,823.0 9,101.0 00:00 00:09 11/3/2018 11/3/2018 1.00 PROD2 DRILL DRLG P BOBD, 1.9 bpm at 4,977 psi, 9,101.0 9,241.0 00:09 01:09 Diff --1.360 psi, WHP=164, BHP=3,820, IA=700, OA=811 11/3/2018 11/3/2018 0.10 PROD2 DRILL WPRT P BHA Wiper PUW 45 k 9,241.0 9,241.0 01:09 01:15 11/3/2018 11/3/2018 1.75 PROD2 DRILL DRLG P BOBD, 1.9 bpm at 5,109 psi, 9,241.0 9,455.0 01:15 03:00 Diff -1,367 psi, WHP=227, BHP=3,849, IA=701, OA=819 Note: New Mud at the bit 9,394' 11/3/2018 11/3/2018 0.34 PROD2 DRILL DRLG P PUH, obtain drilling parameters, 9,455.0 9,500.0 03:00 03:20 BOBD, 1.9 bpm at 4,698 psi, Diff=1,349, WHP=340, BHP=3,830, IA=696, OA=804 11/3/2018 11/3/2018 0.45 PROD2 DRILL WPRT P Wiper up hole 1000', PUW 39 k 9,500.0 8,500.0 03:20 03:47 11/3/2018 11/3/2018 0.40 PROD2 DRILL WPRT P Wiper back in hole, RIW 8,500.0 9,500.0 03:47 04:11 11/3/2018 11/3/2018 1.90 PROD2 DRILL DRLG P BOBD, 1.9 bpm at 4,489 psi, 9,500.0 9,773.0 04:11 06:05 Diff --1,130, WHP=387, BHP=3,846, IA=694, OA=771 Average ROP over interval 143 Whir 11/3/2018 11/3/2018 0.45 PROD2 DRILL WPRT P PU wt 42 k, crew change pick up, 9,773.0 9,773.0 06:05 06:32 100' wiper, RBIH Wt 8.9 k lbs 11/3/2018 11/3/2018 0.60 PROD2 DRILL DRLG P CT 4650 psi @ 1.88 bpm in, 1.80 bpm 9,773.0 9,900.0 06:32 07:08 out, Free spin diff 1211 psi, Annular 3875 psi, 11.8 ppg @ the window WH 335 psi, IA 694 psi, OA 755 psi BOBD, CT Wt 0 k lbs, WOB 1.34 k lbs, ROP 100-200 Whir Average ROP over interval ft/hr 211 11/3/2018 11/3/2018 0.40 PROD2 DRILL WPRT P PU Wt 44 kwiper #2 9,900.0 8,896.0 07:08 07:32 11/3/2018 11/3/2018 0.40 PROD2 DRILL WPRT P RBIH Ct Wt 8,896.0 9,900.0 07:32 0756 11/3/2018 11/3/2018 0.90 PROD2 DRILL DRLG P OBD 9,900.0 10,018.0 07:56 08:50 CT 5025 psi @ 1.88 bpm Free spin diff 1202 psi, CT Wt -1 k lbs, WOB 1. k lbs, ROP 100-200 It/hr Average ROP over interval It/hr 131 11/3/2018 11/3/2018 0.40 PROD2 DRILL DRLG P DD having issue building angle, PU 10,018.0 10,068.0 08:50 09:14 and restart with lower pump rate, 1.53 bpm CT 5025 psi @ 1.88 bpm Free spin diff 1202 psi, CT Wt -1 k lbs, WOB 1. k lbs, ROP 100-200 Whir Average ROP over interval ft/hr 125 11/3/2018 11/3/2018 0.80 PROD2 DRILL DRLG P Built angle to 88°, PU 40 k lbs, 10,068.0 10,137.0 09:14 10:02 increase rate back to 1.9 CT 4878 psi, @ 1.88 bpm in, 1.86 bpm out, Annular 3898 psi, WH 271 psi, IA 695 psi, OA 776 psi CT Wt -4.8 k lbs, WOB 1 k lbs, ROP 150 (L/min PU 10081, 44 k lbs Average ROP over interval tUhr 86 Page 16/39 ReportPrinted: 11/20/2018 Uperations Summary (with Timeli Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tme End Time Dur ph,) Phase Op Code Activity Code Time P -T -X Operation Slart Depth fKB) End Depth(ftKB) 11/3/2018 11/3/2018 1.70 PROD2 DRILL DRLG P Sudden dop in ROP @ 10137', drilling 10,137.0 10,265.0 1002 1144 break @ 10,140' CT 4878 psi, @ 1.88 bpm in, 1.86 bpm out, Annular 3898 psi, WH 271 psi, IA 695 psi, OA 776 psi CT Wt -4.8 k lbs, WOB 1 k lbs, ROP 8 - 150 ft/min PU's 10081, 44 k lbs 10138 48 k 10169 42 k 10185 43 k 10204 43 k 10230 46 k 10247 46k Pump 5x5, Average ROP over interval ft/hr 75 11/3/2018 11/3/2018 1.00 PROD2 DRILL WPRT P PU Wt 46 kwiper #3 10,265.0 7,360.0 11:44 1244 Hole and billet clea on trip out of hole, returned 0.5 bbls solids 11/3/2018 11/3/2018 0.10 PROD2 DRILL DLOG P Tie into the RA tag for a +4' correction 7,360.0 7,381.0 12:44 12:50 11/3/2018 11/3/2018 1.80 PROD2 DRILL WPRT P Wiper back in hole, RIW 7,381.0 10,266.0 12:50 14:38 billet clean, Stack WOB to 4 k x4, PU's to -2 k lbs WOB from 8340-8390' Orient TF to as drilled, pump to min rate, and lower RIH speed to 30 ft/min,, slid through. Hale otherwise clean to bottom. While increasing rate to 1.9 bpm, experienced 2 annular pressure events and pulled heavy 48 k lbs , packing off. Launched 5x5 sweep pulled up hole slowly pumping 1.9 bpm, pressures back to normal. lower pump rate to 1.7 bpm and attempt to RIH, no luck 11/3/2018 11/3/2018 0.40 PROD2 DRILL WPRT P PUH on 500' wiper while adding low 10,266.0 10,266.0 14:38 1502 torqu to high and low vis pit pits as well as Alpine beads to Hi Vis Turn around @ 9776' RBIH 11/3/2018 11/3/2018 2.96 PROD2 DRILL DRLG P CT 4345 psi, @ 1.70 bpm in, 1.70 10,266.0 10,421.0 15:02 18:00 bpm out, Annular 3913 psi, WH 311 psi, IA IA 698, OA 789 CT Wt -4.9 k lbs, WOB 1.76 k lbs, PPU @ 10297', 52 k lbs Pumping sweeps 5x5 w beads in the hi -vis 11/3/2018 11/3/2018 4.20 PROD2 DRILL DRLG P Continue Drilling ahead with beaded 10,421.0 10,696.0 18:00 22:12 sweeps, 1.9 bpm at 4,420 psi, Diff=1,152 psi, WHP=244, BHP=3,938, IA=700, OA=813, PU's 35-45 k 11/3/2018 11/4/2018 1.80 PROD2 DRILL WPRT P TDALl-01 Lateral, PUH 35k, heistate 10,696.0 7,316.0 22:12 00:00 for sweeps to exit bit, POOH, launch and time out sweeps @ EOB and window, continue Wiper to the swab valve. 11/4/2018 11/4/2018 1.50 PROD2 DRILL WPRT P Continue wiper to the swab valve, 7,316.0 78.3 00:00 01:30 pumping 1.83 bpm at 4,725 psi, perform jog @ 1,071' - 1,453', recovered some cavings across shaker, retrieve sample and upload picture to sArive, continue wiper to surface Page 17139 ReportPrinted: 1112 0/2 01 8 -` Uperations Summary (with Timelog Depths) 3H-13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time EM Time Our (ho Phase Op Code AcUsity C Time P-T-X Operation sten Depth (WS) End Depth (WFI) 11/4/2018 11/4/2018 0.20 PROD2 DRILL WPRT P Tag up at surface, reset counter 78.3 78.3 01:30 01:42 depths 11/4/2018 11/4/2018 0.20 PROM DRILL TRIP P —Daylight savings— 78.3 7,095.0 01:42 01:54 RIH to confirm TD 11/4/2018 11/4/2018 0.20 PROD2 DRILL DLOG P Log the K1 correction of minus 9.5', 7,095.0 7,316.0 01:54 02:06 PUW 11/4/2018 11/4/2018 0.20 PROD2 DRILL CTOP P Perform Pressure Survey, Shutdown 7,316.0 7,316.0 02:06 02:18 mud pump, close choke 71' RKB to Sea Lvl 11.6 ppg ECD 3,595 psi Press Sensor (TVD) 5,947.88' 11/4/2018 11/4/2018 2.20 PROD2 DRILL WPRT T Continue IH, started taking CT weight 7,316.0 10,420.0 02:18 0430 @ 8,392'(4k bobble) no pickup, continued IH, 9,045'sel down, noticed packing off and pulling heavy (52k), worked pipe, continued back up hole to 8,000', RBIH, fairly clean toward bottom, struggling to get back to bottom @ 10,420', pull wiper to the window. 11/4/2018 11/4/2018 2.20 PROD2 DRILL WPRT T Pull wiper to the window, PUW 45 k 10,420.0 7,360.0 04:30 06:42 Up down passes @ 10,288, 10135, 10107' -1 k WOB bobble @ 8348- 11/4/2018 11/4/2018 0.20 PROM DRILL DLOG T Tie int oth R4 tag for +2' correcion 7,360.0 7,396.0 06:42 06:54 11/4/2018 11/4/2018 1.00 PROD2 DRILL TRIP T RBIH to confirm TD and lay in liner 7,396.0 9,720.0 06:54 07:54 running pill Encounter motor work in multiple spots, 8375, 9030, 9451, 9720' SID multiple times 9720', varied pump rate, running speed, and TF, PU's 45 k lbs fine fresh cavings and lots of fine cuttings at the shaker, looks like we are drilling ahead at – 120 ft/hr 11/4/2018 11/4/2018 1.80 PROD2 DRILL WPRT T Consult w engineering on path 9,720.0 7,280.0 07:54 09:42 forward, Roll into clean out mode, transfer liner running pill back to pit 6 KW and build 50 bbl's each to and hi vis, hi vis out of active mud to allow room for expected returns at surface. While building sweeps, PUH slowly, minor pack off events @ 9200, 9075, 9891', 8364' and pulled heavy at 8344' RBIH, 3 k WOB, PU, 35 k lbs, PUH Billet and window clean. ""additional 1.4 bbl's of cuttings returned since RBIH post swab wiper 11/4/2018 11/4/2018 1.60 PROD2 DRILL WPRT T Pump 5x5, chase to surface while 7,280.0 7,097.0 09:42 11:18 jogging coil from 6559 to 7275'. Some large rocks and a large amount of fine cavings returned to the shaker. Steady state of cavings that had been returning diminished significantly. Pumped additional 5x5, greatly diminished amount of large rocks, only a couple versus 100's. 11/4/2018 11/4/2018 0.20 PROD2 DRILL DLOG T Tie into the K1 for a +3 ' correction. 7,097.0 7,112.2 11:18 11:30 Page 18139 Report Printed: 11/20/2018 Uperations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time EM Time our (hr) Phew Op Co" Activity Cafe Time P -T -X Operetion Start Depth (ftKB) End Depth (ftKB) 11/4/2018 11/4/2018 1.40 PROD2 DRILL WPRT T RIH, window and build clean, pumping 7,112.2 10,699.0 11:30 12:54 1 bpm and running 50 ft/min. Some motor work @7776', 9432', and SID @ 10,290'. PU 40 k lbs. 11/4/2018 11/4/2018 0.30 PROD2 DRILL WPRT T PU, 38 k lbs, Stage pump to 1.9 bpm, 10,699.0 10,630.0 12:54 13:12 POOH slowly at rate chasing sweep out of open hole. Three annular pressure spikes with a sligh drop in out rate 38 bbls pumped. 11/4/2018 11/4/2018 1.00 PROD2 DRILL WPRT T Increase pulling speed to 50 ft/min, 10,630.0 7,863.0 13:12 14:12 POOH Stage sweeps for build and the window. neg WOB over pulls @ 9461' and 8377'with annular pressure spikes. 11/4/2018 11/4/2018 0.80 PROD2 DRILL WPRT T Baker coil trac tools lost power, slow 7,863.0 7,718.0 14:12 15:00 pulling speed to 3 Warm. Sweeps exiting early, Started to pack off and pull heavy @ 7779' Attempt to RIH, setting down at 7755' Pulling up to 50 k @ 7746. Work pipe, returns Fluctuating. Pull past billet, full returns 11/4/2018 11/4/2018 0.80 PROD2 DRILL WPRT T Pull through build blind. No over pull 7,718.0 7,718.0 15:00 15:48 on CT Wt. Sweeps from the billet landed with a few rocks, mostly small savings. Pumped 4 sweeps in cased hole, third and fourth clean. 11/4/2018 11/4/2018 2.75 PROD2 DRILL WPRT T POOH, to surface without comms to 7,716.0 78.2 15:48 18:33 BHA 11/4/2018 11/42018 1.00 PROD2 DRILL PULD T At surface, PUD failed drilling BHA 78.2 0.0 18:33 19:33 #13, unstab INJH, test a -line (good - test), slide cart back, hooked up test cable to BHA test tools (bad -test), continue PUD 11/4/2018 11/4/2018 1.15 PROD2 DRILL PULD T PD cleanout BHA#14 0.0 68.4 19:33 20:42 11/4/2018 11/4/2018 1.25 PROD2 DRILL TRIP T Tag up, reset counters, RIH w/BHA 68.4 7,090.0 20:42 21:57 #14 cleanout assembly with D331 and agitator. 11/42018 11/4/2018 0.20 PROD2 DRILL DLOG T Log the K1 marker correction of minus 7,090.0 7,124.0 21:57 22:09 8.5' """ Note: End of BHI DT 11/4/2018 11/4/2018 0.45 PROD2 DRILL TRIP T Continue RIH thru window, timeout 7,124.0 7,900.0 22:09 22:36 5x5 sweep, `"" Note: 7,733'-7,776' notice +2.2 k DHWOB 11/4/2018 11/4/2018 1.00 PROD2 DRILL WPRT T Pull wiper up to the tubing, PUW 36 k, 7,900.0 5,500.0 22:36 23:36 notice "'" Note: Minus 6.0 k pull @ 7,730' as DTF 11/4/2018 11/5/2018 0.40 PROD2 DRILL TRIP T Continue trip back in hole, RIW 14 k 5,500.0 7,646.0 23:36 00:00 11/5/2018 11/5/2018 0.55 PROD2 DRILL TRIP T Continue trip back in hole clean, RIW 7,646.0 9,000.0 00:00 00:33 1 14 k 11/5/2018 11/5/2018 1.00 PROD2 DRILL WPRT T Wiper up hole into the tubing, PUW 38 9,000.0 5,800.0 00:33 01:33 k, 7,763' minus 1.0 k, 8,983' minus 2.5 k Page 19139 ReportPrinted: 11120120181 Uperations Summary (with Timelog [Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Tme Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (hKe) 11/512018 1115/2018 0.25 PROD2 DRILL TRIP T RBIH 5,800.0 7,090.0 01:33 01:48 11/5/2018 11/5/2018 0.10 PROD2 DRILL DLOG T Log the K1 marker correction of plus 7,090.0 7,110.0 01:48 01:54 2.5' 11/5/2018 11/5/2018 1.70 PROD2 DRILL TRIP T Continue trip in hole, RIW 14 k, 7,730' 7,110.0 10,699.0 01:54 03:36 0.9 k, 9,450' 0.3 k, 10,251' 1.0 k, 10,400' 0.6 k, 10,470' setdown, PUH 38 k, RBIH, confirm TD 10,699', pump 10x10 sweep 11/5/2018 11/5/2018 1.80 PROD2 DRILL WPRT T PUH slowly notice annular pressure 10,699.0 10,465.0 03:36 05:24 swings, slowly work coil up hole, 10,465' pull heavy, turn around and are unable to move pipe, returns slowly deminished to zero. Countinue to work pipe to establish returns. 11/5/2018 11/5/2018 7.10 PROD2 DRILL CTOP T Circulate 14.7 bbl of LVT down coil, let 10,465.0 10,465.0 05:24 12:30 soak, work pipe staging CT Wt up to 86 k lbs, and -16 k Ibs. Atempted various pump rates and dumped choke while pulling max. 11/5/2018 11/5/2018 3.50 PROD2 DRILL CTOP T Build 10 bbl 100 k LSRV Hi -vis pill, 10,465.0 10,465.0 12:30 16:00 displace down coil to open hole. Let sit static 1 hr. Open EDC. Stage pumps to 3 bpm, reduce WH to - 350 psi, no circulation. Diconnect from BHA, pump up to 2 bpm, cyle pipe to 80 k - 15 k lbs. no movement CT depth 10461.6 to 10444.8' 11/5/2018 11/5/2018 2.00 PROD2 DRILL CTOP T Trapped WH of 660 psi, slowly falling, 10,465.0 10,465.0 16:00 18:00 11/5/2018 11/5/2018 1.40 PROD2 DRILL CTOP T Make up and confirm kill fluid is up to 10,465.0 10,465.0 18:00 19:24 weight 11.8 ppg, with added lubes 42 bbl, confirm 100 bbls of kill fluid without 11/5/2018 11/5/2018 0.65 PROD2 DRILL CTOP T Work pipe, unsuccessful 10,465.0 10,465.0 19:24 20:03 11/5/2018 11/5/2018 1.00 PROD2 DRILL CTOP T Pump kill 11.8 ppg kill fluid down back 10,465.0 10,465.0 20:03 21:03 side. 1,800 psi slowly dropping to 992 psi (65 bbls) 11/5/2018 11/5/2018 1.50 PROD2 DRILL CTOP T Pump additional 5 bbis while working 10,465.0 10,465.0 21:03 22:33 pipe -10k -+95k 11/5/2018 1115/2018 0.50 PROD2 DRILL CTOP T Circulate 11.8 ppg tubed kill weight 10,465.0 10,465.0 22:33 23:03 fluid down the coil @ 1.5 bpm 11/5/2018 11/5/2018 0.75 PROD2 DRILL CTOP T Monitor well for flow, work pipe twice 10,465.0 10,465.0 23:03 23:48 with no success. 11/5/2018 11/6/2018 0.20 PROD2 DRILL CTOP T Open 1x2 on pump in sub on RF, 10,465.0 10,465.0 23:48 00:00 monitor well for flow. 11/6/2018 11/6/2018 1.00 PROD2 DRILL CTOP T Fill hole, loss rate 1.2 bbls every hour. 10,465.0 10,465.0 00:00 01:00 SLB on location with hot -tap, run hand thru rig orientation. PJSM 11/6/2018 11/6/2018 0.40 PROD2 DRILL CTOP T PJSM with rig crew on pipe recovery, 10,465.0 10,465.0 01:00 01:24 no flow at surface 11/6/2018 11/6/2018 0.25 PR0D2 DRILL CTOP T 41 k, (no flow) function closed Upper 10,465.0 10,465.0 01:24 01:39 and Lower 2 inch rams, manually lock rams. 11/6/2018 11/6/2018 0.50 PROD2 DRILL CTOP T line up and blow down riser to the pit 10,465.0 10,465.0 01:39 02:09 11/6/2018 11/6/2018 0.50 PROD2 DRILL CTOP T Install pipe slips, dog collar, and dog 10,465.0 10,465.0 02:09 02:39 collar, secure coil at stump 11/6/2018 11/6/2018 1.40 PROD2 DRILL CTOP T PJSM, (no -flow), install hot -tap, drill 10,465.0 10,465.0 02:39 04:03 I hole into coil, monitor flow inside coil, fluiid appears to be high -vis Page 20/39 Report Printed: 1 112 012 01 8 Uperations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tena End Time our (m) Phase Op Code Activity Code Time P -T -x Operation sten Depen (tIKB) End Depm(Po(B) 11/6/2018 11/6/2018 1.50 PROD2 DRILL CTOP T Remove hot -tap, cut coil above 87" 10,465.0 10,465.0 04:03 05:33 from rig floor, install a -line clamp. trim coil to obtain 20' of slack a -line. 11/6/2018 11/6/2018 0.50 PROD2 DRILL CTOP T Install coil clamp, clean and organize 10,465.0 10,465.0 05:33 06:03 RF for changeout 11/6/2018 11/6/2018 6.40 PROD2 DRILL CTOP T Complete change out, discuss path 10,465.0 10,465.0 06:03 12:27 forward, lockout and cut wire at injector, install T bar, take Control of wire at stump, Pull tension, remove lower wire clamp, cut additional tubing to allow space for roll bar to clear while skidding cart. "' note 80" max coil length to clear lower wire grab. Reattach lower wire clamp, skid cart and start installing spoolable connector on injector side of pipe. Install Tbar clamp to wire, RON (30 ton strain gauge) n tugger limited to 5k lbs. Pull tension on a -line, working up in 300 lb increments up to 2700 lbs on the RON, confer with town engineer to pull overworking limit of cable (2700 lbs), and Cable releases at 2950 lbs after -200' slack pulled from coil. Hanging weight of cable after release = 1000 lbs indicating that the cable released at the anchor. •'147.3' of slack pulled" '"Loss rate = 1 bbVhr" 11/6/2018 11/6/2018 1.00 PROD2 DRILL CTOP T SLB a -line on location, discuss plan 10,465.0 10,465.0 1227 13:27 forward, conduct rig orientation and PJSM 11/6/2018 11/6/2018 1.50 PROD2 DRILL CTOP T Spot a -line unit outside ng and R/U 10,465.0 10,465.0 13:27 14:57 equipment to spool CDR3's a -line onto SLB's empty drum 11/6/2018 11/6/2018 1.75 PROD2 DRILL CTOP T Begin pulling a -line cable out of hole, 10,465.0 10,465.0 14:57 16:42 slow down and pull by hand -500 ft from surface 11/6/2018 11/6/2018 1.00 PROD2 DRILL 'TOP T E -line and anchor out of hole, R/D e- 10,465.0 10,465.0 16:42 17:42 line, top off inside of coil with KWF, R/U scaffold 11/6/2018 11/6/2018 0.50 PROD2 DRILL CTOP T Fill coil w/11.8 ppg KWF 10,465.0 10,465.0 17:42 18:12 11/6/2018 11/6/2018 0.50 PROD2 DRILL CTOP T PJSM, with rig and SLB crews 10,465.0 10,465.0 18:12 18:42 11/6/2018 11/6/2018 0.40 PROD2 DRILL CTOP T Spot SLB a -line unit and whale next to 10,465.0 10,465.0 18:42 19:06 rig while installing BOT 5 -pitch CTC and pull test 25 k 11/6/2018 11/6/2018 3.00 PROD2 DRILL CTOP T RU a -line, 10,465.0 10,465.0 19:06 22:06 11/672018 11/6/2018 1.00 PROD2 DRILL CTOP T SLB aline heading up firing head. 10,465.0 10,465.0 22:06 23:06 11/6/2018 11/6/2018 0.40 PROD2 DRILL CTOP T Bring up tools from ground and space 10,465.0 10,465.0 23:06 23:30 out fast line sheave in mast. 11/6/2018 11/6/2018 0.30 PROD2 DRILL CTOP T PU/MU SLB drift (weight bar) 10,465.0 10,465.0 23:30 23:48 11/6/2018 11/7/2018 0.20 PROD2 DRILL CTOP T RIH, pumping 1.0 bpm @ 1,524 psi 10,465.0 10,465.0 23:48 00:00 250', POOH 11/7/2018 11/7/2018 2.00 PROD2 DRILL CTOP T PJSM, notify Caelus, COP Security, 10,465.0 10,465.0 00:00 02:00 and DSO radio silence 11/7/2618 11/7/2018 1.00 PROD2 DRILL CTOP T RIH, pumping 1.0 bpm tripping 150 10,465.0 10,465.0 02:00 03:00 fpm towards bottom 8,050' Page 21139 Report Printed: 1112 0/2 01 8 Operations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time EM Time DW (M Phase Op code Activity Cafe Time P -T-% Operation Start Depth (fixe) EM Depth (flK6) 11/7/2018 11/7/2018 1.20 PROD2 DRILL CTOP T Pull up hole 7,980', SL PUW 946 k, 10,465.0 10,465.0 03:00 04:12 hesitate for fluid movement, fire cutter, indication at surface of full function. RIH to 8,046', POOH 11/7/2018 11/7/2018 0.40 PROD2 DRILL CTOP T PJSM, LD cutter 10,465.0 10,465.0 04:12 04:36 11/7/2018 11/7/2018 3.50 PROD2 DRILL CTOP T RD, pump in sub, 2x2, and XO's, 10,465.0 10,465.0 04:36 08:06 install lifting sub onto 5 pitch CTC, lower traveling blocks, latch up 11/7/2018 11/7/2018 1.25 PROD2 DRILL CTOP T PJSM before pulling on tubing, PU to 10,465.0 10.49'5-0- 08:06 09:21 42K string weight, open up lower pipe rams, open up bleeder valves to confirm zero pressure underneath upper pipe rams, open upper pipe rams and remove slips and dog collar, begin pulling tension on coil, 4 cycles at 60K, 3 cycles at 65K, 3 cycles at 70K, 3 cycles at 75K (60K on CTC due to weight of elevators), pipe still not free. Discuss with town engineer plan forward. 11/7/2018 11/7/2018 2.00 PROD2 DRILL CTOP T Decision made to pump down coil to 10,465.0 10,465.0 09:21 11:21 determine if there is circulation through the cut, bring string weight down to 41.51K, shut upper 2" pipe rams, set slips and dog collar, install XO from Baker lifting sub (2-3/8 8rd EUE to 1502), 2x2 valve. Valves too high to operate from scaffolding so decision made to take Baker lifting sub out of the rig -up to put valves at a safe working height. 11/712018 11/7/2018 0.50 PROD2 DRILL CTOP T Line up to pump down coil taking 10,465.0 10,465.0 11:21 11:51 returns through the drilling choke. Pump 3 bbls at 0.3bpm/650psi, no returns, increase pump rate to 1 bpm/1300 psi and pump an additional 2 bbls for a total of 5 bbls 11.8 KWF, no returns seen at surface 11/7/2018 11/7/2018 0.50 PROD2 DRILL CTOP T Prep rig floor for rigging up SLB a -line, 10,465.0 10,465.0 11:51 12:21 wait on e -line to show up on location after madatory 8 hour rest period. 11/7/2018 11/7/2018 0.75 PROD2 DRILL CTOP T Call for scaffold crew to move 10,465.0 10,465.0 12:21 13:06 scaffolding up 3' due to pipe stretch from pulling tension on coil 11/7/2018 11/7/2018 1.40 PROD2 DRILL CTOP T Make decision to work pipe some 10,465.0 10,465.0 13:06 14:30 more, build scaffold up 3', rig up baker lifting sub 11/7/2018 11/7/2018 1.00 PROD2 DRILL CTOP T Measure rig floor to bottom of CTC 10,465.0 10,465.0 14:30 15:30 (91") prior to working pipe, latch up to liftig sub, open upper pipe rams, pull slips and dog collar, work pipe 7 cycles between 75K and 26K, bring string weight back to 41.51K and measure distance to CTC (72"), indicating that we are still stuck. 11/7/2018 1117/2018 1.20 PROD2 DRILL CTOP T Prep rig floor for a -line operations 10,465.0 10,465.0 15:30 16:42 11/7/2018 11/7/2018 1.50 PROD2 DRILL CTOP T PJSM, call for radio silence, RU and 10,465.0 10,465.0 16:42 18:12 arm cutter, 11/7/2018 11/7/2018 2.00 PROD2 DRILL CTOP T Bring cutter to the floor and MU quick 10,465.0 10,465.0 18:12 20:12 union Page 22139 Report Printed: 11/20/2018 Uperations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time D.,nn Phase Op Code Activity Code Time P -T -X Operation Stall Depth (WB) End Depth(Wtt) 11/7/2018 11/7/2018 0.75 PROD2 DRILL CTOP T RIH, come on line with pump 0.6 bpm 10,465.0 10,465.0 20:12 2057 @ 1,209 psi, 1.0 bpm @ 1600 psi, 5 bbl away, noticed pressure spike to trip at 2,100 psi, shut down pump, check surface lines and line up, surface lines seems to be free, calculate vol from first cut depth (severing head) to top of Nabors CTC, 6.25 bbl, may be the 4" part of the severing head wedged into the BHI upper quick float valves. 11/7/2018 11/8/2018 3.05 PROD2 DRILL CTOP T Continue RIH 100 fpm down to 7,335', 10.465.0 10,465.0 20:57 00:00 PUH and work wire down hole, pressure up in increments 1,000 psi/ bleed, 2,000 psi/bleed, 3,000 psi/bleed, and 4,000' psi/bleed, midnight depth 7,357'. 11/8/2018 11/8/2018 1.75 PROD2 DRILL CTOP T Continue to work eline down hole, 10,465.0 10,465.0 00:00 01:45 pressure up and bleed off, working in stages 1,000 psi, 2,000 psi, 3,000 psi, 4,000 psi, unable to move down hole further, phone town team, decision was made to perfrom cut @ 7,357' 11/8/2018 11/8/2018 2.00 PROD2 DRILL CTOP T After cut, unable to move up or down 10 465.0 10,465.0 01:45 0345 hole with a -line, bring pump up 0.59 bpm at 549 psi returns to surface, worked eline, still unable to move up or down, increase pump rate up to 1.7 bpm at 1,130 psi, pulled eline tools free, continue POOH 11/8/2018 11/8/2018 1.25 PROD2 DRILL CTOP T At 200', call for radio silence, PJSM, 10,465.0 10,465.0 03:45 0500 LD SLB cutter, RD equipment from cut end of coil 11/8/2018 11/8/2018 1.00 PROD2 DRILL CTOP T Bring blocks down and attach to lifting 10 465.0 10,465.0 05:00 0600 sub 11/8/2018 11/8/2018 1.00 PROD2 DRILL CTOP T Latch onto lifting sub, open pipe rams, 10,465.0 7,357.0 06:00 0700 remove slips and dog collar, PU —20' at 37K holding steady, appear to have a good cut, set back down to original depth and set pipe rams, slips, and dog collars 11/8/2018 11/8/2018 3.50 PROD2 DRILL CTOP T Release SLB e -line, RD equipment 7,357.0 7,357.0 07:00 10:30 from cut end of coil, trim coil and dress stump end for spoolable CTC, make up to spoolable connector on injector and downhole side of coil 11/8/2018 11/8/2018 0.50 PROD2 DRILL CTOP T Stab on with injector, test packoffs, 7,357.0 7,357.0 10:30 11:00 pull test connector to 25K 11/8/2018 11/8/2018 1.00 PROD2 DRILL CTOP T POOH slowly 1.5 fpm 30K watch for 7,357.0 7,000.0 11:00 12:00 spoolable connector coming through injector, over horses head, and get 3 wraps on reel with connector 11/8/2018 11/8/2018 2.35 PROD2 DRILL CTOP T Continue POOH slowly at 80 fpm, 7,000.0 500.0 12:00 1421 pumping across the top to keep hole full 11/8/2018 11/8/2018 0.65 PROD2 DRILL CTOP T Flow check, confirm well is dead 500.0 500.0 14:21 15:00 11/8/2018 11/8/2018 0.90 PROD2 DRILL CTOP T Break riser, POOH at 20 fpm until cut 500.0 0.0 15:00 15:54 is seen at surface, cut looks good 11/8/2018 11/8/2018 0.50 PROD2 DRILL CTOP T Slab back on with injector, conduct 0.0 0.0 15:54 1624 PJSM with HAL N2 for reel blowdown, come online with Nitrogen at 1500 scf/min for 8 minutes (11000 set N2 total), observed 15 bbls of KWF returns to the Tiger Tank Page 23139 Report Printed: 11/20/2018 Operations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depth start Tune End Tme Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (WS) End Depth (fiKB) 11/8/2018 11/8/2018 1.50 PROD2 DRILL CTOP T Bleed down N2 from coil and surface 0.0 0.0 16:24 17:54 lines, RD Hal. N2, unstab INJH, install clamp onto free end of coil, skid cart back 11/8/2018 11/8/2018 0.50 PROD2 DRILL CTOP T Cleanup and organize RF 0.0 0.0 17:54 18:24 11/8/2018 11/8/2018 1.20 PROD2 DRILL CTOP P Grease all equipment and Fluid pack 0.0 0.0 18:24 19:36 all lines. Prep RF for testing 11/8/2018 11/8/2018 1.00 PROD2 DRILL CTOP P Obtain shell test, swab leaking by, 0.0 0.0 19:36 20:36 phone out Valve crew, service wellhead valves. 11/8/2018 11/9/2018 3.40 PROD2 DRILL BOPE P Start BOP test, Witness waived by 0.0 0.0 20:36 00:00 Guy Cook, November 08, 2018 @ 15:14 pm, 250 psi low/4,800 psi High/2,500 psi Annular, Test #8 midnight "` Sim -ops: Dress and install graple into free end of coil, remove and pin out counters 11/9/2018 11/9/2018 3.00 PROD2 DRILL BOPE P Continue BOP lest, Witness waived by 0.0 0.0 00:00 03:00 Guy Cook, November 08, 2018 15:14 pm, 250 psi low/4,800 psi High/2,500 psi Annular, Test #8 - 14 "` Sim -ops: remove inner reel iron 11/9/2018 11/9/2018 0.50 PROD2 DRILL BOPE P Test #14-15, perform drawdown test 0.0 0.0 03:00 03:30 (7.0 hr test) 11/9/2018 11/9/2018 4.00 PROD2 DRILL CTOP T Continue Reel Swap, remove 0.0 0.0 03:30 07:30 counters, rig down inner reel iron and bulkhead, install grapple 11/9/2018 11/9/2018 2.50 PROD2 DRILL CTOP T Pull test grapple, PJSM for 0.0 0.0 07:30 10:00 unstabbing, unstab coil tubing 11/9/2018 11/9/2018 1.25 PROD2 DRILL CTOP T Position reel, RU shackles and slings, 0.0 0.0 10:00 11:15 remove saddle clamps, open back doors 11/9/2018 11/9/2018 1.00 PROD2 DRILL CTOP T Load old reel onto Peak truck, pick up 0.0 0.0 11:15 12:15 reel #52348 and load onto rig 11/9/2018 11/9/2018 5.75 PROD2 DRILL CTOP T position and secure new reel, install 0.0 0.0 12:15 18:00 new stripper brass, install inner reel iron, make up and pull test grapple 11/9/2018 11/9/2018 2.50 PROD2 DRILL CTOP T Crew Change, PJSM, install new 0.0 0.0 18:00 20:30 stripper and secure to INJH, inspect, adjust, and secure inner reel iron 11/9/2018 11/9/2018 1.50 PROM DRILL CTOP T Install and pull test grapple, re -lighten 0.0 0.0 20:30 22:00 grapple, remove all banding and shipping material from reel 11/9/2018 11/9/2018 1.25 PROD2 DRILL CTOP T PJSM, stab coiled tubing into INJH 0.0 0.0 22:00 23:15 11/9/2018 11/10/2018 0.75 PROD2 DRILL CTOP T Prep free end of coiled tubing for CTC 0.0 0.0 23:15 00:00 installation Sim -ops: PJSM, blow air thru CSL, RU little red services to CSL, 11/10/2018 11/10/2018 0.80 PROM DRILL CTOP T Continue MU new coiled tubing 0.0 0.0 00:00 00:48 reel.load 5 bbl of meothonal into reel, dress free end of coiled tubing for CTC, pull lest 35 k (good -test) 11/1012018 11/10/2018 1.00 PROD2 DRILL CTOP T Head up BHI upper quick connect, 0.0 0.0 00:48 01:48 (good -test), >2000165. install nozzle 11/10/2018 11/10/2018 2.00 PROD2 DRILL CTOP T Slide cart forward, stab onto stump, 0.0 0.0 01:48 03:48 follow meothanol with fresh water, taking returns to kill tank. Page 24139 Report Printed: 11/20/2018 Summary (with Timelog Depths) 3H -13A lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth start rime End Tana Du, (hr) Phase Op Code AcIPoiry Code T ne P -T -X Operation (ftKB) End Depth (ftKB) 11/10/2018 11/10/2018 1.20 PROD2 DRILL CTOP T Line up to test inner reel valve and 0.0 0.0 03:48 05:00 pac-off 250 psi low/4,800 psi high 11/10/2018 11/10/2018 2.50 SLOT WELLPR PULD T PU/MU cleanout BHA #15 0.0 62.4 05:00 07:30 11/10/2018 11/10/2018 1.55 SLOT WELLPR TRIP T RIH with cleanout BHA#15, pumping 62.4 7,060.0 07:30 09:03 11.8 KWF at 1 BPM IA/OA = 657psi/509psi 11/10/2018 11/10/2018 0.15 SLOT WELLPR DLOG T Log Kt, +19' correction 7,060.0 7,088.0 09:03 09:12 11/10/2018 11/10/2018 0.30 SLOT WELLPR TRIP T Continue to RIH, Wt Chk at 7100'= 7,088.0 7,340.0 09:12 09:30 30K, slow down and tum around at 7340', did not stack out on whipstock or stuck end of coil 11/10/2018 11110/2018 1.50 SLOT WELLPR CIRC T PUH to new TOWS depth 7315' and 7,340.0 7,315.0 09:30 11:00 displace well to 8.6 ppg Power Pro 11/10/2018 11110/2018 2.00 SLOT WELLPR CIRC T On bottom, recip pipe and clean hole 7,315.0 7,315.0 11:00 13:00 pumping 1.8 BPM, drop rate to 1.6 BPM for 15 minutes to calibrate choke, continue to recip pipe while building sweeps in mud pits, circ=3800 psi diff -400 psi IA=669 OA=569 1111012018 11/10/2018 2.25 SLOT WELLPR CIRC T POOH pumping with 1.8 BPM, making 7,315.0 62.4 13:00 15:15 multiple logging passes and pumping three 5x5 sweeps 11/10/2018 11/10/2018 1.60 SLOT WELLPR PULD T PUD BHA#15, WHP=775 psi 62.4 0.0 15:15 1651 11/10/2018 11110/2018 1.30 PROD1 RPEQPT PULD T PD, WS setting BHA 0.0 73.6 16:51 18:09 11/10/2018 11/10/2018 1.50 PROD1 RPEQPT TRIP T RIH, with WS settling BHA#16, 3-1/2" 73.6 7,090.0 18:09 1939 Monobore XL Whipstock 11/10/2018 11/10/2018 0.20 PROM RPEQPT DLOG T Log the K1 marker correction of minus 7,090.0 7,128.8 19:39 19:51 6.0' 11/10/2018 11/10/2018 0.20 PROD1 RPEQPT DLOG T Continue IH to setting depth, close 7,128.8 7,325.5 19:51 20:03 EDC 11/10/2018 11/10/2018 0.15 PROD1 RPEQPT DLOG T 7,315', (Anchor @ 0" HS), PUW 35 k, 7,325.5 7,315.0 20:03 20:12 RBIH to setting depth, PUW 32 k, bring pump up to shear 5,400 psi, set down 5.5 k DHWOB, PUW 35 k 11/10/2018 11/10/2018 1.50 PROD1 RPEQPT TRIP T POOH, pumping 1.2 bpm at 2,775 psi 7,315.0 73.6 20:12 21:42 11/10/2018 11/10/2018 1.00 PROD1 RPEQPT PULD T PUD, WS setting tools 73.6 0.0 21:42 22:42 11/10/2018 11/11/2018 1.30 PROD1 WHPST PULD T PD, Window milling assembly 0.0 74.3 22:42 0000 11/11/2018 11/11/2018 1.40 PROD1 WHPST TRIP T RIH, w/window milling assembly 0.6° 74.3 7,090.0 00:00 01:24 ako motor, re -run string reamer (run#6) 2.80"OD and new DSM 2.80"OD 11/11/2018 11/11/2018 0.20 PROM WHPST DLOG T Log the K1 marker correction of minus 7,090.0 7,128.0 01:24 01:36 1 1 16.5' 11/11/2018 11/11/2018 0.30 PROD1 WHPST TRIP T Continue IH 7,128.0 7,315.0 01:36 01:54 11/11/2018 11/11/2018 0.10 PROM WHPST WPST T Dry tag TOWS @ 7,315', PUW 35 k 7,315.0 7,315.0 01:54 02:00 11/11/2018 11/11/2018 5.00 PROD1 WHPST WPST T Bring pump online @ 1.7 bpm @ 7,315.0 7,318.0 02:00 07:00 4,056 psi, Diff -530, WHP=325, BHP=3,651, IA=659, OA=533 11/11/2018 11/11/2018 2.00 PROD1 WHPST WPST T Continue milling window @ 1.9 7,318.0 7,321.0 07:00 09:00 BPM/4120 psi, WHP=310 psi, Diff -650 psi, BHP=3630 psi, IA/OA=683/632, WOB=1500 lbs Page 25139 Report Printed: 11/2012018 Operations Summary (with Timelog Depths) 3H-13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Actively Code Time P-T-X Operation Start Depth (MB) End Depth (flKB) 11/11/2018 11/11/2018 1.75 PROD1 WHPST WPST T Continue milling window @ 1.9 7,321.0 7,325.0 09:00 10:45 BPM/4020psi, WOB drops to 1030 lbs, T/110=313/690/669, Diff=610, BHP=4245 11111/2018 11/11/2018 2.00 PROD1 WHPST WPST T Through window, mill 11' of rathole. 7,325.0 7,336.0 10:45 12:45 1.9BPM, circ=4200psi, Diff=750psi, WOB=2300lbs, BHP=4400psi, T/110=337/692/688 11/11/2018 11/1112018 2.40 PROD1 WHPST REAM T Dress window, make 5 reaming 7,336.0 7,315.0 12:45 15:09 passes at 1 fpm, 2 at as drilled TF, 30° ROHS, 30° LOHS, and 180° ROHS, come offline with pumps and dry drift window, clean. 11/11/2018 11/11/2018 1.60 PROD1 WHPST TRIP T Open EDC and POOH pumping 1.9 7,315.0 74.3 15:09 16:45 BPM 11111/2018 11/1112018 1.25 PRODt WHPST PULD T At surface, spaceout, PUD milling 74.3 0.0 16:45 18:00 BHA #17 "' Note: Mills gauged 2.80 no-go 11/11/2018 11/11/2018 1.00 PROD1 DRILL PULD T PD, pre-loaded Build assembly 0.0 72.2 18:00 19:00 11/11/2018 11/11/2018 1.30 PROD1 DRILL TRIP T Tag up, reset counters, RIH w/ Build 72.2 7,080.0 19:00 20:18 BHA#18, 2.5° ako, P104 bi-center bit 11/11/2018 11/11/2018 0.20 PRODi DRILL DLOG T Log the K1 marker correction of minus 7,080.0 7,108.3 20:18 20:30 5.5' 11/11/2018 11111/2018 0.30 PROD1 DRILL TRIP T Continue IH to bottom, dose EDC, 7,108.3 7,336.0 20:30 20:48 PUW 36 k 11/11/2018 11/11/2018 0.70 PROD1 DRILL DRLG T OBD, 1.9 bpm at 4,100 psi, Diff=600 7,336.0 7,423.0 20:48 21:30 psi, BHP=3,710, WHP=335, IA=691, OA=638 11/11/2018 11/11/2018 0.20 PROD1 DRILL WPRT T Short wiper up hole, PUW 37 k 7,423.0 7,090.0 21:30 21:42 11/11/2018 11/11/2018 0.20 PRODi DRILL DLOG T Log the K1 marker no correction, 7,090.0 7,335.0 21:42 21:54 continue IH log the RA marker, PUW 37 k - Note: Offical Window Depths TOWS=7,315' BOW=7,320' RA Marker=7321' 11/11/2018 11/1112018 0.20 PROD1 DRILL WPRT T Continue IH 7,335.0 7,423.0 21:54 22:06 11/11/2018 11/12/2018 1.90 PROD1 DRILL DRLG T BOBD, 1.9 bpm at 4,086 psi, Diff=515 7,423.0 7,616.0 22:06 00:00 psi, WHP=298, BHP=3,706, IA=694, OA=673 11/12/2018 11/12/2018 2.20 PROD1 DRILL DRLG T OBD, 1.9 bpm at 4,181 psi, D1ff=530 7,616.0 7,760.0 00:00 02:12 psi, WHP=323, BHP=3,666, IA=688, OA=649 "` Note: New mud at the bit Q 7,620' 11/12/2018 11/1212018 1.50 PRODi DRILL TRIP T POOH 7,760.0 78.3 02:12 03:42 11/12/2018 11/12/2018 1.25 PROD1 DRILL PULD T At surface, space out, PUD build 78.3 0.0 03:42 04:57 assembly 11/12/2018 11/12/2018 1.25 PROD1 DRILL PULD T Makeup and PD AL1 lateral drilling 0.0 78.3 04:57 06:12 BHA#19 11/1212018 11/12/2018 1.50 PROD1 DRILL TRIP T RIH 78.3 7,073.0 06:12 07:42 11/12/2018 11/12/2018 0.20 PROD1 DRILL DLOG T Log K1, -7.5' correction 7,073.0 7,117.0 07:42 07:54 11/12/2018 11/12/2018 0.30 PROD1 DRILL TRIP T wt check @7100'=34K, continue to 7,117.0 7,760.0 07:54 08:12 RIH to build TD Page 26139 Report Printed: 11/2012018 Operations Summary (with Timelog [Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our inn Phase Op Code Activit' Code Time P -T -X Operation Start Depth (MB) End Depth (M(13) 11/12/2018 11/12/2018 0.40 PROD? DRILL DRLG T Record free spin, diff --1 671 psi, reset 7,760.0 7,827.0 08:12 08:36 WOB and tag build TD at 7660', drill ahead, WOB=2700 lbs, Diff=1820 psi, cirp5546 psi, BHP=5734 psi, T/1/0=336/681/552, wt check @7764'=35K 11/12/2018 11/12/2018 0.20 PROD1 DRILL WPRT T Returns drop off to 0.4 BPM (pumping 7,827.0 7,804.0 08:36 08:48 1.9 BPM), PUH to 7804' PUW=35K 11/12/2018 11/12/2018 0.10 PROD1 DRILL WPRT T RBIH 7,804.0 7,827.0 08:48 08:54 11/12/2018 11/12/2018 0.10 PROD1 DRILL DRLG T OBD, lose returns ay 7864' 7,827.0 7,864.0 08:54 09:00 11/12/2018 11/12/2018 0.10 PROD1 DRILL WPRT T Pick up to above 7827'to let losses 7,864.0 7,827.0 09:00 09:06 heal, PUW=39K 11/12/2018 11/12/2018 0.10 PROM DRILL WPRT T RBIH 7,827.0 7,864.0 09:06 09:12 11112/2018 11/12/2018 0.10 PROD1 DRILL DRLG T OBD, plan for wipers to end of build 7,864.0 7,900.0 09:12 0918 every 100' 11/12/2018 11/12/2018 0.05 PROM DRILL WPRT T Wiper to EOB, PUW=38K 7,900.0 7,772.0 09:18 09:21 11/1212018 11/12/2018 0.05 PROD1 DRILL WPRT T RBIH 7,772.0 7,900.0 09:21 09:24 11/12/2018 11/1212018 0.60 PROD1 DRILL DRLG T OBD, WOB=16001bs, circ --5440 psi, 7,900.0 8,000.0 09:24 10:00 diff --1850 psi, BHP=5600 psi, T/1/0=310/684/588 11/12/2018 11/12/2018 0.10 PROD1 DRILL WPRT T Wiper trip to End of Build, PUW=38K 8,000.0 7,766.0 10:00 10:06 11/12/2018 11/1212018 0.10 PROM DRILL WPRT T RBIH 7,766.0 8,000.0 10:06 10:12 11/12/2018 11/12/2018 3.50 PROD1 DRILL DRLG T OBD, performing BHA wipers every 8,000.0 8,400.0 10:12 13:42 100' drilled, 1.9 BPM @ 5512 psi, Diff=2035 psi, BHP=5755 psi, T/1/0=3071687/602, WOB=2520 lbs, PUW=37K@8100', 37K@8200', 40K@8358' 1111212018 11112/2018 0.25 PROD1 DRILL WPRT T Wiper trip to EOB 7770', PUW=40K 8,400.0 7,770.0 13:42 13:57 11/12/2018 11/1212018 0.35 PROD1 DRILL WPRT T RBIH, set down 1400 Ibis WOB at 7,770.0 8,400.0 13:57 14:18 8300' MD (near end of high GR section), PU 10' and RBIH no problem 11/1212018 11112/2018 3.00 PROD1 DRILL DRLG T OBD at 1.9 BPM/5634 psi, 8,400.0 8,810.0 14:18 17:18 WOB=2510 lbs, Diff -1951 psi, BHP=5731 psi, T/1/0=277/6971673, pull BHA wipers every 100', PUW's=37K@8505', 38K@8600', 38K@8700' 11/12/2018 11/1212018 0.87 PRODi DRILL WPRT T Wiper up hole to the window, PUW 38 8,810.0 7,336.0 17:18 18:10 1 k 11/12/2018 11/12/2018 0.20 PROM DRILL DLOG T Log the RA marker correction of plus 7,336.0 7,363.0 18:10 18:22 2.5' 1111212018 1111212018 0.65 PROM DRILL WPRT T Wiper back in hole, RIW 10 k, 8,200' 7,363.0 8,749.0 18:22 19:01 notice pump (bore) pressure climbing, continue IH, attempt to bring pump rate up to drilling rate, 1.53 bpm at 2000 psi Diff. 11/12/2018 11/12/2018 2.80 PROD1 DRILL TRIP T POOH, to inspect BHA (agitator), 8,749.0 78.2 19:01 21:49 performing Jog above window, and @ 1,990' (700'), Page 27139 ReportPrinted: 11/20/2018 Uperations Summary (with Timelog Depths) 3H -13A 16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Statl Time End Time Dur (hr) Phase Op Cotle Activity Cotle Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 11/12/2018 11/12/2018 1.69 PRODi DRILL PULD T At surface, space out, PUD drilling 78.2 0.0 21:49 23:30 BHA#19 "' Note: Found Lower Bearing housing on mud motor had backed completly off. 11/12/2018 11/13/2018 0.49 PRODt DRILL PULD T PD, All lateral drilling BHA#20 0.0 78.2 23:30 00:00 11/13/2018 11/13/2018 1.00 PRODi DRILL PULD T Finish PD lateral drilling BHA #20 78.2 78.2 00:00 01:00 11/13/2018 11/13/2018 1.60 PROW DRILL TRIP T RIH, with AL1 lateral drilling BHA#20, 78.2 7,090.0 01:00 02:36 0.5° ako, RR bi-center bit, surface test agitator @ 517' (good -test) 11/13/2018 11/13/2018 0.20 PR0D1 DRILL DLOG T Log the K1 correction of minus 5.5', 7,090.0 7,128.0 02:36 02:48 PUW 37 k *** Note: 7.5 him NPT (BHI) 11/13/2018 11/13/2018 0.65 PROD1 DRILL TRIP T Continue IH, setting down Q 8,228', 7,128.0 8,296.0 02:48 03:27 PUW 38 k, lower pump rate RBIH, clean pass spot brought pump back up to 1.5 bpm, set down again at DTF 8,296', PUW 50k, -6 k DHWOB, continued up hole, seeing drag -1.1 k- 3.2 k, 11/13/2018 11/13/2018 1.20 PROD1 DRILL WPRT T Continue PUH, pumping bottoms up, 8,296.0 7,605.0 03:27 04:39 sand in sample (no -rocks), make call Ito TT. 11/13/2018 11/13/2018 0.30 PROD1 DRILL WPRT T RBIH to 8,200', line up and pump 5x5 7,605.0 8,200.0 04:39 04:57 sweep Wow 11/13/2018 11/1312018 1.00 PRODi DRILL WPRT T Chase sweep to surface 8,200.0 5,500.0 04:57 05:57 11/13/2018 11/13/2018 1.20 PR0D1 DRILL TRIP T RBIH, log K1 +2' correction, set down 5,500.0 8,254.0 05:57 07:09 @ 8222' WOB=2K PUW=38K, pull up 50' and RIH, set down @ 8254' WOB=3.1K PUW=38K, pick up 100' and RIH again, set down (418212' WOB=3.5K PUW=45K, pick up 40' and RBIH, set down (a1 8245' WOB=2.6K PUW=38K 11/13/2018 11/13/2018 0.30 PROD1 DRILL WPRT T PUH and confer with Town Engineer 8,254.0 7,342.0 07:09 07:27 11/13/2018 11/13/2018 0.20 PROD1 DRILL WPRT T RBIH to a cleanout depth of 8100' 7,342.0 8,100.0 07:27 07:39 11/13/2018 11/13/2018 3.20 PROD1 DRILL WPRT T Cleanout hole from 8100' pumping 4 8,100.0 78.2 07:39 10:51 5x5 sweeps and making multiple jogs in on way out of hole, HOT tool cutting out on way out of hole, will inspect at surface and run new BHA 11/13/2018 11/13/2018 1.10 PROD? DRILL PULD T Tag up, PUDALI lateral drilling BHA 78.2 0.0 10:51 11:57 #20 11/13/2018 11/13/2618 1.50 PROD1 STK PULD T Make up and PD aluminum billet 0.0 73.4 11:57 13:27 WOH Anchor BHA #21 11/13/2018 11/13/2018 1.40 PR0D1 STK TRIP T RIH with BHA#21 @ 80 fpm _w/EDC in 73.4 7,054.0 13:27 14:51 Open position, slow down through window, build, and openhole sections 11/13/2018 11/13/2018 0.20 PRODi STK BLDG T Log K1, -7' correction 7,054.0 7,120.0 14:51 15:03 11/13/2018 11/13/2018 0.40 PRODt STK TRIP T RIH to 8011.78' and pull slack out of 7,120.0 8,011.8 15:03 15:27 coil to set Top of Billet at 8000' Page 28139 Report Printed: 11/20/2018 Operations Summary (with Timelog Depths) 3H-13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log StaM1Time EM Time Dur (Ar) Phase Op Cade Activity Code Time P-T-X Operation Stan Depth (WB) End DepM(ftKB) 11/1312018 11/13/2018 0.20 PROD1 STK WPST T PUW=34K pre-set, close EDC and 8,011.8 8,011.8 15:27 15:39 come online w/pumps, sheared at 5166 psi / 1.2 BPM (Diff-1500 psi), set down 3600 lbs to confirm Openhole Anchored Billet is set. 11/13/2018 11113/2018 1.50 PROM STK TRIP T POOH 8,011.8 61.7 15:39 17:09 11/1312018 11/13/2018 2.00 PRODi STK PULD T PUD, setting tools, crew change, 61.7 0.0 17:09 19:09 PJSM, swap out tools, PU motor and agitator, LD MWD tool, PU Res tool, MU HOT-FVS, scribe to motor. 11/13/2018 11/13/2018 1.00 PROM STK PULD T PD, kickoff/drilling BHA, MU to upper 0.0 78.3 19:09 20:09 quick, surface test (good-test), MU INJH, tag up, re-set counter depths, check pac-offs (good) 11/1312018 11113/2018 1.25 PROD1 STK TRIP T RIH, w/kickoff/drilling BHA#22, 78.3 7,090.0 20:09 21:24 •" Note: Test agitator 1.5 bpm @ 4,141 psi, and 1.9 bpm @ 5,100 psi 11113/2018 11/13/2018 0.20 PROD1 STK DLOG T Log the K1 marker correction of minus 7,090.0 7,128.0 21:24 21:36 7.5', PUW 34 k 11/13/2018 11/13/2018 0.50 PRODi STK TRIP T Continue IH, dry tag TOB @ 8,000', 7,128.0 8,000.0 21:36 22:06 2.5k DHWOB, PUW 35 k 11113/2018 11/13/2018 0.13 PROD1 STK KOST T PUH, obtain ddlliing parameters, 1.9 8,000.0 7,999.0 22:06 22:13 bpm at 5,082 psi, Diff-1,215 psi, WHP=256, BHP=3,725, IA=698, OA=645 11/13/2018 11/13/2018 0.80 PROD1 STK KOST T Kickoff billet @ time drilling @ 1 ft/hr 7,999.0 8,000.2 22:13 23:01 11/13/2618 11/1312018 0.60 PROM STK KOST T Kickoff billet @ time drilling @ 2 ft/hr 8,000.2 8,001.2 23:01 23:37 11/1312018 11/13/2018 0.20 PROD1 STK KOST T Kickoff billet @ fime drilling @ 3 ft/hr 8,001.2 8,001.9 23:37 23:49 11/13/2018 11/1412018 0.17 PROD1 DRILL DRLG T Drill ahead @ 1 k DHWOB 8,001.9 8,011.0 23:49 00:00 11/1412018 11/14/2018 0.67 PROD1 DRILL DRLG T Drilling Ahead, 1.9 bpm at 5,082 psi, 8,011.0 8,124.0 00:00 00:40 Diff--1,215 psi, WHP=189, BHP=3,748, IA=698, OA=648 DHWOB=2.0 k CTSW=11.0 k 11/14/2018 11/14/2018 0.10 PROD1 DRILL WPRT T PUH, dry drift kickoff point (dean) , 8,124.0 7,970.0 00:40 00:46 PUW 35 k 11/14/2018 11/14/2018 0.10 PROD1 DRILL WPRT T Wiper back in hole, RIW 12 k 7,970.0 8,124.0 00:46 00:52 11/14/2018 11/1412018 1.30 PROD1 DRILL DRLG T OBD, 1.9 bpm at 5,115 psi, Diff=1,215, 8,124.0 8,350.0 00:52 02:10 WHP=213, BHP=3,747, IA=698, OA=649 DHWOB=1.9-2.4 k CTSW=8-12 k 11/14/2018 11/14/2018 0.20 PROD1 DRILL WPRT T Wiper up hole, PUW 38 k 8,350.0 8,080.0 02:10 02:22 11/14/2018 11/14/2018 0.20 PROD1 DRILL WPRT T Wiper back in hole, RIW 12 k 8,080.0 8,350.0 02:22 02:34 11/1412018 11114/2018 1.35 PRODt DRILL DRLG T BOBD, 1.9 bpm at 4,962 psi, 8,350.0 8,550.0 02:34 03:55 Diff--11,155 psi, WHP=210, BHP=3,789, IA=701, OA=671 DHWOB=2.5 k CTSW=9.0 k Page 29/39 Report Printed: 11120-120-181 Uperations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stars Time I End Time Dur (hr) Phase Op Code Activity ity Code Time P -T -X Operation Depth (ftKB) End Depth(ftKS) 11/14/2018 11/14/2018 0.15 PRODi DRILL WPRT T 100' Wiper up hole, PUW 40 k 8,550.0 8,550.0 03:55 04:04 11/14/2018 11/14/2018 1.50 PROD1 DRILL DRLG T OBD, 1.9 bpm at 5,114 psi, 8,550.0 8,780.0 04:04 05:34 BHP=3,787, WHP=207, IA=702, OA=671 DHWOB=2.1 k CTSW=8.0 k 11/14/2018 11/14/2018 0.30 PROD1 DRILL WPRT T Wiper up hole, PUW 35K 8,780.0 8,035.0 05:34 0552 11/14/2018 11/14/2018 0.20 PROD1 DRILL WPRT T Wiper back in hole, RIW 12K 8,035.0 8,780.0 05:52 0604 11/14/2018 11/14/2018 0.70 PROD1 DRILL DRLG T BOBD, 1.9 bpm at 5650 psi, 8,780.0 8,880.0 06:04 06:46 Diff=1,670 psi, WHP=210, BHP=5470 DHWOB=2.5 k 11/14/2018 11/14/2018 0.10 PROD1 DRILL DRLG T 100' wiper up hole, PUW=40K 8,880.0 8,880.0 06:46 06:52 11/14/2018 11/14/2018 0.80 PROD? DRILL DRLG T BOBD, 1.9 bpm at 5419 psi, Diff=1490 8,880.0 8,980.0 06:52 07:40 psi, 'AiBHP=5289, IA=703, OA=693 DHWOB=2.1 K 11/14/2018 11/14/2018 0.10 PROD1 DRILL WPRT T 100'wiper up hole, PUW=35K 1 8,980.0 07:40 07:46 11/14/2018 11/14/2018 0.50 PROD1 DRILL DRLG T OBD, 1.9 BPM @ 5583 psi, Diff=1564 8,980.0 9,080.0 07:46 08:16 psi, WHP=219, BHP=5412, IA=703, OA693 WOB=2.1 K 11/14/2018 11/14/2018 0.10 PROD1 DRILL WPRT T 100'wiper up hole, PUW=35K 9,080.0 9,080.0 08:16 08:22 11/14/2018 11/14/2018 1.50 PROD1 DRILL DRLG T OBD, 1.9 BPM @ 5584 psi, Diff=1561 9,080.0 9,190.0 08:22 09:52 psi, WHP=233 psi, BHP=5362 psi, IA=703, OA=697 WOB=2.2K 11/14/2018 11!14/2018 0.80 PROD1 DRILL WPRT T Window Wiper, PUW=38K 9,190.0 7,334.0 09:52 10:40 11/14/2018 11/14/2018 0.70 PROD1 DRILL WPRT T Wiper back in hole, RIW=12K 7,334.0 9,190.0 10:40 11122 11/14/2018 11/14/2018 0.50 PROD1 DRILL DREG T OBD, 1.9 BPM @ 5619, Diff=1550, 9,190.0 9,290.0 11:22 11:52 BHP=5349 WOB=1540 lbs HKLD=2K "Mud Swap: Begin pumping new mud at 9262'" 11/14/2018 11/14/2018 0.10 PROD1 DRILL WPRT T BHA Wiper 1 00'up hole, PUW=36K 9,290.0 9,290.0 11:52 11:58 11/14/2018 11/14/2018 0.60 PROD1 DRILL DRLG T OBD, 1.9 BPM @ 4920 psi, 9,290.0 9,390.0 11:58 12:34 Diff=1102psi, WHP=289, BHP=4863, IA=697, OA=664 WOB=2.3K 11/14/2018 11/14/2018 0.10 PROD1 DRILL WPRT T 100' wiper uphole, PUW=36K 9,390.0 9,390.0 12:34 12:40 11/14/2018 11/14/2018 0.80 PROD1 DRILL DRLG T OBD, 1.9 BPM @ 5270 psi, Diff=1511, 9,390.0 9,490.0 12:40 1328 WHP=321, BHP=5346, IA=696, OA=655, WOB=2.5K 11/14/2018 11/14/2018 0.10 PROD1 DRILL WPRT T 100'wiper uphole, PUW=39K 9490.0 9,490,6- 13:28 1334 Page 30139 Report Printed: 11/20/2018 Uperations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth start Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth(ftKB) 11/14/2018 11/14/2018 0.80 PROD1 DRILL DRLG T OBD, 1.9 BPM @ 5127 psi, Diff -1302, 9,490.0 9,590.0 13:34 14:22 WHP=306, BHP=5229, IA=695, OA=629, WOB=2.2K 11/14/2018 11/14/2018 0.20 PROD1 DRILL WPRT T Wiper trip, PUW=38K 9,590.0 8,590.0 14:22 1434 11/14/2018 11/14/2018 0.30 PROD1 DRILL WPRT T RBIH 6,590.0 9,590.0 1434 1452 11/14/2018 11/14/2018 1.30 PROD1 DRILL DRLG T BOBD, 1.9 BPM @ 5301 psi, 9.590.0 9,741.0 1452 1610 Diff --1450, WHP=299, BHP=5332, IA=694, OA=11, WOB=2.4K MWD tools acting up @ 9671' (DGS, HOT, DPS, RES all intermittent, continue drilling ahead) 11/14/2018 11/14/2018 2.25 PRODt DRILL TRIP T Decision made to POOH to inspect 9,741.0 78.3 16:10 18:25 and changeout BHA, PUW=38K 11/14/2018 11/1412018 2.20 PROD1 DRILL PULD T PJSM, Driller side PDL froze„ work SL 78.3 0.0 18:25 20:37 free, PUD, AL1 drilling BHA#22 11/142018 11/14/2018 1.70 PROD? DRILL PULD T PD preloaded tools, AL1 drilling BHA 0.0 78.3 20:37 22:19 #23, PU/MU INJH to BHI tools, perfom sufaoe test (ggod-test), continue onto stabbing the INJH, space out, re -set depths 11/14/2018 11/14/2018 1.35 PROD1 DRILL TRIP T RIH w/AL1 drilling assembly 0.5°- ako 78.3 7,090.0 22:19 23:40 1 1 1 motor, and RR bi-center bit. 11114/2018 11/14/2018 0.20 PROD1 DRILL DLOG T Log the K1 marker correction of minus 7,090.0 7,128.0 23:40 23:52 5.5' 11/14/2018 11/152018 0.13 PROD1 DRILL TRIP T Continue IH 7,128.0 7,430.0 23:52 00:00 Nole:7.3 hrs NPT (BHI) 11/15/2018 11/15/2018 0.80 PROD1 DRILL TRIP T Continue IH 7,430.0 9,741.0 00:00 00:48 11/15/2018 11/15/2018 1.00 PRODi DRILL DRLG T BOBD, 1.9 bpm at 4,944 psi, 9,741.0 9,897.0 00:48 01:48 Diff -1,096 psi, WHP=332, BHP=3,882, IA=692, OA=594 11/15/2018 11/152018 0.10 PROD1 DRILL WPRT T 100' BHA wiper up hole, PUW 9,897.0 9,812.0 01:48 01:54 11/15/2018 11/15/2018 0.10 PROD1 DRILL WPRT T Wiper back in hole, RIW 9.4 k 9,812.0 9,897.0 01:54 02:00 11/15/2018 11/15/2018 1.25 PROD1 DRILL DRLG T BOBD, 1.9 bpm at 4,944 psi, 9,897.0 10,100.0 02:00 03:15 Diff --1,096 psi, WHP=332, BHP=3,882, IA=692, OA=594 11/15/2018 11/15/2018 1.10 PROD1 DRILL WPRT T TO 10,100', chase 5x5 to window 10,100.0 7,315.0 03:15 04:21 11/152018 111152018 1.60 PROD1 DRILL WPRT T Continue wiper to the swab valve, 7,315.0 69.5 04:21 05:57 PUW 35 k, performing jogs @ 5,000', 1,500', and 500' 11/152018 11/15/2018 1.30 PROD1 DRILL TRIP T Trip back in hole 69.5 7,000.0 05:57 07:15 11/15/2018 11/15/2018 0.10 PRODi DRILL DLOG T Log Ki, +27' correction 7,000.0 7,113.0 07:15 07:21 11/15/2018 11/15/2018 0.40 PROM DRILL DLOG T Perform static pressure survey above 7,113.0 7,300.0 07:21 07:45 the window, trap 11.8 ppg and falls off to 11.6 ppg in 14 minutes 11/152018 11/15/2018 0.10 PROM DRILL DLOG T Continue to RIH, log RA, no 7,300.0 7,361.0 07:45 07:51 correction, 11/15/2018 11/15/2018 1.00 PROD1 DRILL TRIP T RIH, confirm TO at 10,100', PUW=33K 7,361.0 10,100.0 07:51 08:51 11/15/2018 11/15/2018 1.10 PROD1 DRILL DISP T Circulate off bottom while weighting up 10,100.0 10,100.0 08:51 09:57 liner running pill, 1.55 BPM @ 4050 psi Page 31139 Report Printed: 1 112 012 01 8 Uperations Summary (with Timelog Depths) 3H-13A I& Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log I rt Depth Stan Time End TimeSta Dur (hr) Phase Cp Code Adwdy Code Time P-T-X Operation (ft B) End Depth (WB) 11/15/2018 11/15/2018 1.50 PROD1 DRILL DISP T Lay in 11.8 ppg NaBR liner running pill 10,100.0 6,000.0 09:57 11:27 with 2 ppb alpine beads (52 BBLS), paint TD flag at 8633.4' and 11/15/2018 11/15/2018 1.20 PROD1 DRILL DISP T Continue POOH laying in 11.8 ppg 6,000.0 78.3 11:27 12:39 NaBR completion fluid, paint window flag @ 5778.3' 11/15/2018 11/15/2018 0.60 PROD1 DRILL DISP T Flow check well to confirm killed, 78.3 78.3 12:39 13:15 SIMOPS: PJSM for running liner 11/15/2018 11/15/2018 0.50 PRODt DRILL PULD T Lay down BHA#23 78.3 0.0 13:15 13:45 11/15/2018 11/15/2018 0.70 PROD1 CASING PUTB T Prep rig floor for running liner 0.0 0.0 13:45 14:27 11/15/2018 11/15/2018 2.00 PROD1 CASING PUTS T Make up Non=ported bullnose, 47 0.0 1,495.8 14:27 16:27 joints of 2-3/8" 4.7# L-80 ST-L Slotted Liner, and shorty deployment sleeve 11/15/2018 11/15/2018 1.40 PROD1 CASING PULD T Pick up coil track tools for liner running 1,495.8 1,540.0 16:27 17:51 BHA #24 11/15/2018 11/15/2018 1.00 PRODi CASING RUNL T RIH with lower liner segment 1,540.0 7,240.0 17:51 18:51 11/15/2018 11/15/2018 0.50 PROD1 CASING RUNL T Come online with pumps, continue 7,240.0 8,420.0 18:51 19:21 RIH, HKLD=I9K 11/15/2018 11/15/2018 0.10 PROD1 CASING DLOG T slow down to log K1, O' correction 8,545.0 8,603.0 19:21 1927 11/15/2018 11/15/2018 0.70 PROD1 CASING RUNL T continue in hole, work liner down from 8,603.0 10,100.0 19:27 20:09 8603' to 8805' making multiple pickups, weight starts to come back and continue RIH at 50 fpm, 14K HKLD 11/15/2018 11/15/2018 0.10 PROD1 CASING RUNL T Tag bottom at 10,100', PUW=45K, set 10,100.0 8,604.2 20:09 20:15 back down and come online with pumps 1.4BPM/3000psi, release off liner, PUW=33K 11/15/2018 11/15/2018 2.00 PROD1 CASING TRIP T Trip out of hole, pumping down 8,604.2 44.2 20:15 22:15 backside 11/15/2018 11/15/2018 0.50 PRODi CASING PULD T UD lower liner running BHA #24 44.2 0.0 22:15 22:45 11/15/2018 11/15/2018 1.00 PROD1 CASING PUTB T Prep Rig floor for running liner 0.0 0.0 22:45 23:45 11/15/2018 11/1612018 0.25 PROD1 CASING PUTB T Start PU upper slotted liner segment 0.0 94.3 23:45 00:00 11116/2018 11/162018 2.00 PRODi CASING PUTB T Continue PU slotted liner A 3-36, 94.3 1,128.2 00:00 02:00 11/16/2018 11116/2018 0.25 PROD1 CASING PULD T RD liner running equipment. 1,128.2 1,128.2 02:00 02:15 11/16/2018 11/16/2018 0.60 PROD1 CASING PULD T PU/MU CoiltrakTools, surface test 1,128.2 1,172.4 02:15 02:51 (good-test), inspect pac-off (good), "' Note: Hanging weight 5,600 lbs 11/16/2018 11/16/2018 1.25 PROD1 CASING RUNL T Tag up, reset counters, RIH w/BHA 1,172.4 7,182.0 02:51 04:06 #25 11/16/2018 11/162018 0.15 PROD1 CASING RUNL T Correct to the EOP flag (minus 9.16'), 7,182.0 7,182.0 04:06 04:15 PUW 35 k 11/16/2018 11/162018 1.70 PRODi CASING RUNL T Continue IH, work liner down 8,232'- 7,182.0 8,603.1 04:15 05:57 8603.4' 11/16/2018 11/16/2018 0.60 PROD1 CASING RUNL T Bring pump up to 1.4 bpm Q 2,046 8,603.1 8,603.1 05:57 06:33 psi, 59 psi differential pressure, unable to release from liner. decision was made to POOH 11/16/2018 11/16/2018 1.50 PROD1 CASING RUNL T Line up across the top, POOH 8,603.1 1,123.3 06:33 08:03 11/16/2018 11/16/2018 0.50 PROD1 CASING PULD T At surface, check well for NOW, LD 1,123.3 1,123.3 08:03 0833 Coiltrak tools, found EDC Page 32139 Report Printed: 1112012018 Uperations Summary (with Timeli Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (fiKB) End DepN(W13) 11/16/2018 11/16/2018 1.50 PROD1 CASING PULD T PU new BHA#26, surface test (good- 1,123.3 1,172.4 08:33 10:03 test), stab INJH *** Note: Hanging weight 5,800 Ilbs 11/16/2018 11/16/2018 1.25 PROD1 CASING RUNL T RIH, w/upper liner segment 36 jts of 1,172.4 7,128.4 10:03 11:18 slotted liner, shorty deployment sleeve, and ported bullnose 11/16/2018 11/16/2018 0.15 PRODt CASING RUNL T Correct to the EOP flag (minus 9.71 7,128.4 7,128.4 11:18 11:27 11/16/2018 11/16/2018 0.50 PROD1 CASING RUNL T Continued IH clean to TD 8603.4' 7,128.4 8,603.4 11:27 11:57 *'* Note: NPT time 5 hrs (BHI) 11/16/2018 11/16/2018 0.20 PROD1 CASING RUNL T Set down on bottom, PUW 36 k, bring 8,603.4 7,475.4 11:57 12:09 pump up to 1.5 bpm at 3,400 psi, 1019 psi differentual, PUW 32 k 11/16/2018 11/16/2018 1.00 PRODi CASING TRIP T POOH, pumping across the top 7,475.4 44.2 12:09 13:09 11/16/2018 11/16/2018 0.70 PROD1 CASING PULD T At surface, check well for flow, LD 44.2 0.0 13:09 13:51 1 1 setting tools on a dead well. 11/16/2018 11/16/2018 0.60 PRODt CASING CTOP T Perform a function test 0.0 0.0 13:51 14:27 11/16/2018 11/16/2018 0.65 PROD1 CASING PULD T PU, OH Anchored Billet and CoilTrak 0.0 73.4 14:27 15:06 toolst, MU UQC, surface test (good - test), Stab INJH, tag up, reset counter depths 11/16/2018 11/16/2018 1.40 PROW CASING TRIP T RIH, w/OH Anchored Billet BHA #27 73.4 7,095.0 15:06 16:30 11/16/2018 11/16/2018 0.20 PROD1 CASING DLOG T Log the Kt correction of minus 7.0', 7,095.0 7,119.0 16:30 16:42 1 - PUW 35 k, close EDC @ 7305.7' 11/16/2018 11/16/2018 0.20 PRODt CASING TRIP T Continue IH 7,119.0 7,474.4 16:42 16:54 11/16/2018 11/16/2018 0.20 PROD1 CASING WPST T Set down on depth, PUH 32 k, bring 7,474.4 7,463.7 16:54 17:06 pump up to shear @ 3,100 psi, PUW 34 k 11/16/2018 11/16/2018 1.30 PROD1 CASING WPST T POOH, tag up, PJSM, flow check 7,463.7 73.0 17:06 18:24 11/16/2018 11/16/2018 OJO PROD1 CASING PULD T LD BHA 926 73.0 0.0 18:24 19:06 11/16/2018 11/16/2018 0.90 PROD3 STK PULD P PU BHA#27 KO/Drill Assembly 0.0 78.0 19:06 20:00 (agitator, 0.5° AKO motor, RS Hughes P104 bit), slide in cart, change out UQC checks, check pack -offs, good, MU to coil 11/16/2018 11/16/2018 1.30 PRODS STK TRIP P RIH w/ BHA #28, shallow lest at 78.0 7,090.0 20:00 21:18 500' (pipe vibrating significantly, though little to no read-out on transducer screen, possibly b/c pumping 11.8 KW) 11/16/2018 11/16/2018 0.10 PROD3 STK CLOG P Log Kl for a -6.5' correction 7,090.0 7,120.0 21:18 21:24 11/16/2018 11/16/2018 0.30 PRODS STK TRIP P Continue RIH 7,120.0 7,288.0 21:24 21:42 11/16/2018 11/16/2018 0.80 PRODS STK DLOG P Displace to PowerPro drilling fluid w/ 7,288.0 7,288.0 21:42 22:30 EDC closed, PUW = 32K 11/16/2018 11/16/2018 0.30 PROD3 STK TRIP P Continue RIH, dry tag TOB @ 741 7,288.0 7,461.8 22:30 22:48 come up to milling rete„ PUW = 32K, tag 7461.8' pumping 11/16/2018 11/16/2018 0.90 PRODS STK KOST P Milling off billet 1 fph for 1 fl, CWT = 7,461.8 7,462.8 22:48 23:42 1 18K, WOB = 0.5K,, BHP = 3705 psi, WHIP = 381 psi, =1111712018 0.30 PRODS STK KOST P Go to 2 fph for 1 fl, CWT= 16K, WOB 7,462.8 7,463.4 = .1 K Page 33/39 ReportPrinted: 11 /2 012 01 8 . Uperations Summary (with Timelog Depths) 3H-13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Steil Depth Sten Time End Tune Dur (hr) Phase Op Cade Activity Gods Time P-T-X Operation (ftKB) End Depth (n(B) 11/17/2018 11/17/2018 0.20 PRODS STK KOST P Continue 2 fph for 1 ft 7,463.4 7,463.8 00:00 00:12 11/17/2018 11/172018 0.30 PRODS STK KOST P Go to 3 fph for 1', begin pushing on it 7,463.8 7,464.8 00:12 00:30 11/17/2018 11/17/2018 0.70 PRODS DRILL DRLG P Drilling, CWT= 3.5K, WOB = 1.5K, 7,464.8 7,584.0 00:30 01:12 BHP = 3684 psi, WHP = 322 psi, circ = 4791, 1.9 bpm in, 1.85 bpm out, pump 5x5 sweeps 11/17/2018 11/17/2018 0.20 PRODS DRILL WPRT P PUW = 35K, drift billet area up & 7,584.0 7,584.0 01:12 01:24 down, clean, RBIH 11/172018 11/172018 1.80 PRODS DRILL DRLG P OBD, CWT = 15K, WOB = 1.4K, BHP 7,584.0 7,900.0 01:24 03:12 = 3680 psi, WHP = 245 psi, circ = 4900 psi, 1.9 bpm, pull 100' vipers every 100', towards planned 400' drill interval, pump 5x5 sweeps, Avg ROP = 175 fph PUW's = 36K-39K, capture transducer sceen off bottom 11/17/2018 11/17/2018 0.20 PRODS DRILL WPRT P Wiper up-hole, PUW = 36K 7,900.0 7,500.0 03:12 03:24 11/17/2018 11/17/2018 0.20 PRODS DRILL WPRT P Wiper in-hole, RIW = 15K 7,500.0 7,900.0 03:24 03:36 11/17/2018 11/17/2018 0.70 PRODS DRILL DRLG P Drilling, 1.9 bpm, FS = 1050 psi, CWT 7,900.0 8,000.0 03:36 04:18 = 13K, WOB = 2.5K, BHP = 3688 psi, WHP = 278 psi, circ = 5069 psi, continue 100' drilled & 100' wiper PUW's = 37K 11/17/2018 11/17/2018 0.15 PRODS DRILL WPRT P 100' wiper up hole PUW 37 k 8,000.0 8,000.0 04:18 04:27 11/17/2018 11/17/2018 0.70 PRODS DRILL DRLG P BOBD, 1.9 bpm at 4,758 psi, Diff=239 8,000.0 8,100.0 04:27 05:09 psi, WHP=323, BHP=3,754, IA=695, OA=688 11/17/2018 11/17/2018 0.15 PRODS DRILL WPRT P 100'wiper up hole PUW 37 k 8,100.0 8,100.0 05:09 05:18 11/17/2018 11/17/2018 0.42 PRODS DRILL DRLG P BOBD, 1.9 bpm at 4,782 psi, Diff=239 8,100.0 8,200.0 05:18 05:43 psi, WHP=323, BHP=3,754, IA=695, OA=688 11/17/2018 11/17/2018 0.15 PROD3 DRILL WPRT P 100' wiper up hole PUW 37 k 8,200.0 8,200.0 05:43 05:52 11/17/2018 11/17/2018 0.45 PRODS DRILL DRLG P BOBD, 1.9 bpm at 4,782 psi, Diff=239 8,200.0 8,300.0 05:52 06:19 psi, WHP=323, BHP=3,754, IA=695, OA=688 11/17/2018 11/172018 0.30 PRODS DRILL WPRT P 800' wiper up hole, PUW 37 k 8,300.0 7,500.0 06:19 06:37 11/17/2018 11/17/2018 0.20 PROD3 DRILL WPRT P Wiper back in hole, RIW 11 k 7,500.0 8,300.0 06:37 06:49 11/17/2018 11/17/2018 0.65 PRODS DRILL DRLG P BOBD, 1.9 bpm at 4,815 psi, Diff-368 8,300.0 8,400.0 06:49 07:28 psi, WHP=323, BHP=3,754, IA=695, OA=688 11/17/2018 11/17/2018 0.15 PRODS DRILL WPRT P 1 00'wiper up hole PUW 37 k 8,400.0 8,400.0 07:28 07:37 11/17/2018 11/17/2018 0.65 PRODS DRILL DRLG P BOBD, 1.9 bpm at 4,815 psi, Diff--368 8,400.0 8,500.0 07:37 08:16 psi, WHP=323, BHP=3,754, IA=695, OA=688 11/17/2018 11/17/2018 0.15 PRODS DRILL WPRT P 1 00'wiper up hole PUW 37 k 8,500.0 8,500.0 08:16 08:25 11/17/2018 11/17/2018 0.80 PRODS DRILL DRLG P BOBD, 1.9 bpm at 4,815 psi, Diff--368 8,500.0 8,665.0 08:25 09:13 I I psi, WHP=323, BHP=3,754, IA=695, OA=688 Page 34139 ReportPrinted; 11/20/2018 Operations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur thr) Phase Op Cove AC9ivay COEe Time P -T -x Operation Start Depth (/IKB) End Depth (ftKB) 11/17/2018 11/17/2018 0.75 PRODS DRILL WPRT P Wiper up hole inside pipe, w/5x5 8,665.0 7,315.0 09:13 09:58 sweep 11/17/2018 11117/2018 0.60 PRODS DRILL WPRT P Continue pulling up hole, chasing 5x5 7,315.0 7,090.0 09:58 10:34 sweep, pump bottoms up. 11/17/2018 11/17/2018 0.20 PRODS DRILL DLOG P Log the K1 marker correction of (+0.5') 7,090.0 7,120.0 10:34 10:46 11/17/2018 11/1712018 0.25 PRODS DRILL WPRT P RIH, perform static pressure survey 7,120.0 7,302.0 10:46 11:01 above window @ 7,302', Gose choke in 11.8 ppg, shut pump down, monitor annular pressure, 11.6 ppg, 11/17/2018 11/17/2018 0.40 PRODS DRILL WPRT P Continue wiper back in hole. RIW 11 7,302.0 8,665.0 11:01 11:25 k 11/17/2018 11/17/2018 0.70 PRODS DRILL DRLG P BOBD, 1.9 bpm at 4,815 psi, 8,665.0 8,765.0 11:25 12:07 Diff -1,039 psi, WHP=253, BHP=3,781, IA=697, OA=688 11/1712018 11/17/2018 0.15 PROD3 DRILL WPRT P 100' wiper up hole PUW 37 k 8,765.0 8,765.0 12:07 12:16 11/17/2018 11/17/2018 1.00 PROD3 DRILL DRLG P BOBD, 1.9 bpm at 4,877 psi, 8,765.0 8,866.0 12:16 13:16 Diff --1,119 psi, WHP=222, BHP=3,809, IA=701, OA=710 11/17/2018 11/17/2018 0.15 PROD3 DRILL WPRT P 1 00'wiper up hole PUW 37 k 8,866.0 8,866.0 13:16 13:25 11/1712018 11/1712018 1.00 PROD3 DRILL DRLG P BOBD, 1.9 bpm at 4,877 psi, 8,866.0 8,985.0 13:25 14:25 Diff=1,119 psi, WHP=222, BHP=3,809, IA=701, OA=710 11/17/2018 11117/2018 0.15 PRODS DRILL WPRT P 100' wiper up hole PUW 37 k 8,985.0 8,985.0 14:25 14:34 11/17/2018 11/17/2018 1.00 PROD3 DRILL DRLG P BOBD, 1.9 bpm at 4,877 psi, 8,985.0 9,065.0 14:34 15:34 Diff --1,119 psi, WHP=222, BHP=3,809, IA=701, OA=710 11/1712018 11117/2018 0.35 PRODS DRILL WPRT P 800', wiper up hole, PUW 37 k 9,065.0 8,265.0 15:34 15:55 11/17/2018 11/17/2018 0.35 PROD3 DRILL WPRT P Wiper back in hole, RIW 15 k 8,265.0 9,065.0 15:55 16:16 11/1712018 11117/2018 1.74 PRODS DRILL DRLG P BOBD, 1.9 bpm at 4,877 psi, 9,065.0 9,216.0 16:16 18:00 Diff= -1,119 psi, WHP=222, BHP=3,809, IA=701, OA=710 11A 7/2018 11/17/2018 2.00 PRODS DRILL DRLG P Crew change, BOBD, CWT =3.8K, FS 9,216.0 9,470.0 18:00 20:00 = 1098 psi @ 1.9 bpm, circ = 5220 psi, BHP = 3818 psi (11.8 EMW @ window), pump 5x5 sweeps 11/17/2018 11/17/2018 1.50 PROD3 DRILL WPRT P Wiper to window, PUW = 37K, MAD 9,470.0 7,300.0 20:00 21:30 pass 7500'-7320' @ 5 fpm (for resistivity) 11/17/2018 11/17/2018 0.50 PROD3 DRILL DLOG P Obtain SBHP 7,300.0 7,300.0 21:30 22:00 Trap 11.87 ppg EMW (3,666 psi), MD = 7300', TVD sensor = 5939.4', allow to drop to 3620' psi, bleed to 3602 psi, built back up to 3618 psi (EMW = 11.72 ppg) ` Seat mud pump #2 (Nabors 112 hour per tour used) 11/17/2018 11/17/2018 0.30 PROD3 DRILL DLOG P Log RA for +2' correction 7,300.0 7,357.0 22:00 22:18 11/17/2018 11/17/2018 0.70 PROD3 DRILL TRIP P TD called, RBIH, confnn TO at 9470' 7,357.0 9,470.0 22:18 23:00 1111712018 11118/2018 0.99 PROD3 DRILL WPRT P Wiper to swab, PUW = 37K 9,470.0 7,630.0 23:00 00:00 11/18/2018 11/18/2618 PROD1 7,630.0 00:00 00:00 Page 35139 ReportPrinted: 11/20/2018 . Uperations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Star) Time End Time Our (hr) Phase Op Code Actively Code Time P -T -X Operation Steri oePM (W15) End NpM (8KB) 11/18/2018 11/18/2018 1.80 PRODS DRILL WPRT P Continue wiper to swab 7,630.0 78.0 00:00 01:48 11/18/2018 11/18/2018 1.30 PRODS DRILL WPRT P RBIH 78.0 7,090.0 01:48 0306 11/182018 11/18/2018 0.20 PROD3 DRILL DLOG P Log Kl for -T correction 7,090.0 7,124.0 03:06 03:18 11/18/2018 11/18/2018 0.10 PROD3 DRILL WPRT P Continue RIH to 7300' 7,124.0 7,300.0 03:18 0324 11/18/2018 11/18/2018 0.20 PROD3 DRILL DLOG P SBHP: bleed to 3599 psi, MD_bit = 7,300.0 7,300.0 03:24 03:36 7300', TVD sensor = 5939', -15 min BHP at 3611 psi, 11.7 ppg EMW 11/18/2018 11/18/2018 0.90 PRODS DRILL WPRT P Continue RIH, RIW = 13K, confirm TD 7,300.0 9,473.0 03:36 04:30 at 9,473' 11/18/2018 11/18/2018 1.15 PRODS DRILL TRIP P POOH, laying in 12.0 ppg beaded 9,473.0 7,315.0 04:30 05:39 LRP up to the window 11/18/2018 11/18/2018 0.90 PRODS DRILL TRIP P Continue POOH, displacing well to 7,315.0 6,645.0 05:39 06:33 12.0 ppg completion fluid. 11/182018 11/182018 0.20 PRODS P P Perform flow check before pulling to 6,645.0 6,645.0 06:33 06:45 surface (no -flow) 11/18/2018 11/1812018 1.25 PRODS P P Continue POOH 6,645.0 78.3 06:45 08:00 11/182018 11/18/2018 0.50 PROD3 JDRILLPULD D P At surface, check well for flow (no- 78.3 78.3 08:00 08:30 flow) 1*** -0 Note: 8 bph loss rate 11/182018 11/18/2018 50 PRODS P LD Drilling BHA on a dead well. 78.3 0.0 08:30 09:00 11/18/2018 11/182018 0.50 PROD3 CASING PUTB P Prep RF for liner ops 0.0 0.0 09:00 09:30 11/18/2018 11/18/2018 2.75 PROD3 CASING PUTB P PU/MU 55 its of slotted 2-3/8" liner, 0.0 1,750.7 09:30 12:15 MU Liner Top Billet, and non -ported bullnose. 11/182018 11/18/2018 0.50 PRODS CASING PUTB P RD liner running equipment 1,750.7 1,750.7 12:15 12:45 11/18/2018 11/1872018 0.75 PROD3 CASING PULD P PU/MU Coiltrak tools with blind sub, 1,750.7 1,795.3 12:45 13:30 slide cart forward, replace checks in the upper quick, check pac-offs (Change -out) 11/18/2018 11/18/2018 1.00 PROD3 CASING RUNL P Tag up, reset counters, RIH 1,795.3 7,202.0 13:30 14:30 -o 11118/2618 11/18/2018 15 PROD3 CASING RUNL P Correct to EDP (-7.64'), PUW 37 k 7,202.0 7,196.4 14:30 14:39 11/18/2618 11/18/2618 0.50 PRODS CASING RUNL P Continue IH 7,196.4 9,078.0 14:39 15:09 11718/2018 11/1812018 0.45 PRODS CASING RUNL P Set down @ 9,078', PUW 39k, 9,078.0 9,473.0 15:09 15:36 continue to work pipe IH, continued RIH clean from 9,108'to bottom. 11/182018 11/18/2018 0.15 PRODS CASING RUNL P Bring pump up 1.5 bpm, PUW 32 9,473.0 9,473.0 15:36 15:45 11/18/2018 11/1872618 -1 15 PRODS CASING TRIP P Pumping across the top, remove liner 9,473.0 44.2 15:45 16:54 length Nom counters, POOH 11/18/2018 11/18/2018 0.60 PROD3 CASING PULD P Check well for flow, PJSM, LD setting 44.2 0.0 16:54 17:30 tools on a dead well 11/18/2018 11/182618 1.20 PROD4 STK PULD P PU BHA#30 KO/Drill Assembly 0.0 78.0 17:30 18:42 (Agitator, 0.7° AKO, RB P104 bit), slide in cart, check pack -offs, good, MU to coil, tag up, set counters 11/18/2018 11718/2018 1.30 PROD4 STK TRIP P RIH w/ BHA #30, shallow test tools, 78.0 7,090.0 18:42 20:00 1 1 good 11/18/2018 121 111182018 0.20 PROD4 STK DLOG P Log K1 for -8' correction 7,090.0 7,120.0 20:00 0:12 Page 36139 Report Printed: 11120/2018 Uperations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation Shirt Depth (M[3) End Depth (ftKB) 11/18/2018 11/18/2018 1.20 PROD4 STK DISP P Displace to PowerPro, PUW = 31K 7,120.0 7,300.0 20:12 21:24 11/18/2018 11/18/2018 0.80 PROD4 STK DLOG P Continue RIH, MAD pass fro 7550' up 7,300.0 7,550.0 21:24 22:12 to 7350' 11/18/2018 11/1812018 0.40 PROD4 STK TRIP P RIH, dry tag TOB @ 7720', PUW = 7,550.0 7,719.8 22:12 22:36 35K, bring up rale, RBIH, begin milling @ 7719.6, PU to adjust TF 11/18/2018 11118/2018 0.90 PROD4 STK KOST P Milling 1 fph for 1 ft, FS = 1080 psi @ 71719.8 7,720.8 22:36 23:30 1.87 bpm, BHP = 3721 psi, WHIP = 215 psi, circ = 5097 psi 11/1812018 11/19/2018 0.50 PROD4 STK KOST P Go to 2 fph for 1 ft 7,720.8 7,721.8 23:30 00:00 11/19/2018 11119/2018 0.30 PROD4 STK KOST P Go to 3 fph for 1 ft, begin pushing on it 7,721.8 7,722.8 00:00 00:18 @ Tin 11/19/2018 11/19/2018 0.60 PROD4 DRILL DRLG P Drilling, 1.87 bpm, CWT= 14.3K, 7,722.8 7,800.0 00:18 00:54 WOB=.BK, BHP =3737 psi, WHIP= 207 psi, circ = 4964 psi, pump 5x5 sweeps, PUW = 38K 11/19/2018 11/19/2018 0.10 PROD4 DRILL WPRT P Drift billet area up & down, slight WOB 7,800.0 7,800.0 00:54 01:00 bobble at 7720' PUH 11/19/2018 11/19/2018 2.00 PROD4 DRILL DRLG P Drilling, FS = 1100 psi @ 1.9 bpm, 7,800.0 7,963.0 01:00 03:00 CWT 15K, WOB=1.7K, BHP= 3736 psi, WHIP = 202 psi, circ = 5190 psi, BHA wiper every 100', lower ROP beginning @ 7954' Holding 11.9 ppg for 1 -for -1, blow down MM, come down to 11.8 ppg & maintain 1 -for -1 11/19/2018 11/19/2018 1.00 PROD4 DRILL DRLG P Drilling, 1.9 bpm, BHP = 3713 psi, 7,963.0 8,000.0 03:00 04:00 WHIP = 187 psi, circa = 5104 psi, dip = 1313 psi, drilling through higherAPI interval w/ low ROP (-25 fph) 11/19/2018 11/19/2018 0.10 PROD4 DRILL WPRT P 100 ft wiper, PUW = 38K, RIW = 15K 8,000.0 8,000.0 04:00 04:06 11/19/2018 11/19/2018 2.70 PROD4 DRILL DRLG P Drilling, FS = 1150 psi @ 1.9 bpm, 8,000.0 8,125.0 04:06 06:48 BHP = 3690 psi, WHIP = 163 psi, circ = 5022 psi 11/19/2018 11/19/2018 0.30 PROD4 DRILL WPRT P Wiper up hole to 7,400', PUW 40 k 8,125.0 7,400.0 06:48 07:06 11/19/2018 11/19/2018 0.30 PROD4 DRILL WPRT P Wiper back in hole, RIW 13.9 k 7,400.0 8,125.0 07:06 07:24 1 11/19/2018 11/19/2018 2.00 PROD4 DRILL DRLG P BOBD, 1.9 bpm at 5,023 psi, 8,125.0 8,171.0 07:24 09:24 Diff --1,098 psi, WHP=236, IA=702, OA=709 11/19/2018 11/19/2018 0.10 PROD4 DRILL WPRT P 200' wiper up hole, PUW 38 k 8,171.0 7,971.0 09:24 09:30 11/19/2018 11/19/2018 0.10 PROD4 DRILL WPRT P Wiper back in hole, RIW 12.8 k 7,971.0 8,171.0 09:30 09:36 11/19/2018 11119/2618 1.40 PROD4 DRILL DRLG P BOBD, 1.9 bpm at 5,023 psi, 8,171.0 8,200.0 09:36 11:00 Diff --1,098 psi,WHP=236, IA=702, OA=709 11119/2018 11/192018 0.20 PROD4 DRILL WPRT P Wiper up hole to 7,900', PUW 39 k 8,200.0 7,900.0 11:00 11:12 11/19/2018 11/19/2018 0.20 PROD4 DRILL WPRT P Wiper back in hole, RIW 9.8 k 7,900.0 8,200.0 11:12 11:24 11/19/2018 11/19/2018 0.25 PROD4 DRILL DRLG P BOBD, 1.9 bpm at 5,023 psi, Diff --984 6,200.0 8,210.0 1124 11:39 psi, WHP=336, IA=702, OA=709 11/19/2018 11/19/2018 0.60 PROD4 DRILL WPRT P Wiper up hole to above window, PUW 8,210.0 7,090.0 11:39 12:15 38 k 11/19/2018 11/19/2018 0.20 PROD4 DRILL DLOG P Log the K1 marker correction plus 1.0' 7,090.0 7,126.0 12:15 12:27 Page 37139 Report Printed: 1112012018 Uperations Summary (with Timelog Depths) 3H -13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stars Time End Time Dur(hr) Phase Op Code Activity Cotle Time P -T -X Operation Start Depth (fIKB) End Dept rftKB) 11/19/2018 11/19/2018 0.50 PROD4 DRILL WPRT P With bottoms up, RIH RIW 14.7 k 7,126.0 8,210.0 12:27 1257 Note: Set down 8,165' 11/19/2018 11/19/2018 1.25 PROD4 DRILL DRLG P BOBD, 1.9 bpm at 5,023 psi, Diffi 8,210.0 8,243.0 12:57 1412 psi, WHP=336, IA=702, 01 11/19/2018 11/19/2018 0.25 PROD4 DRILL WPRT P Wiper to the billet, PUW 37 k 8,243.0 7,740.0 14:12 1427 Note: Called TO early do to hole conditions/150 API 11/19/2018 11/19/2018 0.40 PROD4 DRILL WPRT P RBIH to 7,950', RIW 13.3 k 7,740.0 7,950.0 14:27 14:51 11/19/2018 11/19/2018 2.00 PROD4 DRILL WPRT P POOH chasing sweeps, performing 7,950.0 78.3 14:51 16:51 1jogs @ 5,200', 3,200', and 517' 11/19/2018 11/19/2018 1.15 PROD4 DRILL TRIP P Tag up, reset counter depths, RIH 78.3 7,090.0 16:51 18:00 11/19/2018 11/19/2018 0.15 PROD4 DRILL DLOG P Log the K1 correction of minus 8.0' 7,090.0 7,126.0 18:00 18:09 11/19/2018 11/19/2018 0.15 PROD4 DRILL DLOG P Perform Static Pressure Survey @ 7,126.0 7,300.0 18:09 1818 7,300', 5,939' (TVD), 3,632 psi (11.76 ppg) 11/19/2018 11/19/2018 0.55 PROD4 DRILL TRIP P Continue IH off bottom @ 7,950', PUW 7,300.0 7,950.0 18:18 1851 34 k 11/19/2018 11/19/2018 1.00 PROD4 DRILL TRIP P POOH, laying in 12.0 ppg beaded liner 7,950.0 5,500.0 18:51 1957 running pill up into cased hole, 5,500', Painting EDP flags TD and above window 11/19/2018 11/19/2018 1.00 PROD4 DRILL TRIP P Continue POOH, displacing well to 5,500.0 78.3 19:51 20:51 12.0 ppg completion fluid 11/19/2018 11/19/2018 0.50 PROD4 DRILL PULD P At surface, check well for flow, PJSM 78.3 78.3 20:51 21:21 11/19/2018 11/19/2018 0.55 PROD4 DRILL PULD P LD drilling BHA on a dead well 78.3 0.0 21:21 21:54 11/19/2018 11/19/2018 0.45 PROD4 CASING PUTB P Prep rig floor for liner ops, PJSM 0.0 0.0 21:54 22:21 11/19/2018 11/19/2018 1.15 COMPZ4 CASING PUTB P MU AL1 -03 liner segment 22 jts, 0.0 685.0 22:21 23:30 shorty deployment sleeve, and non - ported bullnose. 11/19/2018 11/20/2018 0.50 COMPZ4 CASING PULD P Begina PU Liner running tools BHA 685.0 685.0 23:30 00:00 #31 17/20/2018 11/20/2018 0.30 0011 CASING PULD P Complete PU Liner running tools BHA 685.0 730.0 00:00 00:18 #31, slide in cart, change out checks, MU to coil, tag up, set counters 11/20/2018 11/20/2018 2.90 COMPZ4 CASING RUNL P RIH w/ BHA#31, -6.13' correction to 730.0 7,944.0 00:18 0312 window flag, PUW = 35K, continue RIH to 7944', PUW = 40, RBIH, bring up pumps 1.55 bpm (dip = 1000 psi), release off liner, PUW = 34K, BOM = 7944', TOL- 7258' 11/20/2018 11/20/2018 0.30 COMPZ4 CASING DLOG P Obtain SBHP (15 min): MD = 7243.6', 7,944.0 7,224.0 03:12 0330 TVD -sensor = 5927.3', Annular= 3667 psi, EMW = 11.91 ppg Note: EMW = 11.76 ppg on last SBHP w/ 9 ppg Power -Pro in the well 11/20/2018 11/20/2018 2.00 COMPZ4 CASING DISP P Open EDC, displace well to seawater, 7,234.0 2,500.0 03:30 0530 POCH 11/20/2018 11/20/2018 1.70 COMPZ4 CASING FRZP P Ffreeze protect from 2500' to surface, 2,500.0 44.0 05:30 0712 POOH 11/20/2018 11/20/2018 1.30 COMPZ4 CASING PULD P PJSM, PUD & LD BHA#31 44.0 0.0 07:12 08:30 "SITP = 1180 psi, IA = 670 psi, OA = 482 psi Page 38139 Report Printed: 11/20/2018 Uperations Summary (with Timelog Depths) 3H-13A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time Entl Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ttKB) Entl Depth(ftKB) 11/20/2018 11/20/2018 1.50 DEMOB WHDBOP RURD P Clear rig floor, MU nozzle, stab on, 0.0 0.0 08:30 10:00 flush stack, pop off, break-off nozzle, blow down surface lines, clear floor, working RD checklist. 11/20/2018 11/20/2018 1.00 DEMOB WHDBOP RURD P Remove UQC checks, work RD 0.0 0.0 10:00 11:00 checklist, vac out stack, freeze protect tree 11/20/2018 11/20/2018 1.00 DEMOB WHDBOP NUND P ND BOP 0.0 0.0 11:00 12:00 Rig Released: 11/20 12:00 him Page 39/39 ReportPrinted: 11/20/2018 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-13AL1 50-103-20089-60 Baker Hughes INTEQ Definitive Survey Report 07 December, 2018 BER HUGHES a CE company ConocoPhillips ER s ConocoPhilli p Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 31-1-13 Wellbore: 31-1-13AL7 Design: 3H-13AL1 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 3H-13 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Position +NIS 0.00 usft Northing: +EI -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 3H-13AL7 Magnetics Model Name Sample Data BGGM2018 1119/2D18 Design 3H-13ALi Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 71.00 Well 3H-13 3H -13A @ 71.00usft (3H -13A) 3H -13A @ 71.00usft (31-1-13A) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 6.000.475.46usft 498,655.42usft usft Declination PI 16.82 Latitude: Longitude: Ground Level: Dip Angle (1) 80.91 Tie On Depth: 7,97365 ,NI -S +El -W Direction (usft) (usft) (') 0.00 0.00 180.00 700 24' 45.119 N 150° 0' 39.419 W 0.00 usft Field Strength (nT) 57,434 12/7/2018 3:44:27PM Page 2 COMPASS 5000.14 Build 850 Survey MD Inc Azl ConocoPhillips TVDSS +N/ -S BA ER ConocoPhillips Map DLS Vertical (usft) (1 (1) Definitive Survey Report (writ) (usN) (usft) Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 3H-13 Survey Tool Name Annotation Project Kuparuk River Unit TVD Reference: 3H -13A Q 71.00usft (311-13A) site Kuparuk 3H Pad (N) MD Reference: 3H -13A @ 71.00usft (3H -13A) Well: 3H-13 200.83 North Reference: True 2,808.45 -62329 Wellbore. 3H-13AL1 8.66 Survey Calculation Method: Minimum Curvature TIP 7,999.00 Design: 3H-13AL7 5,983.16 Database: EDT 14 Alaska Production -632.05 6,003,25998 Survey Program 503 Date MWD -INC _ONLY (5) KOP 8,030.53 - From TO -5,911.71 2754.89 -642.36 Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Data 95.00 5,900.00 3H-13 (3H-13) GCT -MS Schlumberger GCT mulashot 1/12/2001 5.01 6,113.56 7,260.49 3H-13AATDB(31-1-13A) MWD MWD -Standard 9/18/2001 5,983.80 7,315.00 7,396.26 3H-13AL1PB3 MWD-INC(3H-13AL1PB3 MWD-INC_ONLY MWD -INC _ONLY -FILLER 11/11/2018 11/11/2018 7,426.34 7,973.65 3H-13AL1PB3 MWD(3H-13ALiPB3) MWD MWD - Standard 11/11/2016 11/13/2018 7,999.00 8,030.53 3H-13AL1 MWD-INC(3H-13ALi) MWD -INC -ONLY MWD-INC_ONLY-FILLER 11/14/2018 11/14/2018 8,060.80 10,065.97 3H-13AL7 MWD(3H-13AL1) MWD MWD - Standard 11/14/2018 11/15/2018 Survey MD Inc Azl TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (1 (1) (usN) (writ) (usN) (usft) Northing Essgng Section Survey Tool Name Annotation (N) (-1100-) (ft) 7,9]3.85 91.90 200.83 5,980.12 -5,913.12 2,808.45 -62329 6,003,283.74 498,032.70 8.66 -2,80845 MWD 14) TIP 7,999.00 92.43 199.67 5,983.16 -5,912.16 2,784.68 -632.05 6,003,25998 498,023.93 503 -2,784.68 MWD -INC _ONLY (5) KOP 8,030.53 89,20 198.50 5,982.71 -5,911.71 2754.89 -642.36 6,003,230.19 498,01362 10.90 -2,754.89 MWD-INC_ONLY (5) Interpolated Azimuth 8,060.80 88.34 199.75 5.98336 -5,912.36 2,726.30 -652,27 6,003,201.61 498.003.70 5.01 -2,726.30 MWD(6) 8,089.81 89.91 200.48 5,983.80 -5,91280 2,699.07 -662.25 6,003,174.38 497.993.72 5.97 -2,699.07 MWD (6) 8,120.51 9206 20159 5,983.28 -5,912.28 2,6T042 -673.27 6,003,14573 497,982.70 7.88 -2,670.42 MWD (6) 8.150.38 92.77 202.19 5,982.02 -5,911.02 2,642.73 -684.39 6,003,118.05 497,971.57 3.11 -2,642.73 MWD (6) 8,180.36 93.38 203.99 5,98041 -5,909.41 2.615.19 -696.13 6,003,090.51 497.959.83 6.33 -2,615.19 MWD (6) 8.21033 9357 206.10 5,97859 -5,907.59 2588.09 -708.80 6,003,06342 497,947.16 7.06 -2,568.09 MWD (6) 8,240.13 93.57 208.13 5.976.74 -5,905.74 2.561.62 -722.35 6,003,036.95 497.933.60 6,80 -2,561.62 MWD (6) 8,270.47 92.25 210.10 5,975.20 -5,904.20 2,535,15 -737,09 6,003010.49 497.918.86 7,81 -2,535.15 MWD (6) 8,300.61 91.51 211.45 5.974.21 -5,903.21 2.509.27 -752.51 6,002.984.61 497,903.44 5.11 -2069.27 MVID(6) 8,330.38 9141 212.81 5,97345 -5,90245 2,484.06 -768.33 6,002,95041 497,88761 4.58 -2,484,06 MWD (6) 8,360.41 91.14 21242 5,972.78 -5,901.78 2.458.78 -784.52 6,002,934.13 497,87142 1.58 -2,458.78 MWO(6) 8,39043 89.51 21154 5,972.61 -5,901,61 2,433.31 -800,41 6,002,908.67 497.855.52 6.17 -2433.31 MWD (6) 8,420.33 88,89 209.38 5,973.03 -5,902.03 2,407.54 -815.5T 6,002,88291 497,840.37 7.52 -2,407.54 MIND (6) 8,450,25 88.99 20T.92 5,973.58 -5,902.58 2,381.29 -829.91 6,002,856.66 497.82602 4.89 -2381.29 MWD (6) 8,480.22 90.09 206.02 5,973.82 -5.902.82 2.354.58 543.50 6,002,829.96 497.812.43 733 2,354.58 MWD(6) 1277/2018 3:44:27PM Page 3 COMPASS 5000.14 Build 85D Survey MD ConocoPhillips Azi ConocoPhillips Definitive Survey Report -N/-S Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 311-13 Project: Kuparuk River Unit TVD Reference: 31-1-13A @ 71.00usft (31-1-13A) Site: Kuparuk 3H Pad MD Reference: 3H -13A @ 71.00usft (31-1-13A) Well: 31-1-13 North Reference. True Wellbore: 3H-13AL7 Survey Calculation Method: Minimum Curvature Design: 3H-13AL7 Database: EDT 14 Alaska Production Survey MD Inc Azi TVD TVDSS -N/-S +EI -W Map Map DLS Vertical (usft) V) (1) (usft) (usft) (usft) (usft) Northing Easling plow) Section Survey Tool Name Annotation (8) (ft) (ft) 8,510.65 8975 20365 5,973.87 -5,902.87 2.326.97 -656.28 6,002,802.35 497.799.64 7.87 -2.326.97 MWD (6) 8,54109 88.80 202.63 5,974.25 -5,903.25 2,298.98 -868.24 6.002,774.37 497,787.68 4.58 -2298.98 MWD (6) 8,571.56 8948 200.82 5,974.71 -5,903.71 2.270.68 $79.52 6,002746.07 497776.40 6.34 -2,27068 MIND (6) 8,600.51 88.86 199.14 5,975.13 -5,904.13 2,243.48 -889.41 6,002,716.67 497,766.50 6.19 -2,243.46 MWD (6) 8,63071 86.40 196.46 5.9T585 -5,90485 2,21473 -898.64 6,002,690.13 497,757.27 9.00 -2,214.73 MWD (6) 8.661.10 88.16 194.89 5.976.76 -5,90576 2,185.49 -906.85 6.002,660.89 497,749.06 5.22 -2,18549 MWD (6) 8,690.88 89.17 192.04 5,97746 -5,906.46 2,156.54 -91378 6.002,631.95 497,742.12 10.15 -2.156.54 MWD (6) 8.725.69 90.21 189.82 5,977.64 -5.906.64 2.122.36 -920.38 6,002,597.78 497,735.52 7.04 -2,122.36 MWD (6) 8,75]63 89.83 187,05 5,977.69 -5,906.69 2.09077 -925.06 6,002.566.19 497.730.83 8.86 -2,090.77 MWO(6) 8,78753 90.46 185.19 5,977.66 -5.906,66 2,061.04 -928.25 6,002,536.46 497,727.63 6.81 -2,061,04 MIND (6) 8,817.78 9239 184.38 5,976.91 -5,905.91 2,030.91 -930.77 6,002,506.33 497,725.11 6.92 -2,030.91 MWO(6) 8,845.99 9359 182.46 5,975.44 -5,904.44 2,002.79 -932.45 6,002,478.22 497.723.42 8.02 -2,002.79 MIND (6) 8,8T701 93.65 180.51 5,973.48 -5,902.48 1,97184 -933.26 6,002,447.27 497,722.61 6.28 -1,971.84 MWD (6) 8,907.63 92.95 17805 5,971.72 -5,900.72 1,94128 -932.87 6,002,416.71 497,722.99 8.34 -1,941.28 MWD (6) 8,937.91 93.01 175.76 5,970.14 -5,899.15 1,911.09 -93124 6.002,386.52 497,724.62 7.66 -1,911.09 MWD (6) 8.967.63 94.52 175.00 5,968.19 -5,897.19 1,881.53 -928.85 6,002,356.97 497,727.00 5.69 -1,881.53 MWD(6) 8,998.84 94.24 172,73 5,965.81 -5,894.81 1.850.59 -925.52 6,002,326.03 497,730.32 7.31 -1,850.59 MWD (6) 9,028.31 93.42 171.46 5,963.84 -5,892.84 1,621.47 -921.48 6,002,296.91 497.734.36 5.12 -1,82147 MWO(6) 9,05783 93.32 170.04 5,962.11 -5,891.11 1,792.38 -916.74 6,002,267.83 497,739.09 4.81 -1,792.38 MWD (6) 9,068.11 93.28 17039 5,960.36 -5,869.36 1,762,59 -91161 6,002,238.04 497,744.22 1.16 -1,762.59 MWD (6) 9.117.95 92.21 170.94 5,958.93 5,887.93 1,733.18 -906.77 6.002,20863 497,749.05 4.03 -1,733.18 MWD (6) 9,148.69 89.85 173.44 5,958.38 5,887,38 1,702.74 -902.60 6,002,178.19 497,75322 11.18 -1,702.74 MWD (6) 9,177,94 89.17 174.11 5,958.63 -5,88763 1,673.66 -899.42 6,002,149.11 497,756.39 3.26 -1,673,65 MIND (6) 9,211.19 88.28 17704 5,959.37 -5,888.37 1,640.52 -896.86 6,002,115.98 497,758.95 9.21 -1,640.52 MIND (6) 9.237.70 88.77 178.65 5,960.05 -5.889.05 1,614.04 -895.86 6,002,089.50 497,759.94 6.35 -1,614.04 MWD (6) 9.267.63 89.69 18074 5.960.46 -5,889.46 1,584.11 -895.70 6.002,059.58 497,760.09 763 -1,584.11 MWD (6) 9,297.96 90.18 183.42 5,960.49 -5,889.49 1,553.81 -896.80 6,002,029,27 497,758.98 8.9B -1.553.81 MWD (6) 9,328.27 90.95 186.12 5,960.19 -5,BB9.19 1.523.61 -899.32 6,001,999.08 497,756.46 9.26 -1,523.61 MD (6) 9,35749 90.64 186.57 5,959.79 -5,88679 1.494.57 -902.55 6,001,970.04 407,753.23 1,87 -1,494.57 MWD (6) 9,388.46 9095 189.84 5,95936 -5.888.36 1,463.92 -906.97 6,001,939.40 49774880 10.60 -1,46392 MWD (6) 9,418.23 89.94 19107 5,959.12 -5.888.12 1,434.65 -912.37 6001,910.13 497.743.40 5.35 -1,434.65 MWD (6) STS a 12/7/2018 144: 27PM Page 4 COMPASS 5000.14 Build 85D Survey MD ConocoPhillips Azi ConocoPhillips Definitive Survey Report +N/ -S Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 3H-13 Project: Kupamk River Unit ND Reference: 31-1-13A Q 71.00usft (31-1-13A) Site: Kuparuk 3H Pad MD Reference: 311-13A @ 71.00usft (3H -13A) Well: 311-13 North Reference: True Wellbore: 311-13AL1 Survey Calculation Method: Minimum Curvature Design: 3H-13AL1 Database: EDT 14 Alaska Production Survey MD Inc Azi NO N +N/ -S *E/ -W Map Map OLS VerticalDSS (usft) (') (°) (usft) (usft) (usft) (usft) Northing Easting (./too.) Section Survey Tool Name A (ft) (ft) 9.44728 88.06 191.86 5,959.63 -5,888.63 1.40618 918.15 6,001,881.67 497,73762 7.02 -1,406.18 MWD (6) 9,477.21 86.44 192.28 5,961.07 -5,890.07 1.37695 -924.40 6.001.85244 497,731.36 5.59 -1,375.95 MWD(6) 9.507.35 8508 192.87 5,963.30 5,89230 1,347.61 -930.94 6,001,823.11 497.724.61 4.92 -1,347.61 MWD(6) 9,537.33 84.96 194.48 5,965.90 -5,894.90 1,318.60 -938.00 6001.79409 497,717]5 5.36 -1,31860 MWD (6) 9,567.70 84.59 196.24 5.968.66 -5.897.66 1.289,43 -946.01 6.001,76493 497.709.73 5.90 -1,289A3 MWD (6) 9,597.30 64.88 198.23 5.971.43 -5,900.43 1,261.29 -954.74 6.001,736.79 497,701.00 6.70 -1,261,29 MWD (6) 9,627.17 8708 198.56 5,973.58 -5,902.58 1.233.02 -964.15 6,001,708.53 497,691.59 8.11 -1,233.02 MIND (6) 9,657.57 8969 198.52 5,974.44 -5,903.44 1,204.21 -973.81 6,001,679.73 497,68193 8.59 -1,204.21 MWD (6) 9,687.79 91.08 200.32 5,974.23 -5,903.23 1,175.71 -98385 6,001,651.23 497,671.88 7.53 -1,175.71 MWD(6) 9,717.29 91.44 201.97 5,973.58 -5,902.58 1,148.21 -994.49 6,001,623.73 497,661.23 5.72 -1,148.21 MWD (6) 9,747.26 91.66 203.80 5,972.77 -5,901.77 1,120.61 -1,006.14 6,001,596.14 497,649.58 6.15 -1,120.61 MWD (6) 9,776.86 90A0 204.46 5,97224 -5,90124 1,093.60 -1,018.24 6,001,569.13 497,637.48 4.81 -1,093.60 MWD (6) 9,807.24 8794 205.11 5,972.68 -5,90168 1.066.02 -1,030.97 6,001,541.56 497,624.74 8.38 -1,066.02 MWD (6) 9,836.70 Her 202.36 5,973.71 -5,902.71 1.039.07 -1042.62 6,001,51662 497,612.89 9.34 -1,03907 MWD(6) 9,861.65 89.51 200.65 5,974.23 -5,903.23 1,015.87 -1,051.97 6,001491A1 497,603.74 6.96 -1,015,87 MWD(6) 9,89246 89,20 198.49 5,974.58 -5,903.58 986.84 -1,062.29 6,001,462.39 497,593.42 7.08 -98684 MWD (6) 9,921.81 86.99 195.97 5,975.04 -5,904.04 958.81 -1,070.98 6.001434.37 497,584]2 8.61 -958.81 MWD (6) 9,951.95 89.02 19397 5,975.57 -5,90457 929.70 -1,078.76 6,001,405.26 497,576,93 6.64 -929.70 MWD (6) 9,982.19 88.19 192.16 5.976.30 -5,905.30 900.25 -1,085.60 6,001,375.82 497,570.09 6.58 -900.25 MWD (6) 10,012.49 88.13 189.65 5,977.28 -5,906.28 870.52 -1,091,32 6,001,346.09 497,564.36 8.28 -87052 MWD(6) 10.042.26 87.88 188.23 5,978.31 -5,90731 841.13 -1,095.95 6,001.316.70 497,559.73 4.84 -841.13 MWD (6) 10,065.97 8791 185.83 5,979.18 -5,908.16 817,62 -1,098.85 6,001,293.19 497,555.83 10.12 .817.62 MWD (6) 10,100.00 87.91 185.83 5,980.42 -5.909.43 783.78 -1.102.30 6,001,259.36 497,553.37 0.00 -783.78 PROJECTED to TD Annotation EIVIER a,, 721712018 3:44: 27PM Page 5 COMPASS 5000.14 Build 850 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-13AL1PB1 50-103-20089-70 Baker Hughes INTEQ Definitive Survey Report 07 December, 2018 BA ER I UGHES aGEcomOany ConocoPhillipsER ConocoPhillips "�" p Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 3H-13 wellbore: 3H-13AL 1 PB1 Design: 3H-13AL1PB1 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 3H-13 Local Co-ordinate Reference: Well 3H-13 TVD Reference: 3H -13A @ 71.00usft (3H -13A) MD Reference: 31-1-13A @ 71.00usft (31-1-13A) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Well Position +NI -S 0.00 usft Northing: Using geodetic scale factor +EI -W 0.00 usft Easting: Position Uncertainty Longitude: 0.00 usft Wellhead Elevation: Wellbore 3H-13AL1PB7 71.00 0.00 Magnetics Model Name Date Sample Date From BGGM2018 11/1/2018 Design 3H-13AL1PB7 Survey (Wellbore) Tool Name Audit Notes: 5,900.00 3H-13 (3H-13) GCT -MS Mean Sea Level 1.0 Using Well Reference Point Tie On Depth7,260.49 Using geodetic scale factor 6,000,475.46usft Latitude: 498,655.42usft Longitude: usft Ground Level: Declination Dip Angle C) M 1683 80.91 Version: 1.0 Phase: ACTUAL Tie On Depth7,260.49 Vertical Section: Depth From (TVD) -NI-S (usft) (usft) 71.00 0.00 Survey Program Date From To (usft) (usft) Survey (Wellbore) Tool Name 95.00 5,900.00 3H-13 (3H-13) GCT -MS 6,113.56 7,260.49 3H-13AATDB(311-13A) MWD 7,340.00 7,390.33 3H-13AL1PB1 MWD -INC (3H-13AL1PB1 MWD-INC—ONLY 7,427.83 9,036.07 3H-13AL1PB1 MWD(3H-13AL1PB1) MWD 1217/2018 3:39:40PM Page 2 +E/ -W (usft) 0.00 Desulption Schlumberger GCT multishot MWD - Standard MWD -INC —ONLY—FILLER MWD - Standard Direction (1) 180.00 Survey Start Date 1/12/2001 9/18/2001 10/24/2018 10/24/2018 70° 24'45.119 N 150` 0'39.419 W 0.00 usft Field Strength (hn 57,435 Survey End Date 10/24/2018 10/27/2018 COMPASS 5000.14 Build 85D ConocoPhilli s"" p ConocoPhillips Definitive Survey Report eR Company: ConocoPhillips (Alaska) Inc. -KUp2 Local Coordinate Reference: Well 31-1-13 Project: Kupamk River Unit TVD Reference: 3H -13A @ 71.00usft (3H -13A) Site Kuparuk 3H Pao MO Reference: 311-13A @ 71.00usft (3H -13A) Woo- 31-1-13 North Reference: True Wellbore: 3H-13ALIPB1 Survey Calculation Method: Minimum Curvature Design: 3H-13AL1PB1 Database: EDT 14 Alaska Production Survey MD Inc Azi TVD TVDSS +NIS +E/•W Map Map DLS Vertical (usft) (1) (1) (usft) NOR) (usft) (usft) Northing Fasting Section Survey Tool Name Annotation (R) Ift) (°1100' ) (ft) 7,260.99 57.88 31]0 5,94406 -5,873.06 2,976.09 -836.14 6,003,45140 497,819.90 040 -2,976.09 MWD -INC _ ONLY (3) TIP 7,340.00 58,38 3187 5,98804 -5,915.D4 3,033.48 -800.57 6,003,508.78 497,855.47 0.65 -3,033.46 MWD-INC_ONLY(3) KOP 7,362.17 61.94 3420 5,997.07 -5,926.07 3,99.60 -790.09 6,003,524.89 497,865.96 18,46 -3,049.6D MWD -INC _ ONLY (3) Interpolated Azimuth 7,390.33 73.73 41.00 6,007.69 -5,936.69 3,070.17 -774,16 6,003,54546 497,881.89 4744 -3,070.17 MWD -INC _ONLY(3) Interpolated Azimuth 7,427.83 90.03 48.58 6,012.97 -5,941.97 3,096,84 -748.54 6,003,572.13 497,907.51 45,88 -3.096.84 MWD (4) 7,460.36 91.44 61.07 6,012.55 -5,941.55 3,115.99 -722.36 6,003,591.27 497,933.70 44.75 -3.11599 MWD (4) 7,490.26 90.34 76.04 6,012.08 -5,941.08 3.126.89 -694.51 6,003,602.16 497.961.44 50.20 -3,126.89 MWO(4) 7,520.15 90.45 8976 6,011.88 -5,940.88 3,130.57 565.02 6,00360584 497.99103 45.90 -3.130.57 MWD (4) 7555.07 91,84 108.09 6,011.17 -5,940.17 3,125.18 530.66 6,003,600.44 498,025.37 52.63 -3,125.18 MWD (4) 7,585.07 91.59 121.80 6,010.28 -5,939.28 3,112.56 -603.55 6,003587.82 498.052.49 45.69 -3,112.56 MWD (4) 7,615.19 93,32 13698 6,008,99 -5,937.99 3,093.53 -580.36 6,003,568.78 498,075.67 50.70 -3,093,53 MWD (4) 7,640.23 93.25 148.92 6,007.55 -5.936.55 3,073.61 -565.33 8003,54886 498.090.711 47.61 -3,073.61 MWD (4) 7,67116 92.12 162.64 6,006.10 -5,935.10 3,045.50 552.69 6,003,520.76 498,103.34 44.46 -3,095.50 MWD (4) 7,702.02 9118 165.22 6,005.05 -5,934,05 3,015.87 -544.15 6.003.491 .12 498,11187 BA3 -3,015.87 MWO(4) 7,73125 92.12 168.76 6,004.05 5,933.05 2,987,41 -53757 6,003,462.67 498,118.44 12.16 -2,987.41 MWD (4) 7,76122 91.69 171.07 6.003.06 -5,932.06 2.957.92 -532.33 6,003,433.18 498.123.68 7.84 -2,957.92 MWD (4) 7,791.24 9242 173.33 6,001.98 -5,930.98 2,92820 -528.26 6.003,403.46 496.127.74 7.91 -2,928,20 MWD (4) 7,82227 92.12 175.61 6,000.75 5,929.75 2,897.34 525.27 6,003.37260 498,13012 741 -2,897.34 MWD (4) 7,851.32 91.38 177.55 8999.86 -5,928.86 2,868.36 523.54 6,003.343.62 498,132.45 7.14 -2,868.36 MWD (4) 7,881.47 90,58 180.11 5.999.35 -5,926.35 2,838.22 -522.92 6,003,313.49 498.133.06 8.89 -2838.22 MWD (4) 7,911.42 91.69 182.94 5.998.76 -5,927.76 2,606.29 523.72 6,003,283.56 498,132.26 10.15 -2,80829 MWD (4) 7,941.43 91.38 185,07 5,997.95 -5,926.95 2,778.37 525.82 6,003,253.64 498,130.16 7.17 -2778.37 MWD (4) 7,971.16 90.55 186.74 5,997.45 -5,92645 2,748.80 -528.87 6,003.224.08 498,127.09 6.27 -2,748.80 MWD (4) 8.001.33 89.88 189.46 5,997.34 -5,926.34 2.718.93 533.12 6,003,194.22 498.122.84 9.28 -2.718.93 MWD (4) 8,031.54 90.03 191.92 5,997.36 -5,926.36 2,689.25 -538.73 6,003.164.59 498,117.23 8.16 -2.689.25 MWD (4) 8,062.63 90.34 194.06 5,997.26 -5,926.26 2.658.96 -545.72 6,003.134.25 498,110.24 696 -2,658,96 MWD (4) 8,092.63 89.79 195.85 5,997.23 -5,926,23 2.62997 -553.46 6,003.10527 498,102.49 624 -2,629.97 MWD (4) 8.122.17 89.97 196.19 5,997.29 -5,926.29 2,601.73 -562.10 6,003,077.03 498,093.84 7.94 -2.601.73 MWD (4) 8,151.84 89.42 20104 5,99745 -5,926.45 2.573.79 -572.06 6,003.049.09 498,08388 9.78 -2,573.79 MWD (4) 8,182.59 89.32 198.87 5,997.78 -5,926.78 2,544.89 -582.56 6003020.20 498,073.38 7.06 -2,544.89 MWD (4) 12/72018 3:39:40PM Page 3 COMPASS 5000.14 Build 85D Survey MD ConocoPhillips Ail ConocoPhillips Definitive Survey Report +N/ -S Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 31-1-13 Project: Kuparuk River Unit TVD Reference: 314-13A @ 71.00usft (31-1-13A) Site: Kuparuk 3H Pad MD Reference: 3H -13A @ 71.00usft (3H -13A) Well: 31-1-13 North Reference: True Wellbore: 3H-13AL1PB1 Survey Calculation Method: Minimum Curvature Design. 3H-13ALiPB1 Database: EDT 14 Alaska Production Survey MD Inc Ail TVD N +N/ -S +EI -W Map Map DLS VerticalDSS (usft) 0 0 (usft) (usft) (usft) (usft) Northing Easting Section Survey Tool Name (ft) (ft) (°1100'1 Iftl 8,212.00 88]7 196.65 5,998.27 -5,927.27 251688 -591.52 6,002,992.20 498,064.41 7.78 -2,516.88 MWD (4) 8,241.47 B7.79 193.89 5,999.16 -5,928.16 2.488.47 -599.28 6,002,963.79 498,056.65 9.93 -2,46847 MWD (4) 6,271.41 86.19 190.50 6,000.73 -5,929.73 2,459.25 605.60 6,002,934.57 498,050.33 12.51 .2,459,25 MWD (4) 8,301.56 86.77 18780 6,002.58 -5,931.58 2,429.52 610.38 6,002,904.85 498,04553 944 -2,429.52 MWD (4) 8,333.09 87.27 183.85 6,00422 -5,933.22 2,398.22 -613.56 6,002,873.56 498,042.33 12.59 -2,398.22 MWD(4) 8,36142 86.86 181.08 6,005.67 -5,934.67 2,369.96 -61480 6,002,84529 498,041.11 9.91 -2.369.96 MWD (4) 8,391.19 87.54 178.22 6,007.13 -5,936.13 2,340.23 -614.62 6.002.815.57 498,041.28 9.86 -2.340.23 MWD (4) 8,421.13 87.67 175.33 6,006.38 3.93738 2,310.37 612.94 6,002,785.71 498,042.96 965 -2310.37 MWD (4) 6,451.11 8856 174.56 6,00937 -5,938.37 2,280.52 610.29 6,002,755.86 498.045.60 3.92 -2,280.52 MWD (4) 8,480.94 90.56 175.15 6,009.59 -5,938.59 2.250.81 607.62 6,002,726.16 498.048.27 7.05 -2.250.81 MWD (4) 8,510.31 92.80 175.53 6,008.72 -5,937.72 2,221.55 -605.24 6,002,696.90 498,050.65 7.67 -2,221.55 MWD (4) 6,540.65 95.16 176.18 6,006.52 -5,935.62 2,191.37 603.05 6,002,666.72 498,052.83 8.07 -2,191.37 MWD (4) 8,570.69 96.28 178.61 6,003.62 -5,93262 2,161.51 601.69 6,002,636.86 498,054.18 887 -2,161.51 MWO(4) 8,599.66 95.94 180.27 6.00054 -5,929.54 2,132.71 601.41 6,002,60806 498.054.46 5,82 -2,132.71 MWD (4) 8,630.26 96.14 183.30 5,997.32 -5,926.32 2,102.30 602.35 6,002,5]7.66 496,053.50 967 -2,102.30 MWD (4) 8,660.47 95.30 185.90 5,994.31 -5,923.31 2,072.34 -60417 6,002,54].70 498,051.09 9.00 -2,072.34 MWD (4) 8,690.86 96.27 187.37 5,991.24 -5,920.25 2.042.31 -608.26 6,002,517.67 498,047.59 5.77 -2,042.31 MWD(4) 8,720.50 97.69 188.56 5,98764 -5.916.64 2,013.17 612.33 6,002,488.54 498,043.51 6.23 -2.013.17 MWD (4) 8,75085 98.07 192.06 5,98348 .5,912.48 1,963,60 -617.71 6,002,458.97 498,038.12 11.49 -1.983.60 MWO(4) 8,775.95 97.69 194.22 5,980.04 -5,909.4 1,959.39 -623.37 6,002,434.76 498,03247 8.66 -1,959.39 MWD (4) 8,805.77 9591 196.86 5,976.51 -5,90551 1,930.86 -631.30 6,002,406.24 498,024.53 10.63 -1,930.86 MWD (4) 8.835.86 94.15 199.14 5,97387 -5,902.87 1,902.36 610.56 6,002,377.75 498,015.27 9.55 -1,902.36 MWD (4) 8,861.26 93.19 199.20 5,972.24 3.90124 1,678.40 618.89 6,002,353.79 498,006.93 3.78 -1,87840 MWD (4) 8,892.54 9544 201.23 5,969.89 -5,898.89 1,849.15 659.66 6,002,324.54 497,996.16 9.68 -1,849.15 MWD (4) 8,916.33 94.91 203.80 5,967.74 -5,896.74 1.827.27 -668.73 6,002.302.66 49T,9B7.08 10.99 -1,827.27 MWD (4) 8,94627 93.13 205.70 5,965.65 -5,894.65 1,800.15 -681.24 6,002,275.55 497.974.58 8.68 -1,600.15 MWD (4) 8,97531 93.87 208.54 5,963.87 -5,892.87 1,774.35 -69445 6.002,249.76 497,96136 10.09 -1,774.35 MWD (4) 9,005.63 94.21 206]6 5,961.74 -5,890.74 1,747.56 -708.48 6,002,222.97 497,947.32 596 -1,747,56 MWD (4) 9,036.07 93.62 20295 5,959.66 -5,888,66 1.72801 -72124 6,002,195.43 497.934.56 12.64 -1,720.01 MWD (4) 9,085.00 93.62 202.95 5.956.57 -5,88557 1,67504 -740.29 6,002.150.47 497.915.51 0.00 -1,675.04 PROJECTED to TD Annotation ER i UGNES 1217/2016 3:39.40PM Page 4 COMPASS 5000.14 Build 850 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-13AL1PB2 50-103-20089-71 Baker Hughes INTEQ Definitive Survey Report 07 December, 2018 BA ER F UGHES a GEcomp ay ConocoPhillips ConocoPhillips "'�" p Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 3H-13 Wellbore: 3H-13AL1 PB2 Design: 3H-13AL1PB2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 3H-13 Local Coordinate Reference' TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Position +NIS 0.00 usR Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 31-1-13AL1PB2 Magnetics Modal Name Sample Data BGGM2018 11/1/2018 Design 3H-13AL1PB2 Audit Notes Version: 1.0 PhaseACTUAL Vertical Section: Depth From (TVD) (usft) 71 00 Well 3H-13 31-1-13A @ 71.00usff (31-1-13A) 3H -13A @ 71.00usft (31-1-13A) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 6,000,475.46usft Latitude: 498,655.42usft Longitude: usft Ground Level: Declination Dip Angle P) C) 16.83 80.91 Tie On Depth: ].731.25 +N/ -S (usft) 0 00 +E/ -W (usft) 0 00 Direction (1) 18000 70° 24'45.119 N 150° 0'39.419 W 0.00 Usti Field Strength (nT) 57,435 1217/2018 3:41:38PM Paye e COMPASS 5000.14 Build 65D ConocoPhillips BT H� ConocoPhilli s-=mmroM p Definitive Survey Report Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Well 31-1-13 N +N/43 Project: Kuparuk River Unit TVD Reference: 3H -13A @ 71.00usft (3H -13A) VerticalDSS Site. Kuparuk 3H Pad (°) MD Reference: 31-1-13A @ 71.00usft (31-1-13A) (usft) (ustt) Wen. 3H-13 Fasting North Reference: True Survey Tool Name Annotation Wellbore: 3H-13AL1PB2 Survey Calculation Method: Minimum Curvature Design. 3H-13ALiPB2 (°1100') Database: EDT 14 Alaska Production 7,731.25 Survey Program 168.76 Date -5,933.05 2,987.41 537.57 6.003,462.67 From TO -2,987.41 MWD l4) TIP Survey Survey lush) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 95.00 5,900.00 31-1-13 (31-1-13) GCT -MS Schlumberger GCT multishot 1/12/2001 170.08 6,113.56 7,260.49 3H-13AATDB(31-1-13A) MWD MWD -Standard 9/18/2001 092 7.340.00 7,390.33 3H-13AL1P81 MWD-INC(3H-13ALiPS1 MWD -INC -ONLY MWD -INC _ONLY -FILLER 10/24/2018 10/24/2018 7427.83 7,731.25 3H-13ALiPB1 MWD(3H-13ALiP61) MWD MWD - Standard 10/24/2018 10/27/2018 7,745.00 7,778.89 3H-13AL1PB2 MWD-INC(3H-13AL1PB2 MW0.1NC_ONLY MWD -INC _ONLY -FILLER 10/28/2018 10/28/2018 7,810.00 10,500.39 3H-13AL1PB2 MWD(3H-13AL1PB2) MWD MWD - Standard 10/28/2018 10/31/2018 Survey MD Inc Azl ND N +N/43 +E1 -W Map Map DLS VerticalDSS (usft) (°) (°) (usft) (usft) (ustt) (usft) Northing Fasting Section Survey Tool Name Annotation iftl (ft) (°1100') (ft) 7,731.25 92.12 168.76 6,004,05 -5,933.05 2,987.41 537.57 6.003,462.67 498,118,44 12.16 -2,987.41 MWD l4) TIP 7.745.00 91.92 169.82 6.003.57 -5,932.57 2.973.91 535.02 6,003,449.16 498,120.99 7.84 -2.973.91 MWD -INC _ ONLY (5) KOP 7,778.89 92.09 170.08 6,002.38 -5,931.38 2,940.56 529.11 6,003,415.82 498,126.89 092 -2,940.56 MWD -INC ONLY(5) Interpolated Azimuth 7,810.00 95.44 170.31 6,000.34 -5,929.34 2,909.97 -523.83 6,003,385.23 498,132.17 10.79 -2,909.97 MWD (6) 7,839.00 96.15 172.15 5,99741 -5,926.41 2,681.46 -519.43 6.003,356.72 498,13656 6.77 -2,88146 MWO(6) 7,869.96 97.07 173.49 5,993.85 -5,922.85 2,850.95 -515.58 6,003,326.21 498.14040 5.23 -2.850,95 MWD (6) 7,899.51 96.30 176.78 5,99041 -5,91941 2.821.71 -513.09 6,003,296.98 498,142.89 1136 -2.82171 MWD (6) 7.932.21 96.86 180.23 5,986.66 -5,915.66 2.789.24 -512.25 6,003,264.51 498,143.73 10.62 -2,789.24 MWD (6) 7,95902 95.99 181.69 5,983.66 -5,912.66 2,762.60 -512.69 6;003,237.88 498,143.28 6.31 -2,762.60 MWD (6) 7,990,71 94.12 184.45 5,98087 -5.909.87 2,731.09 514.38 6,003,206.36 498.141.58 10.49 -2,731.09 MWD (6) 8,01948 92.46 186.68 5,979.22 -5,908.22 2,702.50 -517.17 6,003,177.78 498,138.79 9.65 -2.702.50 MWD (6) 8,049.99 93.50 188.89 5,977.63 -5.906.63 2,672.32 521.30 6,003.147.60 498,134.66 8.00 -2,672.32 MWD (6) 8,079.97 91.87 190.14 5,976.22 -5,905.22 2,642.78 -526.25 6,003,118.07 498.129.70 6.85 -2,642.78 MWD (6) 8,109.17 91.60 192.15 5,975.34 -5,904.34 2,614.15 -531.89 6,003,089.44 498,124.06 6.94 -2,614.15 MWD (6) 8,139.23 9141 194.47 5,97455 -5,903.55 2,584.91 -538.81 6,003,060.21 498.117.13 7.74 -2,584.91 MWD (6) 8.169.19 90.52 19654 5,974.05 -5,90305 2,556.04 54681 6,003.031.35 498,109.12 7.52 -2,556.04 MWD (6) 8,199.31 9003 19948 5,973.90 -5.902.90 2.52740 -556.12 6,003 002 71 498,099.81 9.90 -2.52740 MWD (6) 8,229.27 89.60 201.67 5,974.00 -5,903.00 2499.36 -566.65 6,002,974.67 496,08927 745 -2,499.36 MWD (6) 12/7/2018 3:41:38PM Page 3 COMPASS 5000.14 Build 650 Survey MD ConocoPhillips Azi ConocoPhillips Definitive Survey Report +N/ -S Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 3H-13 Project. Kuparuk River Unit TVD Reference: 3H -13A @ 71.00usft (3H -13A) Stte< Kupamk 3H Pad MD Reference: 3H -13A @ 71.00usft (3HA3A) Well. 3H-13 North Reference: True Wellbore: 3H-13AL1PB2 Survey Calculation Method: Minimum Curvature Design 3H-13AL1PB2 Database: EDT 14 Alaska Production Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name (R) (ft) (ft) 8,259.34 8840 203.84 5,974.52 -5,903.52 2,47163 -578.28 6,002,94695 498.077.64 8.25 -2,471.63 MWD (6) 8,289.34 87,05 205.57 5,975.71 -5,904.71 2,444.40 -590.81 6,002,919.72 498.065,11 7.31 -2,444.40 MWD (6) 8.31936 87.45 203.21 5,977.15 -5,906.15 2.41709 -603.19 6,002,89242 498,052.73 7.96 -2,41709 MWD (6) 8,35052 88.19 200.40 5,97834 -5,907.34 2.388.19 -614.75 6,002,863.52 498,041.16 9.32 -2,388.19 MWD (6) 8,384.94 88.59 196.67 5,979.31 -5.90831 2.355.57 625.69 6,002,830.91 498.030.22 1089 -2.355.57 MWD (6) 8.410.70 88.59 19601 5,979.94 -5,908.94 2,330.T4 632.50 6,002,806.08 498,023.40 1032 -2,330.74 MWD (6) 6,441.47 9443 191.75 5,979.13 -5,908.13 2,300.77 -63936 6,002,776.11 498,016.54 2035 -2.300.77 MWD (6) 8,470.13 93.81 188.69 5,977.07 -5.906.07 2.272.64 644.43 6,002,747.99 498,01147 10.87 -2.272.64 MWD (6) 8,50142 90.18 184.69 5,9T5.98 -5,904.98 2,241.59 -648.07 6,002,716.95 498,00782 17.26 -2,241,59 MWD (6) 8,535.13 91.29 180.31 5,975.55 -5,90455 2,207.93 -649.54 6,002,683.28 498,006.35 1340 -2,207,93 MWD (6) 8,559.00 93.07 179.16 5,974.64 -5,903.64 2,184.08 -649.43 6,002,65943 498,006.45 888 -2,184.08 MWD (6) 8,689.33 9480 176.86 5,972.56 -5,901.56 2,153.84 -646.38 6,002,629.20 498,007.50 9.47 -2,153.84 MWD (6) 8,619.68 94.65 173.40 5,970.06 -5,899.06 2,123.71 -645.81 6,002,599.07 498,010.06 11.37 -2,123.71 MWD (6) 8,649.31 94.15 172.93 5.967.79 -5,896.79 2,094.37 -642.29 6,002,569.74 498,01357 2.31 -2,094.37 MWD (6) 8,678.39 92.89 iT1.81 5,966.00 -5,89500 2,065.51 -63844 6,002,540.97 498.01742 579 -2,065.61 MWO(6) 8,708.33 90.80 16973 5,965.04 -5,894.04 2036.07 -631(Pl 6,002,511.44 498,022.21 9.85 -2,036.07 MWD (6) 8,738.74 88.77 16794 5,965.15 -5,894.15 2,00624 -627.75 6,002,481.61 498,028.09 8.90 -2,006.24 MWD (6) 8,769.47 8606 168.98 5,966.00 -5,895.00 1,976.14 -621.61 6,002,451.52 498,034.23 4.10 -1,976.14 MWD (6) 8,799.12 88.37 171.67 5,966.92 -5,895.92 1,946.93 -616.63 6,002.422.31 498,039.21 9.13 -1,94693 MWD (6l 8,829.53 87.89 174.73 5,967.97 -5,896.97 1,91876 -613.03 6,002,392.14 498,042.80 10.30 -1,91676 MWD (6) 8,864.11 88.28 177.31 5,969.19 -5,698.19 1,882.29 610.63 6.002.357.67 498.045.19 7,65 -1,882.29 MWD (6) 8,897.86 88.95 179.74 5,970.00 -5,899.00 1,848.54 609.76 6.002,323.92 498,045.05 746 -1,848.54 MWD (6) 8,920.06 89.20 181.52 5,970.36 -5,899.35 1.826.36 61001 6,002,30175 498.045.80 8.10 -1,826.36 MWD (6) 8,949.33 88.56 183.44 5,970.93 -5,899.93 1,797.13 -611.27 6,002,272.52 498,04453 6.91 -1,797.13 MWD (6) 8,974.75 87,85 185.82 5,971.73 -5.900.73 1,TT1.81 -613.32 6,002.24T.20 498,042.48 9.77 -1,771.81 MWD(6) 9,015.37 85.42 189.03 5,974.11 -5,903.11 1731.60 -618.56 6,002,207.00 498.037.23 9.90 -1,731.60 MWD (6) 9,043.33 85.66 191.42 5,976.29 -5,905.29 1,704.17 623.51 6,002,179.58 498,032.28 8.57 -1,704.17 MWD (6) 9,076.09 87,91 193.66 5,978.13 -5,907.13 1,672.25 -630.61 6,002.147.66 498025.17 968 -1,67225 MWD (6) 9,105.97 88.16 196.58 5,979.15 -5,908.15 1.64342 -638.40 6,002,118.84 498,01738 9.80 -1.643.42 MWD J6) 9.146.11 86.99 20133 5,980.85 -5,909.85 1,605.51 -65142 6,002,080.92 498.004.35 12.18 -1605.51 MWD (6) 9.176.07 89.26 203.75 5,98183 -5,910.83 1,57785 662.90 8002.053.28 49T,992.87 1107 -1,577.85 MWD (6) Annotation eA ER F�I/GHES 12/7/2018 3:41:38PM Page 4 COMPASS 5000.14 Build 85D ✓ ConocoPhillips ConocoPhillipsER Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 31-1-13 Project: Kuparuk River Unit TVD Reference: 31-1-13A @ 71.00usft (3H -13A) Site: Kuparuk 3H Pad MD Reference: 31-1-13A @ 71.O0usft (31-1-13A) Well, 31-1-13 North Reference: True Wellbore: 3H-13AL1PB2 Survey Calculation Method: Minimum Curvature Design 3H-13AL t PB2 Database: EDT 14 Alaska Production Survey MD Inc ND N +N/+N/-S-El-V1-El-V1Northing Map Map OLS Vertical (usft) (°) (°) (1) (usft) rush) sft) (usR) (ustt) Easting Section Survey Tool Name Annotation (K) (ft) (ft) 9,270.52 87.12 204.64 5,982.92 -5,911.92 1,54645 -677.01 6,002,021.88 497,978.76 6.73 -154645 MWD (6) 9,239.81 86.99 205.85 5,983.91 -5,912.91 1,519.97 689.49 6,001,99541 497.96627 762 -1.519.97 MWD (6) 9.261.94 88.77 209.30 5,984.40 -5,913,40 1,497.71 -701.13 6,001,973.14 497,954.63 13.71 -1,497.71 MWD (6) 9,294.13 87.58 21146 5,985.33 -5,914.33 1,472.54 -71588 6,001,947.98 497.939.88 8.45 -1,472.54 MWD (6) 9,324.43 8647 212.82 5,986.91 -5,91591 1,446.92 -731.96 6,001,922.37 497,923.78 5.79 1446.92 MWD (6) 9,35415 86.44 210.71 5,988.78 -5,917.78 1,421.19 -747.91 6,001,896.64 497,907.84 6.95 -1,421.19 MWD (6) 9,385,37 87.08 20643 5,990.51 -5,919.51 1.394,60 -762.99 6,001,870.06 497.892]6 772 -1,394.60 MWD (6) 9.414.63 87.33 206.03 5,991.94 -5.920.94 1.368.62 -776.36 6,001,844.06 497,879.38 8.24 -1.368.62 MWD (6) 9445.05 88.26 203.92 5,993.10 -5,922.10 1,341.07 -78920 6,001,816.53 497,86654 7.60 -1,341.07 MWD (6) 9,480.15 91.48 20260 5,993.18 -5,922.18 1,308.82 -803.05 6,001,784.30 497.852.68 9.86 -1,308.82 MWD (6) 9,520.25 93.69 200.50 5,991.37 -5,920.37 1,271.57 -817.77 6,001,747.05 497,837.96 160 -1,271.57 MWD (6) 9,550.35 94.65 197.82 5,989.18 -5,916.18 1,243.21 -827.62 6001,718.70 497,828.11 9.44 -1,243.21 MWD (6) 9,580.36 96.22 196.70 5,986.34 -5,915.34 1,21469 $36.48 6,001,690.18 497,819.24 642 -1,214.69 MWD (6) 9,611.63 95.29 193.54 5.963.20 -5,912.20 1.184.66 -844.6D 6.001,660.15 497,811.12 10.49 -1,184.66 MWD (6) 9,644.55 95.02 190.93 5,960.24 -5,909.24 1,152.62 -851.55 6,001,628.11 497,804.17 7.94 -1,152.62 MWD (6) 9.675.76 94.39 185.91 5,977.68 -5,906.68 1,121.86 -856.10 6,001,597.36 497,799.61 16.16 -1,12116 MWD (6) 9,700.83 92.98 185.53 5,976.07 -5,905.07 1,096.96 -858.59 6,001,57247 497,797.11 582 -1,09698 MWD (6) 9.728.69 93.66 18267 5,97446 5.903.46 1,06922 -860.58 6,001,544.73 497,795.12 10.53 -1,069.22 MWD (6) 9,765.13 94,03 179.07 5,972.01 -5,901.01 1,03288 -861.13 6,001,508.39 497,794.56 9.91 -1,032.88 MWD (6) 9,795.47 92.55 177.10 5,97027 -5,899,27 1,002.61 -860.12 6,001,476.12 497,79557 8.11 -1,002.61 MWD (6) 9,825.13 92.40 174.41 5,968.99 -5,897.99 973.06 -857.93 6.001,448.57 497.797.75 9.08 -973.05 MD (6) 9,860.35 92.43 176.61 5.967.5D -5,896.50 937.98 -855.17 6,001,413.50 497,800.50 6.24 -937.98 MD (6) 9,896.09 91.88 178.86 5.966.16 -5,895.16 902.29 -853.76 6.001,377.82 497.801.91 6.48 -902.29 MWD (6) 9,93187 9301 18242 5,964.63 -5,893.63 866.56 -854.16 6,001,342.08 497,801.50 10.43 -866.56 MWD (6) 9,96525 9347 185.60 5,962.75 -5,89175 83332 -85649 6,001,308.85 497,799.17 set -833.32 MWD (6) 9,996.27 9D83 186.54 5,961.58 -5,890.58 80249 -85977 6,001,278.03 497,795.88 903 -80249 MWD (6) 10,026.05 88.37 186.74 5,96179 -5,890.79 772.92 -86321 6,001,248.45 497,79244 8.29 472.92 MWD(6) 10,05635 85.61 187.11 5,963.38 -5,892.38 742.88 -866.86 6.0D1,21e42 497,788.78 9.19 .742.88 MWD (6) 10,091.64 84.16 186.92 5,966.53 -5.895.53 708.08 -871.76 6,001,183.62 497,783.88 656 -70608 MWD (6) 10.115.87 8485 19171 5.968.89 -5,89189 65,136 -676.08 6.001,159.91 49].779.56 1164 -684.36 MWD (6) 10,147.25 8456 194.56 5,97184 -5,900.84 653.94 -883.17 6,001,129.49 497,772.45 9.05 -65394 MWD (6) 1277/2018 3:41:38PM Page 5 COMPASS 5000 14 Build 85D Annotation TI1GHE5 0 12/712018 3.41:38PM Page 6 COMPASS 5000.14 Build 850 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 3H-13 Project: Kuparuk River Unit TVD Reference: 31-1-13A @ 71.00usft (31-1-13A) Site. Kuparuk 3H Pad MD Reference: 3H -13A Q 71.00usft (3H -13A) Well: 31-1-13 North Reference: True Wellbore: 3H-13AL1PB2 Survey Calculation Method: Minimum Curvature Design: 3H-13AL1PB2 Database: EDT 14 Alaska Production Survey MD Inc Azl TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (I V) lush) (usft) (usft) Northing Neal Easting (°1100') Section Survey Tool Name (ft) (ft) (ft) 10.175.91 84.43 196.83 5.974.59 -5,903.59 626.47 890.89 6,001,102.03 497,764.73 190 -626.47 MWD (6) 10,20165 8509 19966 5,977.49 -5,90649 596.46 -900.79 6,001,072.02 497,754.83 9.12 -596.46 MWD(6) 10,235.93 83.66 202.89 5,980.26 -5.90026 57024 -910.99 6,001.04580 497,744.62 1244 -570.24 MWD (6) 10,267.62 8315 207.14 5.983.90 -5,912.90 541.72 -924.30 6,001,017.29 497,731.31 13.42 -541]2 MWD (6) 10,295.58 83.21 210.92 5,987.23 -5,91623 517.45 -937.77 6,000.993.02 497.717.83 13.43 -517.45 MWD (6) 10,325.80 83.14 210.81 5.990.82 -5,919.82 491.69 -953.17 6,000,967.27 497.702A4 0.43 491.69 MWD(6) 10,355.52 8345 212.54 5,994.29 -5,923.29 46657 -968.66 6,000,942.16 497,686.94 5.87 466.57 MWD (6) 10,385.57 83.51 21545 5,997.70 -5,926.70 441.82 -985.36 6000,91141 497,670.24 9.62 441.82 MWD (6) 10.415.70 82.86 216.93 6.001.28 -5,930.28 417.68 -1.003.02 61000,893.27 497,652.58 5.33 417.68 MWD (6) 10,40.85 80.23 21865 6,00497 -5,93397 397.76 -1,017.92 6,000,873.36 497,637.68 10.52 -39776 MWD (6) 10,470.49 77.03 21700 6,01082 5,939.82 374.50 -1,035.33 6,000,850.11 497,620.26 1086 -374.50 MWD(6) 10,500.39 73.69 216.68 6,018.37 -5,94137 35185 -1,052.67 6,000,826.96 497,602.91 1122 -351.35 MWD (6) 10,535.00 73.69 21668 6,028.09 -5,957.09 32411 -1,072.52 6,000,800.33 497,563.07 0.00 -32471 PROJECTED to TD Annotation TI1GHE5 0 12/712018 3.41:38PM Page 6 COMPASS 5000.14 Build 850 �-I ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-13AL1PB3 50-103-20089-73 Baker Hughes INTEQ Definitive Survey Report 07 December, 2018 BA ER t UGHES a CE company a ER ConocoPhilliConocoPhillips p s`'`" Definitive Survey Report company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 3H-13 Project Kuparuk River Unit TVD Reference: 3H-13A Q 71.00usft (3H-13A) Site: Kupamk 3H Pad MD Reference: 3H-13A @ 71.00usft (3H-13A) Well: 3H-13 North Reference: True Wellbore: 3H-13ALiPB3 Survey Calculation Method: Minimum Curvature Design: 3H-13ALiPB3 Database: EDT 14 Alaska Production 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 Well 3H-13 Well Position +N/-S 0.00 usft Northing: 6,000.475.46usft Latitude: 70'24'45.119 N +E/-W 0.00 usft Easting: 498,655.42 usft Longitude: 150° 0'39.419 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3H-13AL1P83 Magnetics Model Name Sample Date Declination Dip Angle Field Strength P) (') (nT) BGGM2018 lV1/2018 16.83 80.91 57,435 Design 3H-13AL1PB3 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7.260.49 Vertical Section: Depth From (TVD) -NI-S +E/-W Direction (usft) (usft) (usft) 11 71.00 0.00 0.00 180.00 Survey Program Date From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Data End Date 95.00 5,900.00 31-1-13 (3H-13) GCT-MS Schlumberger GCT multishot 1/12/2001 6,113.56 7,260.49 3H-13AATDB(31-1-13A) MWD MWD-Standard 9/18/2001 7,315.00 7,396.26 3H-13AL1P63 MWD-INC(3H-13ALiPB3 MWD-INC—ONLY MWD-INC_ONLY_FILLER 11/11/2018 11/11/2018 7,426.34 8,766.05 3H-13AL1 P63 MWD (3H-13AL7 PB3) MWD MWD-Standard 11/11/2018 11/13/2018 1217/2018 3:43:52PM Page 2 COMPASS 5000.14 Build 65D �- ConocoPhillips ConocoPhillips Definitive Survey Report AN Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 31-11-13 Project: Kuparuk River Unit TVD Reference: 31-11-13A Q 71.00usft (3H -13A) Site: Kuparuk 3H Pad MD Reference: 31-11-13A Q 71.00usft (31-1-13A) Well: 3H-13 North Reference: True Wellbore: 3H-13ALiPB3 Survey Calculation Method: Minimum Curvature Design. 3H-13AL1PB3 Database: EDT 14 Alaska Production Survey MD Inc AN TVD TVDSS +WS +E1 -W Map Map DLS Vertical (usfl) (°) (•) (usfl) (usfl ) (usfl) (uafl) Northing Basting (°/100') Section Survey Tool Nam( Ifl1 (fl) (fl) 7,260.49 57.88 31.70 5,944.06 -5,873.06 2,976.09 -636.14 6,003,451.40 497,819.90 0.40 -2,976.09 MWD-INC_ONLY (3) 7,315.00 5822 31.81 5,972.91 -5,901.91 3,D1542 -811.80 6,003,49072 497,844.25 0,65 -3,01542 MWD -INC _ONLY (3) 7,33693 61,54 31.81 5,983.91 -5,912.91 3,031.53 -801.80 6,003,50683 497,854.24 15.14 -3,031.53 MWD-INC_ONLY (3) 7,366.82 74.4 31.81 5,994.99 -5,923.99 3,05596 -78721 6,003,530.36 497,868.84 4450 -3,055.06 MWD -INC _ONLY (3) 7,396.26 88.40 31.81 5,999.27 -5,928.27 3,079.76 -771.89 6,003,555.05 49T,884.16 46.06 -3.079.76 MWD -INC _ONLY (3) 7.426.34 99.27 31.67 5,997.26 -5,926.26 3,105.24 -756.13 6,003,580.53 497,899.93 36.14 -3,105.24 MWD (4) 7,456.57 97.82 46.59 5,992,T4 -5,921.74 3,128.36 -737.31 6,003,603.54 497,91815 49.04 -3,128.36 MWD (4) T,486.47 95.04 60.96 5,98938 -5,91838 3,145.86 -713.40 6,003,621.13 497,942.66 48.65 -3,145.86 MWD (4) 7,516.26 93.75 76.30 5,987.08 -5,916.08 3,156.65 -68582 6.003A31 91 497.970.23 5152 -3,156.65 MWD (4) 7,546.81 93.10 92.51 5.985.25 -5,914.25 3.159.81 555.58 6.003,634 87 498,000.48 53.01 -3,159.61 MWD (4) 7,576.27 91.20 106.57 5,984.13 -5,913.13 3,154.74 -626.62 6,003,630.00 498,02943 48.12 -3,154.74 MWD (4) 7,608.16 90.18 122.75 5,963.74 -5,912.74 3.141.23 -597.19 6,003,61648 498,058.85 49.89 3,141.23 MWD (4) 7,640.06 90.00 138.37 5,983.69 -5.912.69 3,120.94 57349 6,003,596.19 498,082.55 49.91 -3,120.94 MWD (4) 7,67087 91.01 153.51 5,983.42 -5,912,42 3,095.49 55628 6,003,570]4 498.099.75 4925 -3,095.49 MWD (4) 7,700.85 90.06 168.30 5,983.14 -5,912,14 3,06724 -546.50 6,003,542.49 498,109.52 49.43 -3,06T.24 MWD(4) 7,731.66 89.94 183.97 5,983.14 -5,912.14 3.038.60 544.43 6.003,511.85 498,111.59 50.86 -3,036.60 MWD (4) 7,76303 89.79 19641 5,983.21 -5,912.21 3,005.78 -549.97 6,003.481.04 498,10604 3966 3,005.78 MWD (4) 7,79321 89.26 198.86 5,983.46 -5,912.46 2,977.02 -559.11 6,003,452.29 498,096.90 8.31 -2,977.02 MWD (4) 7,822.54 8893 198.57 5,983.92 -5,912.92 2949.25 -568.52 6.003,424.51 498.08748 1.50 -2.949.25 MWD (4) 7,854.65 89.91 200.73 5,984.25 -5,91325 2,919.01 5T9.32 6,003,394.26 498,076.68 7.39 -2,919.01 MWD(4) 7,682.68 89.51 202.42 5,984.39 -5,913.39 2.892.95 589.63 6,003,368.22 498,066.37 6.20 -2.892.95 MWD (4) 7,915.07 89.94 202.80 5,984.55 -5,913.55 2,863.05 -602.09 6,003.338.33 498,053.91 1.86 -2,863.05 MWD (4) 7,943.18 8988 200.64 5,984.59 -5,913.59 2.836.94 -612.50 6,003,312.23 498.043.49 7.83 -2,836.94 MD (4) 7,973.65 9190 200.83 5,964.12 -5,913.12 2,60845 523,29 6,003,283.74 498,032.70 6.66 -2,808.45 MWD(4) 8,006.15 92.58 199.34 5,982.85 -5,911.85 2,777.95 534.44 6,003,253.25 498,021.55 504 -27T795 MWD(4) 8.033.20 92.27 196.71 5,981.7D -5,910.70 2,752.25 542.80 6,003,227.55 498,013.18 9.78 -2.752.25 MWD (4) 8,063.60 92.91 194.18 5,980.33 -5,909.33 2,722.98 550.89 6,003,198.29 498,005.09 858 -2.72298 MWD (4) 8,092.57 93.99 196.59 5,978.59 -5,907.59 2,695.10 -658,56 6,003,170.41 497,99741 9.10 -2,695.10 MWD(4) 8,121.33 94.48 197.51 5,976.45 -5,90546 2.667.68 -666.97 6,003,143.00 497,989.00 3.62 -2,667.68 MWD (4) 8,153.06 93.59 198.71 5,974.23 -5,903.23 2.637.60 -676.81 6,003,112.92 497.979.16 4.70 -2637.60 MWD (4) BA ER F U, HES 11 Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 121712018 3:43:52PM Page 3 COMPASS 5000.14 Build 65D Survey MD ConocoPhillips Axl ConocoPhillips Definitive Survey Report +NIS Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 31-1-13 Project: Kupamk River Unit TVD Reference: 31-1-13A @ 71.0Ousft (311-13A) Site: Kuparuk 3H Pad MD Reference: 3H -13A @ 71.00usft (31-1-13A) Well: 31-1-13 North Reference'. True Wellbore: 3H-13ALIPB3 Survey Calculation Method: Minimum Curvature Design: 3H-13AL1PB3 Database: EDT 14 Alaska Production Survey MD Inc Axl TVD TVDSS +NIS +E/ -W Map Map DLS Vertical (usft) (°) (°) (usft) Instill (usft) (usft) Easbng (01100') Section Survey Tool Name (ft)(ft) (ft) 8,182.15 92.82 200.43 5,972.60 -5,90160 2,610.24 88653 6,003,.085.58 497.969.42 6.47 -2,810.24 MWD (4) 8,212.92 92.15 201.87 5.971.27 -5,900.27 2.581.57 .697.63 6.003.056.89 497.958.33 5.16 -2,561.57 MWD (4) 6,252.57 91.81 205.66 5,969.90 -5,89890 2.545.31 -713.59 6,003,020.64 497,942.36 9.59 -2,545.31 MWD (4) 8.272.85 90.95 207.46 5,969,41 -5,89841 2.527.17 -722.66 6,003,00251 497,933.29 983 -2,527.17 MWD(4) 8,304.85 8963 208.56 5,969.25 -5,898.25 2,498.92 -737.68 6,002,974.27 497,918.26 5.37 -2,498.92 MWD (4) 8,331.50 8634 208.93 5,969.72 -5,896.72 2,475.56 -750.50 6,002,95091 497,905.44 5.04 -2,475.56 MWD (4) 8.366.21 86.99 207,07 5.W1.13 -5,900.13 2.444.94 -766.78 6,002,920.30 497,889.16 6.62 -2,444.94 MWD (4) 8,407]9 87.14 203.44 5,973.26 -5,902.26 2.407.39 -784.49 6,002.882.75 497.871.44 613 -2,407.39 MWD (4) 6,438.37 8847 201.61 5,974A3 -5,903.43 2.379.17 -796.20 6,002,854.53 497.859.73 7.39 -2379.17 MWD (4) 8,46837 88.50 200.79 5,975.23 -5,904.23 2,35121 -807.04 6,002,826.58 497,84888 2.73 -2,351.21 MWD (4) 8,497.67 90.83 197,46 5,975.40 -5,904.40 2,323.53 576.64 6,002,798.91 497,839.28 13.87 -2,323.53 MWD (4) 8,526.13 91.14 195.84 5,974.91 -5,903.91 2,296.27 82459 6,002,771.65 497,831.12 5.79 -2,296.27 MWD (4) 8,558.81 86.06 192.96 5,975.12 -5,904.12 2,26675 -83237 6,002,742.14 497,823.54 13.83 -2,268.75 MWD (4) 8,587.65 87.39 191.64 5,976.35 -5,905.35 2,236.45 -838.98 6,002,711.84 497,816.93 4.77 -2,236.45 MWD (4) 8,618.09 87.97 189.23 5,97759 -5,906.59 2.206.50 -844.49 6,002,681.93 497,811.42 8.14 -2,206.54 MWD (4) 8,648.42 88.00 187.79 5,978.65 -5,90165 2.176.57 448.97 6,002,651.96 497,80892 4.75 -2,176.57 MWD (4) 8,676.89 89.09 186.11 5,979.38 -5,908.38 2,148.32 552.42 6,002,623.71 497,80348 7.03 -2,148.32 MWD(4) 8,70749 89,05 185.29 5,979.87 -5,906.87 2,11187 555.45 6,002,593.27 497,80043 2.68 -2117.87 MWD (4) 8,735.93 8B96 181.82 5.960.37 3,909.37 208949 -857.22 6,002,56490 497,798.66 12.20 -2,08949 MWD (4) 8.766.05 88.62 180.38 501.00 -5.910.00 2,059.39 -857.80 6,002,534.80 497,79808 4.91 -2,059,39 MWD (4) 8.810.00 88.62 180.38 5,982.06 -5,911.06 2015.45 -858.09 6,002.490.86 497.797.78 000 -2,015.45 PROJECTED WTD Annotation RATER 0 GFIFS 12172018 3:43.'52PM Page 4 COMPASS 5000 14 Build 850 AER %i PRINT DISTRIBUTION LIST UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3H-13AL1 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 (FEDU N1LL NDT DELIVER TO P.O. WK) PERSON ATTENTION V t BP North Slope. EOA, PBOC, PR&20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc Atm: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 EssonVlohil, Alaska Ann: Lunda M. Vaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC .Attn: Natural Resources Technician II 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 218135 301 ie sign and return one copy of this transmittal form to: 3coPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. is ra¢e. Alaska 99510 data. LOG TYPE GR - RES LOG DATE November 19, 2018 TODAYS DATE December 11, 2018 Revision Details: Rev. Requested by: --- FIELD I FINAL CD/DVD FINAL PRELIM (las, dlis, PDF, META, SURVEY I REPORT LOGS LOGS CGM, Final Sury (Compass) # OF PRINTSur rKuN # OF COPIES I# OF COPIES # OF COPIES lu jj 4 lu 4 jj 0 1 0 1 0 R�G�3 2p1� 0 1 1 1 1 1 0 10 5DNR- Division ofOil&Gas *** 0 0 1 0 0 'Atm: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 #** Stamp "confidential" on all material deliver to DNR 61 BP Exploration (Alaska) Inc. 0 0 1 0 0 Petrotechnical Data Center, IR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 3 0 0 BA . M PRINT DISTRIBUTION LIST a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3H-13ALiPB1 FIELD Greater Kuparuk Area 210135 30111 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 to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(cDbakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT OELPIER TO P.O. BOX) PERSON ATTENTION t BP North Slop EDA, PROC, 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 ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOCCC Atm: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 S ',DNR -Division ofOil&Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 GR - RES LOG DATE November 19, 2018 TODAYS DATE December 11, 2018 Revision No Details: Rev. Requested by: --- FIELD I FINAL CD/DVD FINAL PRELIM I (las, dlis, PDF, META, SURVEY I REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTSV Ur VKIN # OF COPIES IPUFCOPIES # OF COPIES Pp 0 0 0 0 0 *** Stamp "confidential" on all material deliver to DNR 6 611 Exploration (Alaska) Inc. L 0 0 0 0 Petrotechnical Data Center, IR2-I 900 E. Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 3 0 0 I BAER PRINT DISTRIBUTION LIST UG" Mi a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3H-13AL1PB2 FIELD Greater Kuparuk Area COUNTY North Slope Borough L1�135 30112 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 to acknowledge receipt of this data. LOG TYPE GR - RES BHI DISTRICT Alaska LOG DATE November 19, 2018 AUTHORIZED BY Patrick Rider EMAIL TODAYS DATE December 11, 2018 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION ,a ) BP North Slope. LOA, PBOC. PRB-20 (Office 109) D&G WO Wells Admin Brenda Glassmakcr & Peggy O'Neill 900 E. Benson Blvd. Anchorage. Alaska 99.508 2 ConocoPhillips Alaska Inc. .Attn: Ricky Elgarico 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 Attn: Natural Resources Technician 11 '.333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 FIELD I FINAL CD/DVD FINAL PRELIM (las, dlis, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES Ig OF COPIES 1# OF COPIES [] 0 V � 10% p 1 A� 1 0% 0 1 1 1 0 1 0 5 DNR - Division ofOil & Gas "* 0 0 1 0 0 Attn: Resource Evaluation 550 West7th Avenue, Suite 1100 Anchorage, Alaska 99501 L* Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. I 0 0 1 0 0 Petrotechnical Data Center, 1R2-1 900 E. Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 3 0 0 BAKER PRINT DISTRIRITTION LIST _gUGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3H-13AL FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT AUTHORIZED BY Patrick Rider EMAIL Patriakerhughes.com 118135 30113 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 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE November 19, 2018 TODAYS DATE December 11, 2018 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION I 'BP North Slope. F.OA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. .Anchorage. Alaska 99508 FIELD / FINAL CDIDVD FINAL SURVEY REPORT PRELIM (las, dlis, PDF, META, LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES 4 4 jj 4 jj 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico o�c GGG ATO 708 700 G Street (�O ,Anchorage, AK 99510 _ — _ _ r — — _ — — 0 0 3 ExxonMobik Alaska ,Atm: 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 5DNR -Division ofOil&Gas *** Atm: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage,Alasln 99501 . *** Stamp "confidendal" on all =metal deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 3 0 0 BA (ER UGHES a GE company El Date: December 7, 2018 Abby Bell AOGCC 333 West 7" Ave, Suite 100 Anchorage, Alaska 99501 Z►81W5 30081 Letter of Transmittal Michael Soper Baker Hughes, a GE Company 795 East 94" Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 3H-13AL1PB1 3H-13AL1PB2 3H-13AL1-01PB1 31H-13AL11PB3 3H-13AL1 3H-13AL1-02 3H-13AL1-03 (7) Total prints RECEIVED DEC 10 2018 AOGCC 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@BakerHughes.com 21135 30081 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-13AL1 50-103-20089-60 Baker Hughes INTEQ BAT GHES a GE company Definitive Survey Report 07 December, 2018 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kupamk River Unit TVD Reference: Site: Kupamk 3H Pad MD Reference: Well: 31-1-13 North Reference: Wellbore: 3H-13AL1 Survey Calculation Method: Design: 3H-13AL1 Database: Well 31-1-13 ` 3H -13A @ 71.00usft (3H -13A) 3H -13A @ 71.00usft (3H -13A) True Minimum Curvature EDT 14 Alaska Production 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 Well 3H-13 Well Position +N/.S 0,00 usft Northing: 6,000,475.46usft Latitude: +E/ -W 0.00 usft Easting: 498,655.42usft Longitude: Position Uncertainty 0 00 usft Wellhead Elevation: usft Ground Level: Wellbore 3H-13AL1 - Magnetics Model Name Sample Date Declination P) Dip Angle (1) BGGM2018 11/9/2018 16.82 80.91 Design 31-1-13AL1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,97365 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 71.00 0.00 0.00 180.00 R UGC 70° 24'45+119 N I` 150°0'39.419W 9 0.00 usft i Field Strength (nT) 57,434 12/712018 3:44: 27PM Page 2 COMPASS 5000.14 Build 85D ConocoPhilli s BA� "EConocoPhilli s Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 31-1-13 Project: Kuparuk River Unit TVD Reference: 3H -13A @ 71.00usft (3H -13A) Site: Kuparuk 3H Pad MD Reference: 3H -13A @ 71.00usft (3H -13A) ). Well: 31-1-13 North Reference: True Wellbore: 31-1-13AL1 Survey Calculation Method: Minimum Curvature Design: 3H-13AL1 Database: EDT 14 Alaska Production ;., Survey Program Inc Date N 7VDSS +N/ -S -E/-W From To DLS Vertical Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Data End Date 95.00 5,900.00 31-1-13 (31-1-13) GCT -MS Schlumberger GCT multishot 1/12/2001 i (fit) (k) (ft) 6,113.56 7,260.49 3H-13AATDB(31-1-13A) MWD MWD -Standard 9/18/2001 2,808.45 7,315.00 7,396.26 31-1-13AL1 PB3 MWD -I NC(3H-13AL1 PB3 MWD-INC_ONLY MWD-INC_ONLY_FILLER 11/11/2018 11/11/2018 i 7,426.34 7,973.65 31-1-13AL1 PB3 MWD (3H-13AL1 PB3) MWD MWD- Standard 11/11/2016 11/13/2018 7,999.00 8,030.53 31-1-13AL1 MWD -INC (31-1-13AL1) MWD4NC_ONLY MWD-INC_ONLY_FILLER 11/14/2018 11/14/2018 8,060.80 10,065.97 3H-13AL1 MWD (3H-13AL1) MWD MWD -Standard 11/14/2018 11/15/2018 j¢r Survey MD Inc Aid AD N 7VDSS +N/ -S -E/-W Map Map DLS Vertical (waft) (I (I (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name (fit) (k) (ft) 7,973.65 91.90 200.83 5,984.12 -5,913.12 2,808.45 -623.29 6,003,283.74 498,032.70 6.66 -2,808.45 MWD (4) 7,999.00 92.43 199.67 5,983.16 -5,912.16 2,784.68 -632.05 6,003,259.98 498,023.93 5.03 -2,78468 MWD -INC -ONLY (5) 8,030.53 89.20 198.50 5,982.71 -5,911.71 2,754.89 642.36 6,003,230.19 498,013.62 10.90 -2,754.89 MWD -INC -ONLY (5) 8,060.80 88.34 199.75 5,983.36 5,912.36 2,726.30 652.27 6,003,201.61 498,003.70 5.01 -2,726.30 MWD (6) 8,089.81 89.91 200.48 5,983.80 -5,912.80 2,699.07 662.25 6,003,174.38 497,993.72 5.97 -2,699.07 MWD (6) 8,120.51 92.06 201.59 5,983.28 -5,912.28 2,670.42 673.27 6,003,145.73 497,982.70 7.88 -2,670.42 MWD (6) 8,150.38 92.77 202.19 5,982.02 -5,911.02 2,642.73 684.39 6,003,11805 497,971.57 3.11 -2,642.73 MWD (6) 8,180.36 93.38 203.99 5,980.41 -5,909.41 2,615.19 696.13 6,003,090.51 497,959.83 6.33 -2,615.19 MWD (6) 8,210.33 93.57 206.10 5,97859 5,907.59 2,58809 -708.80 6,003.063.42 497,997.16 7.06 -2,588.09 MWD (6) 8,240.13 93.57 208.13 5,976.74 -5,905.74 2,561.62 -722.35 6,003,036.95 497,93360 6.80 -2,561.62 MWD(6) 8,270.47 9225 210.10 5,975.20 -5,904.20 2,535.15 -737.09 6,003,01049 497,918.86 7.81 -2,535.15 1(6) 8,300.61 91.51 211.45 5,974.21 -5,903.21 2,509.27 -752.51 6,002,984.61 497,903.44 5.11 -2,509.27 MWD (6) 8,330.38 9141 212.81 5,973.45 -5,902.45 2,48906 -768.33 6,002,95941 497,88761 4.58 -2,484.06 MWD(6) 8,36041 91.14 21242 5,972.78 5,901.78 2,458.78 -784.52 6,002,934.13 497,871.42 1.58 -2,458.78 MWO(6) 8,390.43 89.51 211.54 5,972.61 -5,901.61 2,433.31 -8DO,41 6,002,908.67 497,855.52 6.17 -2,433.31 MWD (6) 8,42033 88.89 209.38 5,973.03 -5,902.03 2,407.54 -815.57 6,002,882.91 497,840.37 7.52 -2,407.54 1(6) 8,450.25 88.99 207.92 5,973.58 -5,902.58 2,381.29 -829.91 6,002,855.66 497,826.02 4.89 -2.381.29 MWD (6) 8,480.22 90.09 206.02 5,97382 -5,90282 2354.58 -843.50 6.002,829.96 497,81243 7.33 -2,35456 MWD (6) 1217/2018 3: 44.27PM Page 3 Annotation TIP KOP Interpolated Azimuth COMPASS 5000.14 Build 85D ✓ ConocoPhillipsER UGHES ConocoPhillips Definitive Survey Report """""" Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 3H-13 Project Kuparuk River Unit TVD Reference: 3H -13A @ 71.00usft (3H -13A) Site: Kuparuk 3H Pad MD Reference: 3H -13A @ 71.00usft (3H -13A) Well: 3H-13 North Reference: True Wellbore: 3H-13AL1 Survey Calculation Method: Minimum Curvature Design: 3H-13AL1 Database: EDT 14 Alaska Production Survey MD Inc Azl TVD TVDSS +N! -S +E/ -W Map Map DLS Vertical (ust) (°) (°) (usR) just) (usft) Just) Northing Easting (°1100') Section Survey Tool Name (it) (ft) (ft) 8,510.65 89.75 203.65 5,973.87 5,902.87 2,326.97 -856.28 6,002,802.35 497,799.64 7.87 -2,326.97 MWD (6) 8,541.09 88.80 202.63 5,97425 5,903.25 2,298.98 -868.24 6,002,774.37 497,787.68 4.58 -2,298.98 MWD (6) 8,571.56 89.48 200.82 5,974.71 -5,90371 2,27068 -879.52 6,002,746.07 497,776.40 6.34 -2.270.68 MM (6) 8,600.51 88.86 199.14 5,975.13 5,904.13 2,243.48 -889.41 6,002,718.87 497,766.50 6.19 -2,243.48 MWD (6) 8,630.71 88.40 196.46 5,975.85 -5,904.85 2,214.73 -89864 6,002,690.13 497,757.27 9.00 -2,214.73 MWD (6) 8,661.10 88.16 194.89 5,976.76 5,905.76 2,185.49 -90665 6,002,660.89 497,749.06 5.22 -2,185.49 MWD (6) 8,690.88 89.17 192.04 5,977.46 -5,906.46 2,156.54 -913.78 6,002,631.95 497.742.12 10.15 -2,156.54 MWD (6) 8,725.69 90.21 189.82 5,977.64 -5,906.64 2,122.36 -920.38 6,002,597.78 497,735.52 7.04 -2,122.36 MWD (6) 8,757.63 89.63 187.05 5,977.69 -5,906.69 2,090.77 -925.06 6,002,566.19 497,730.83 8.86 -2,090.77 MWD(6) 8,787.53 90.46 18519 5,977.66 -5,906.66 2,061.04 -928.25 6,002,536.46 497,727.63 6.81 -2,061.04 MWD (6) 8,817.78 92.39 184.38 5,976.91 -5,905.91 2,030.91 -930.77 6,002,506.33 497,725.11 6.92 -2.030.91 MM (6) 8,845.99 93.59 182.46 5,975.44 5,904.44 2,002.79 -932.45 6,002,478.22 497,723.42 8.02 -2,002.79 MWD (6) 8,877.01 93.65 180.51 5,973.48 -5,902.48 1,971.84 -933.26 6,002,447.27 497,722.61 6.28 -1,971,84 MM (6) 8,907.63 92.95 178.05 5,971.72 -5,900.72 1,941.28 -932.87 6,002,416.71 497,722.99 8.34 -1,941.28 MWD(6) 8,937.91 93.01 175.76 5,W0.14 5,899.15 1,911.09 -931.24 6,002,386.52 497,724.62 7.56 -1,911.09 MWD (6) 8,967.63 94.52 175.00 5,968.19 -5,897.19 1,881.53 -928.85 6,002,35697 497,727.00 5.69 -1,881.53 MWD(6) 8,998.84 94.24 172.73 5,965.81 5,894.81 1,850.59 -92552 6,002,326.03 497,730.32 7.31 -1,850.59 MWD (6) 9,028.31 93.42 171,46 5,963.84 -5,892.84 1,821.47 -921.48 6,002,298.91 497,734.36 5.12 -1,821.47 MWD (6) 9,057.83 93.32 17004 5,962.11 5,891.11 1,792.38 -916.74 6,002,267.83 497,739.09 4.81 -1,792.38 MWD (6) 9,088.11 93.28 17039 5,960.36 -5,889.36 1,762.59 -911.61 6,002,238.04 497,744.22 1.16 -1,762.59 MVM (6) 9,117.95 92.21 170.94 5,958.93 5,887.93 1,733.18 -906.77 6,002,20663 497,749.05 4.03 -1,733.18 MWD (6) 9.148.69 89.85 173.44 5,958.38 -5,887.38 1,702.74 -902.60 6,002,178.19 497,753.22 11.18 -1,702.74 MM (6) 9,177.94 89.17 174.11 5,958.63 5,88763 1,673.66 -893.42 6,002,149.11 497,756.39 3.26 -1,673.66 MWD (6) 9,211.19 88.28 177.04 5,959.37 5,888.37 1,640.52 -896.86 6,002,115.98 497,758.95 9.21 -1,640.52 MWD(6) 9,23770 88.77 178.65 5,96095 5,88905 1,614.04 -89586 6,002,089.50 497,759.94 6.35 -1,61404 MWD(6) 9,267.63 89.69 180.74 5,96046 5,88946 1,584.11 -895.70 6,002,059.58 497,760.09 7.63 -1,584.11 MWD (6) 9,297.96 90.18 183.42 5,96049 5,889.49 1,553.81 -896.80 6,002,029.27 497,758.96 8.98 -1,553.81 MWD (6) 9,328.27 90.95 186.12 5,960.19 5,889.19 1,52361 -899.32 6,001,999.08 497,756.46 9.26 -1,523.61 MWD (6) 9,35749 90.64 186.57 5,95979 5,888.79 1,494.57 -902.55 6,001,970.04 497,753.23 1.87 -1,494.57 MWD (6) 9,38846 90.95 18984 5,959.36 -5,888.36 1,463.92 -906.97 6,001,939.40 497,748.80 1060 -1463.92 MWD (6) 9418.23 89.94 191.07 5,959.12 -5,888.12 143465 -912.37 6,001,910 13 497,74340 5.35 -1434.65 MWD (6) Annotation 1217/2018 3:44: 27PM Page 4 COMPASS 5000.14 Build 85D 11 ConocoPhillips ConocoPhillips Definitive Survey Report 114 W HES 9 Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 3H-13 Project: Kuparuk River Unit TVD Reference: 3H-13A @ 71.00usft (3H-13A) Site: Kuparuk 3H Pad MD Reference: 3H-13A @ 71.00usft (3H-13A) Well: 3H-13 North Reference: True Wellbore: 3H-13AL7 Survey Calculation Method: Minimum Curvature Design: 3H-13AL1 Database: EDT 14 Alaska Production Survey MD Inc Azi TVD TVOSS +N/ -S .E/ -W Map DLS VerticalS (ustt) (°) (°) (usft) (usfry (usk) (usR) Northing Easgng Section Survey Tool Name Iftl ( (°1100') (11) 9,447.28 88.06 19186 5,95963 -5,888.63 1,406.18 -918.15 6,001,88167 497,7, 737.62 7.02 -1,406.18 MWD (6) 9,477.21 86.44 192.28 5,961.07 5,890.07 1,376.95 -92440 6,001,85244 497,731.36 5.59 -1,376.95 MVJD(6) 9,507.35 85.08 192.87 5,963.30 -5,892.30 1,347.61 -930.94 6,001,823.11 497,724.81 4.92 -1,347.61 MWD (6) 9,537.33 8496 19448 5,965.90 -5,894.90 1,318.60 -938.00 6,001,794.09 497,717.75 5.36 -1,318.60 MWD (6) 9,567.70 84.59 196.24 5,96866 -5,897.66 1,289.43 -946.01 6,001,764.93 497,709.73 5.90 -1,289.43 MWD (6) 9,597.30 84.68 198.23 5,971.43 -5,90043 1,261.29 -954.74 6,001,736.79 497,701.00 6.70 -1,261.29 MAID (6) 9,627.17 87.08 198.56 5,973.58 -5,902.58 1,233.02 -964.15 6,001,70853 497,691.59 8.11 -1,233.02 MWD (6) 9,657.57 6969 198.52 5,974.44 5,903.44 1,204.21 -973.81 6,001,67973 497,681.93 8.59 -1,204.21 MWD (6) 9,687.79 91.08 200.32 5,974.23 -5,903.23 1,175.71 -983.85 6,001,651.23 497,671.88 7.53 -1,175.71 MWD (6) 9,717.29 91.44 201.97 5,973.68 -5,902.58 1,148.21 -994.49 6,001,623.73 497,661,23 5.72 -1,148.21 MWD(6) 9,747.26 91.66 203.80 5,972.77 -5,901,77 1,12061 -1,006.14 6,001,596.14 497,649.58 6.15 -1,120.61 MM (6) 9,776.86 90.40 204.46 5,972.24 5,901.24 1,093.60 -1,018.24 6,001,569.13 497,637.48 4.81 -1,09360 MWD (6) 9,807.24 87.94 205.11 5,972.68 5,901.68 1,06502 -1,03097 6,001,54156 497,624.74 8.38 -1,066.02 MM (6) 9,836.70 88.07 202.36 5,973.71 -5,902.71 1,039.07 -1,042.82 6,001,514.62 497,612.89 9.34 -1,039.07 MWD(6) 9,861,65 89.51 20065 5,974.23 -5,903.23 1,015.87 -1,051.97 6,001,491.41 497,603.74 8.96 -1,015.87 MWO(6) 9,892,46 89.20 198.49 5,974.58 5,903.58 986.84 -1,062.29 6,001,462.39 497,593.42 7.08 -986.84 MWD (6) 9,921.81 88.99 195.97 5,975.04 5,904.04 958.81 -1,070.98 6,001,434.37 497,584.72 8.61 -958.81 MWD (6) 9,951.95 89.02 193.97 5,975.57 -5,904.57 929.70 -1,078.76 6,001,40526 497,576.93 664 -929.70 MWD (6) 9,982.19 88.19 192.16 5,976.30 -5,905.30 900.25 -1,085.60 6,001,375.82 497570.09 6.58 -900.25 MWD (6) 10,012.49 88.13 18965 5,977.28 -5,906.28 870.52 -1,091.32 6,001,346.09 497,564.36 8.28 -870.52 MWO(6) 10,042.26 87.88 188.23 5,978.31 -5,907.31 841.13 -1,095.95 6,001,316.70 497,559.73 4.84 -841.13 MWD (6) 10,06597 87.91 185.83 5,979.18 -5,908.18 81762 -1,098.85 6.01,293.19 497,556.83 10.12 -817.62 MWD (6) 10,100.00 87.91 18583 5,980.42 -5.909.43 783.78 -1,102.30 6,001,259.36 497,553.37 0.0 -783.78 PROJECTED to TD Annotation 1277/2018 3.44: 27PM Page 5 COMPASS 5000.14 Build 35D BA ER F UGHES a GE company Date: December 7, 2018 Abby Bell AOGCC 333 West 71h Ave, Suite 100 Anchorage, Alaska 99501 218135 30085 Letter of Transmittal Michael Soper Baker Hughes, a GE Company 795 East 941h Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 3H-13AL1PB1 3H-13AL1PB2 3H-13AL1-01PB1 3H-13AL1PB3 3H-13AL1 3H-13AL1-02 3H-13AL1-03 (7) Total prints RECEIVED DEC 10 2018 AOGCC 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 BakerHuahes.com 210135 30085 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-13AL1PB1 50-103-20089-70 Baker Hughes INTEQ Bd(ERES UGH a GE company Definitive Survey Report 07 December, 2018 e 9 � $� @ }\ \� )j ( 0 2\ G 0k | E< .k k /\\!)( E $� @ \� ( 0 G 0k | \ .k k $� @ E | E kE E / r.)\\k\ k\§)\ \} E I � \\ $ �=k :N 0°i (a«:: {j\\ - -._ \;\�))z}\ - .T ! - ! ! $] � § \{§t}!@; _- §- } } $� @ ( | kE E / r.)\\k\ k\§)\ ( | E / r.)\\k\ \} E � \\ (a«:: {j\\ ! - ! ! $] � § \{§t}!@; ( ConocoPhillips SA ER ConocoPhillips Definitive Survey Report UGt ES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 31-1-13 Wellbore: 3H-13AL1 PB1 Design: 3H-13AL1PB1 Survey Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3H-13 3H -13A@ 71.00usft (3H -13A) 3H -13A@ 71,00usft (3H -13A) True Minimum Curvature EDT 14 Alaska Production Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth 1217/2018 3:39:40PM Page 3 COMPASS 5000.14 Build 850 Map Map VerticalDSS MD Inc An ND N +N/ -S +E/ -W DLS (usft) (°) (1) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name (ft) (ft) (ft) 7,260.49 57.88 31.70 5,944.06 -5,873.06 2,976.09 -836.14 6,00345140 497,819.90 0.40 -2,976.09 MWD -INC _ONLY (3) 7,34000 58.38 31.87 5,966.04 5,815.04 3,033.48 -800.57 6,003,50878 497,855.47 0.65 -3,033.48 MWD -INC _ONLY (3) 7,352.17 61.94 34.20 5,99107 5,926.07 3,04960 -790.09 6,003,52489 497,865.96 18.46 -3,049.60 MWD-INC_ONLY (3) 7,390.33 73.73 41.00 6,007.69 -5,936.69 3,070.17 -774.16 6,003,54546 497,881.89 47.44 -3070.17 MWD-INC_ONLY (3) 7,427.83 90.03 46.58 6,012.97 -5,941.97 3,096.84 -748.54 6,003,572.13 497,907.51 45.88 -3,096.84 MWD (4) 7,46038 91.44 61.07 6,012.55 5,941.55 3,115.99 -722.36 6,003,591.27 497,933.70 44.75 -3,115.99 MWD (4) 7,49026 90.34 76.04 6,012.08 -5,941.08 3,126.89 -69461 6,003,602.16 497,961.44 50.20 -3,126.89 MWD (4) 7,520.15 9046 89.76 6,011.88 -5,940.88 3,130.57 -65.02 6,003,605.84 497,991.03 45.90 -3,130.57 MWD (4) 7,555.07 91.84 108.09 6,011.17 -5,940.17 3,125.18 -63068 6,003,60044 498,025.37 52.63 -3,125.18 MWD (4) 7,585.07 91.54 121.80 6,010.28 -5,939.28 3,112.56 503.55 6,003,587.82 498,052.49 45.69 -3112.56 MWD (4) 7,615.19 93.32 136.98 6,008.99 -5,937.99 3,093.53 580.36 6,003,568.78 498,075.67 50.70 -3,093.53 MWD (4) 7,640.23 93.25 148.92 6,007.55 -5,936.55 3,073.61 565.33 6,003,548.86 498,090.70 47.61 -3,073.61 MWD (4) 7,671.16 92.12 16264 6,006.10 -5,935.10 3,045.50 -552.69 6,003,520.76 498,103.34 44.46 -3,045.50 MWD (4) 7,702.02 91.78 165.22 6,005.05 -5,934.05 3,015.81 -544.15 6,003,491.12 498,111.87 8.43 -3,015.87 MM (4) 7,731.25 92.12 16876 6,004.05 -5,933.05 2,987.41 537.57 6,003,462.67 498,118.44 12.16 -2,98741 MWD (4) 7,761.22 91.69 171.07 6,00306 -5,932.06 2,957.92 -532.33 6,003,433.18 498,123.68 7.84 -2,957.92 MWD (4) 7,791.24 92.42 173.33 6,001.98 -5,930.98 2,928.20 -528.26 6,003,403.46 498,127.74 7.91 -2,92820 MWD (4) 7,822.27 92.12 175.61 6,000]5 5,929.75 2,897.34 -525.27 6,003,372.60 498,130.72 7.41 -2,897.34 MWD (4) 7,851.32 91.38 177.55 5,999.86 5,928.86 2,868.36 -523.54 6,003,343.62 498,132.45 7.14 -2,868.36 MWD (4) 7,881.47 90.58 180.11 5,999.35 -5,928.35 2,838.22 -522.92 6,003,313.49 498,133.06 8.89 -2,838.22 MWD (4) 7,911.42 91.69 182.94 5,998.76 -5,927.76 2,808.29 -523.72 6,003,283.56 498,132.26 10.15 -2,80829 MWD (4) 7,941.43 91.38 185.07 5,997.95 -5,926.95 2,778.37 -525.82 6,003,253.64 498,130.16 7.17 -2,77837 MWD(4) 7,971.16 90.55 186.74 5,99745 -5,926.45 2,748.80 -528.87 6,003,224.08 498,1909 6.27 -2,748.80 MM (4) 8,001.33 89.88 189.46 5,997.34 -5,926.34 2,718.93 -533.12 6,003,19422 498,122.84 9.28 -2,718.93 MWD (4) 8,031.54 90.03 191.92 5,997.36 5,926.36 2,68925 -538.73 6,003,164.54 498,117.23 8.16 -2,689.25 MM (4) 8,062.63 90.34 194.06 5,997.26 -5,92626 2,65886 -54572 6,003,13425 498,110.24 6.96 -2,658.96 MM (4) 8,092.63 8979 195.85 5,997.23 5,926.23 2,629.97 55346 6,003,10527 498,10249 6.24 -2,629.97 MWD (4) 8,122.17 8997 198.19 5,997,29 5,926.29 2,601.73 562.10 6,003,07703 498,093.84 7.94 -2,601.73 MWO(4) 8,151.84 89.42 201.04 5,99145 5,926.45 2,573.79 -572.06 6,003,049.09 498,083.88 978 -2,573.79 MWD(4) 8,182.59 8932 198.87 5,99778 -5,926.78 2,544.69 -582.56 6,003,020.20 498073.38 7.06 -2,544.89 MM (4) Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth 1217/2018 3:39:40PM Page 3 COMPASS 5000.14 Build 850 101. ConocoPhillips BAER ConocoPhillipsUGH Definitive Survey Report i -L... Company: Project: Site: Well: Wellbore: Design: Survey ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-13 3H-13AL1PB1 31-1-13AL1 PB1 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3H-13 3H -13A @ 71.00usft (3H -13A) 3H -13A @ 71.00usft (3H -13A) True Minimum Curvature EDT 14 Alaska Production MD Inc AidTVO) TVDSS +N/ -S +E/ -W Map Map OLS Vertical (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting Section Survey Tool Name (it) (ft) (°/1110') (ft) 6212.00 88]] 196.65 5,996.27 5,927.27 2,516.88 -591.52 6,002,992.20 498,064.41 7.78 -2,516.88 MWD (4) 8,241.47 87.79 193.89 5,999.16 -5,928.16 2,488.47 -599.28 6,002,963.79 498,056.65 9.93 -2,488.47 MWO(4) 8,271.41 86.19 190.50 6,000.73 -5,929.73 2,459.25 -605.60 6,002,934.57 498,050.33 12.51 -2,459.25 MWD (4) 8,301.56 86.77 187.80 6,002.58 -5,931.58 2,429.52 -610.38 6,002,904.85 498,045.53 9.14 -2,429.52 VIVID (4) 8,333.09 87.27 183.86 6,004.22 5,93322 2,398.22 -613.58 6,002,873.56 498,042.33 12.59 -2,398.22 MWD (4) 8,361.42 86.86 181.08 600567 5,934.67 2,369.96 -614.80 6,002,845.29 498,041.11 9.91 -2,369.96 MWD (4) 8,391.19 87.54 178.22 6,007.13 5,936.13 2,34023 -614.62 6,002,81557 498,041.28 9.86 -2,340.23 MWD (4) 8,421.13 87.67 175.33 6,008.38 -5,937.38 2,310.37 -612.94 6,002,785.71 498,042.96 9.65 -2,310.37 MWD (4) 8,451.11 88.56 174.56 6,009.37 -5,938.37 2,280.52 -610.29 6,002,755.86 498,045.60 3.92 -2,280.52 MWD (4) 8,480.94 90.58 175.15 6,009.59 -5,938.59 2,250,81 507.62 6,002,726.16 498,048.27 7.05 -2,250.81 MM (4) 8,510.31 92.80 175.53 6,008.72 -5,937.72 2,221.55 .605.24 6,W2,696.90 498,050.65 7.67 -2,221.55 MWD (4) 8,540,65 95.16 176.18 6,005.62 5,935.62 2,191.37 -603.05 6,002,866.72 498,052.83 8.W -2,191.37 MM (4) 8,570.69 96.28 17661 6,003.62 -5,932.62 2,161.51 501.69 6,002,636.86 498,054.18 8.87 -2,161.51 MWO(4) 8,599.65 95.94 180.27 6,000.54 -5,929.54 2,132.71 -601.41 6,002,608.06 498,054.46 5.82 -2,132.71 MWD (4) 8,630.26 96.14 183.30 5,997.32 -5,926.32 2,102.30 -602.35 6,002,577.66 496053.50 9.87 -2,102.30 MWD (4) 8,660.47 95.30 185.90 5,994.31 5,923.31 2,072.34 -604.77 6,002,547.70 498,051.09 9.00 -2,072.34 MWD (4) 8,690.86 96.27 187.37 5,991.24 5,920.25 2,042.31 508.26 8,002,517.67 498,047.59 5.77 -2,042.31 MWD(4) 8,720.50 97.69 188.56 5,987.64 -5,916.64 2,013.17 512.33 6,002,488.54 498,043.51 6.23 -2,013.17 MWD (4) 8,750.85 98.07 192.06 5,983.48 -5,912.98 1,983.60 51271 6,002,458.97 498,038.12 11.49 -1,983.60 MWD (4) 8,775.95 97.69 194.22 5,980.04 -5,909.04 1,959.39 523.37 6,002,434.76 498,032.47 8.66 -1,959.39 MWD (4) 8,805.77 95.91 196.85 5,976.51 -5,905.51 1930.86 -631.30 6,002,406.24 498,024.53 10.63 -1,930.86 MWD (4) 8,835.86 94.15 199.14 5,973.87 5,902.87 1,902.36 540.56 6,002,377.75 498,015.27 9.55 -1,902.36 MWD (4) 8,861.28 93.19 199.20 5572.24 -5,901.24 1,878.40 548.89 6,002,353.79 498,006.93 3.78 -1,878.40 MWD (4) 8,892.54 95.44 201.23 5,969.89 -5,898.89 1,899.15 -659.66 6,002,324.59 497,996.16 968 -1,849,15 MWD (4) 8,916.33 94.91 203.80 5,967.74 -5,896.74 1,827.27 -668.73 6,002,302.66 497,987.08 10.99 -1,827.27 MWD (4) 8,946.27 93.13 20570 5,96565 -5,89465 1,800.15 -681.24 6,002,275.55 497,974.58 8.68 -1,800.15 MWD(4) 8,975.31 93.87 208.54 5,963.87 -5,892.87 1,774.35 -694.45 6,002,249.76 497,961.36 10.09 -1,774.35 MWD (4) 9,00563 94.21 206.76 5,961.74 5,890.74 1,747.56 -706.48 6,002,222.97 497,947.32 5.96 -1,747.56 MWD (4) 9,036.07 9362 202.95 5,959.66 5,888.66 1,720.01 -721.24 8,002,19543 497,934.56 12.64 -1,720.01 MWD (4) 9,08500 93.62 202.95 5,956.57 -5,885.57 1,675.04 -74029 6,002,15047 497,915.51 0.00 -1,675.04 PROJECTED bTD 1217/2018 3: 39: 40PM Page 4 Annotation COMPASS 5000.14 Build 85D BAFER �IGHES a GE company ro 218135 30 08 6 Letter of Transmittal Date: ----- -- - December 7, 2018 Abby Bell AOGCC 333 West 7' Ave, Suite 100 Anchorage, Alaska 99501 Michael Soper Baker Hughes, a GE Company 795 East 94" Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 3H-13AL1PB1 3H-13AL1PB2 3H-13AL1-01PB1 3H-13AL1PB3 3H-13AL1 3 H -13A L1-02 3H-13AL1-03 (7) Total prints RECEIVED DEC 10 2018 AOGCC 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.SooerCDBakerHughes.com ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-13AL1PB2 50-103-20089-71 Baker Hughes INTEQ Definitive Survey Report 07 December, 2018 BA, ICER UGHES a GE company 218135 30086 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc.-Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 3H Pad MD Reference: Well: 3H-13 North Reference: Wellbore: 3H-13AL1 PB2 Survey Calculation Method: Design: 3H-13AL1PS2 Database: Project Kuparuk River Unit, North Slope Alaska, United States Longitude: 150° 0'39,419 W Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) (nT) Map Zone: Alaska Zone 04 Well 3H-13 Well Position +N/ -S 0.00 usft Northing: -1 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 31-1-13AL1 PB2 Magnetics Model Name Sample Date BGGM2018 11/1/2018 Design 3H-13AL1 PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 71.00 Well 3H-13 3H -13A @ 71.00usft (3H -13A) 3H -13A @ 71.00usft (31-1-13A) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 6,000,475.46 usft 498,655.42usR usft Declination (1) 16 83 Tie On Depth: 7,731.25 +N/ -S (usft) 0.00 BA (ER UGHES 11 .11,_ .- Latitude: 1 70'24'45.119 N Longitude: 150° 0'39,419 W Ground Level: 0.00 usft Dip Angle Field Strength (nT) 80.91 57,435 Direction (`) 180.00 12/7/2018 3,41.'38PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BA ER ConocoPhillips Definitive Suvey Report UGH ES Company: ConocoPhillips (Alaska) Inc. -Kup2 _w Local Co-ordinate Reference: Well 3H-13 Project: Kupamk River Unit TVD Reference: 3H -13A @ 71.00usft (3H -13A) Site: Kuparuk 3H Pad MD Reference: 3H -13A @ 71.00usft (31-1-13A) Map Map Well: 311-13 North Reference: True Azi TVD NDSS Wellbore: 3H-13AL1PB2 Northing Northing Survey Calculation Method: Minimum Curvature Section { Design: 3H-13AL1PB2 (°) Database: EDT 14 Alaska Production (usft) usft) Survey Program v Date 4 Survey Tool Name y Annotation From To Survey Survey (ft) (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 2,987.41 95.00 5,900.00 311-13 (31-4-13) GCT -MS Schlumberger GCT multishot 1/12/2001 TIP 7.74500 6,113.56 7,260.49 3H-13AATDB(311-13A) MWD MWD - Standard 9/18/2001 6,003,449.16 498,120.99 7,340.00 7,390.33 3H-13AL1 PBI MWD -INC (3H-13AL7 PBI MWD -INC -ONLY MWD -INC -ONLY -FILLER 10/24/2018 10/24/2018 6,002.38 7,427.83 7,731.25 3H-13AL1P81 MWD(3H-13ALIPB7) MWD MWD -Standard 10/24/2018 10/27/2018 MWD -INC -ONLY (5) 7,745.00 7,778.89 311-13AL1 PB2 MWD -INC (3H-13AL1 PB2 MWD -INC -ONLY MWD -INC -ONLY -FILLER 10/28/2018 10/28/2018 523.83 7,810.00 10,500.39 311-13AL1 PB2 MWD (3H-13ALI PB2) MWD MWD -Standard 10/28/2018 10/31/2018 96.15 Survey Map Map Vertical MD Inc Azi TVD NDSS *N/ -S -E/-W Northing Northing Easting DLS Section usft)(°) (°) (usft) (usft) (usft) usft) (°M00') Survey Tool Name y Annotation (ft) (ft) 7.73125 92.12 16876 6,004,05 5,933,05 2,987.41 -53757 6.003 462.67 498,118.44 12.16 -2,997.41 MWD(4) TIP 7.74500 91.92 169.82 6,003,57 -5,932.57 2,973.91 -535.02 6,003,449.16 498,120.99 7.84 -2,973,91 MWD -INC -ONLY (5) KOP 7,778.89 92.09 170.08 6,002.38 -5,931.38 2,940.56 -529.11 6,003,415.82 498,126.89 0.92 -2,94056 MWD -INC -ONLY (5) Interpolated Azimuth 7,810.00 95.44 170.31 6,000,34 -5,929,34 2,909.97 523.83 6,003,385,23 498,132.17 10.79 -2,909,97 MWD (6) "`- 7,839,00 96.15 172,15 5,997.41 -5,926.41 2,881.46 519.43 6,003,356]2 498,136.56 6.77 -2,88146 MWD (6) 7,869.96 97.07 17349 5,993.85 -5,922.85 2,850,95 -515.58 6,003,326.21 498,140.40 5.23 -2,850.95 MWD (6) 7,899,51 96,30 176.78 5,990.41 -5,919.41 2,821.71 -513.09 6,003,296.98 498,142,89 11.36 -2,821.71 MWD(6) 7,93221 96.86 18023 5,986,66 -5,915.66 2,789.24 512.25 6,003,264.51 498,143.73 10,62 -2,789.24 MM (6) 7,959.02 9599 18169 5,983,66 -5,912.66 2,762,60 -512.69 6,003,237.88 498,143,28 6.31 -2,762.60 MWD (6) 7,990]1 94.12 184.45 5,980,87 -5,909.87 2,731.09 514.38 6,003,205.36 498,14158 1049 -2,731.09 MWD (6) 8,019.48 92.46 186.68 5,979.22 -5,908,22 2,70250 517A7 6,003,177.78 498,138.79 9.65 -2,702.50 MWD(6) 8,04999 9350 188.89 5,977,63 -5,905.63 2,672.32 -521.30 6,00,147.60 498,13466 8.00 -2,672.32 MWD(6) 8,079,97 91.87 190,14 5,976,22 -5,905.22 2,64278 526.25 6,03,118.07 498,129]0 685 -2,642.78 MWD (6) 8,109.17 91.60 192.15 5,975.34 -5,904.34 2,614,15 -531.89 6,00,08944 498,124.06 6.94 -2,614.15 MAD (6) 8,139.23 91.41 194.47 5,974.55 5,903.55 2,584,91 538.81 6,003,060.21 498,117.13 7.74 -2,584.91 MM (6) 8,16919 90.52 19654 5,974.05 -5,903.05 2,556.04 -546.81 6,003,031.35 498,10.12 7.52 -2,556,04 MWD (6) 8,19931 90.0 19948 5,973,90 -5,902.90 2,527.40 -556.12 6,03,00271 498,099.81 9.90 -2,52740 MWD (6) 8,22927 8960 20167 5.974.00 -5,903.00 2,49936 -566.65 6,002,97467 498,08927 7.45 -2499.36 MWD (6) 1217/2018 3A1:38PM Page 3 COMPASS 5000.14 Build 85D 10101. p, ConocoPhillips DA <ER ITf CDnoFri l lull t�UGHES Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 3H-13 Wellbore: 3H-13AL1 PB2 Design: 3H-13AL1PB2 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3H-13 3H -13A @ 71.00usft (3H -13A) 3H -13A @ 71.00usft (3H -13A) True Minimum Curvature EDT 14 Alaska Production Annotation 12172018 3:41:38PM Page 4 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +NAS +FJ -W DLS Northing Easting Section Survey Tool Name (usft) (') (1) (usft) (usft) (usft) (usft) P/100 8,259.34 8840 203.84 5,974.52 5,903.52 2,47163 -57828 6,002,946.95 49807764 8.25 -2,47163 MWD (6) 8,289.34 87.05 205.57 5,975.71 -5,909.71 2,444.40 590.81 6,002,91972 498,065.11 7.31 -2,444.40 MWD (6) 8,319.36 87.45 20321 5,977.15 5,906.15 2,417.09 -603.19 6,002,89242 498,052.73 7.96 -2,417.09 MIND (6) 8,350.52 88.19 200.40 5,978.34 5,907.34 2,388.19 51415 6,002,863.52 498,041.16 9.32 -2,388.19 MIND (6) 8,384.94 88.59 196.67 5,979.31 -5,908.31 2,355.57 525.69 6,002,830.91 498,030.22 10.89 2,355.57 MWD (6) 8,410.70 88.59 194.01 5,979.94 5,908.94 2,330.74 -632.50 6,02,82.08 498,023.40 10.32 -2,330.74 MWD(6) 8,441.47 9443 191.75 5,979.13 -5,908.13 2,300.77 539.36 6,002,776.11 498,016.54 20.35 -2,300.77 MWD (6) 8,470.13 93.81 188.69 5,977.07 5,906.07 2,272.64 -644.43 6,002,747.99 498,011.47 10.87 -2,27264 MWD (6) 8,501.42 90.18 184.69 5,975.98 -5,904.98 2,241.59 548.07 6,002,716.95 498,007.82 17.26 -2,241.59 MWD (6) 8,535.13 91.29 180.31 5,975.55 -5,904.55 2,207.93 549.54 6,002,683.28 498,006.35 13.40 -2,207.93 MWD (6) 8,559.00 93.07 179.16 5,974.64 -5,90364 2,184.08 549.43 6,002,659.43 498,006.45 8.88 -2,184.08 MWD (6) 8,589.33 94.80 176.85 5,972.56 5,901.56 2,153.84 -648.38 6,02,629.20 498,007.50 9.47 -2,153.84 MM (6) 8,619.68 94.65 173.40 5,970.2 -5,899.06 2,123.71 645.81 6,02,599.07 498,010.06 11.37 -2,123.71 MWD (6) 8,649.31 94.15 172.93 5,967,79 -5,896.79 2,094.37 542.29 6,002,569.74 498,013.57 2.31 4,094.37 MWD (6) 8,678.39 92.89 171.81 5,966.00 -5,895.00 2,065.61 638.44 6,002,540.97 498,017.42 5.79 -2,06561 MWD (6) 8,708.33 0.80 169.73 5,965.04 -5,894.04 2,036.07 633.64 6,002,511.44 498,022.21 9.85 -2,036.07 MM (6) 8,738.74 88.77 16794 5,965.15 -5,894.15 2,006.24 527.75 6,02,481.61 498,028.09 8.90 -2,06.24 MIND (6) 8,769.47 88.0 16898 5,966.0 -5,895.0 1,976.14 521.61 6,002,451.52 498,034.23 4.10 -1,976.14 MWD(6) 8,70.12 88.37 17167 5,966.92 -5,895.92 1,946.93 -616.63 6,02,422.31 498,039.21 9.13 -1,996.93 MWD (6) 8,829.53 87.69 174.73 5,967.97 -5,896.97 1,916.76 513.03 6,002,392.14 498,042.80 10.30 -1,916.76 MWD (6) 8,864.11 88.28 177.31 5,969.19 -5,898.19 1,882.29 510.63 6,002,357.67 498,045.19 7.65 -1,882.29 MWD (6) 8,897.88 88.95 179.74 5,970.0 -5,899.0 1,848.54 50.76 6,002,323.92 498,046.05 7.46 -1,898.54 MWD (6) 8,920.06 89.20 181.52 5,970.36 -5,899.36 1,826.36 510.01 6,002,301.75 498,045.80 8.10 -1,826.36 MM (6) 8,949.33 88.56 18344 5,970.93 -5,899.93 1,797.13 511.27 6,002,272.52 498,044.53 6.91 -1,797.13 MWD (6) 8,974.75 87.85 185.82 5,971.73 -5,90.73 1771.81 -613.32 6,002,247.20 498042.48 9.77 -1,771.81 MIND (6) 9,015.37 8542 189.03 5,974.11 5,03.11 1,731.60 -618.56 6,02,2070 498,03723 9.90 -1,731.0 MWD (6) 9,043.33 8566 191.42 5,976.29 5,905.29 1,704.17 523.51 6,002,17958 498,032.28 8.57 -1,704.17 MM (6) 9,076.09 87.91 10.66 5,978.13 -5,907.13 167225 53061 6,002,147.65 498,025.17 9.68 -1,672.25 MWD (6) 9,105.97 88.16 196.58 5,979.15 5,908.15 1,643.42 538.40 6,02,11884 498,017.38 9.80 -1,643.42 MWD (6) 9,146.11 86.99 20133 890.85 -5,90985 1,605.51 651.42 6,002,2092 40,004.35 12.18 -1,05.51 MWD (6) 9,176.07 8926 20375 5,981.83 -5,910.83 1,577.85 562.90 6,002,05328 497,992.87 11.07 -1,57785 MWD (6) Annotation 12172018 3:41:38PM Page 4 COMPASS 5000.14 Build 85D 1217/2018 3:41:38PM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips B ER s Definitive Survey Report ooConocoPhilli Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Cc -ordinate Reference: Well 311-13 Project: Kuparuk River Unit TVD Reference: 311-13A @ 71.00usft (31-1-13A) Site: Kuparuk 3H Pao MD Reference: 3H -13A @ 71.00usft (3H -13A) Well: 3H-13 North Reference: True Wellbore: 3H-13ALiPB2 Survey Calculation Method: Minimum Curvature Design: 3H-13AL1PB2 Database: EDT 14 Alaska Production i Survey -^ , Map Map Vertical MD Inc Azi TVD. TVDSS +N/ -S -E/-W DLS (usft) (1) V) (usft) OEM (usft) (usft) Northing Easting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 9,210.52 87.12 2(Nt 5,982.92 5,911.92 1,546.45 -677.01 6,002,02188 497,978.76 6.73 -1,546.45 MWD (6) i 9,239.81 88.99 205.86 5,983.91 5,912.91 1,519.97 689.49 6,001,99541 497,966.27 7.62 -1,519.97 MVJD(6) 9,264.94 88.77 209.30 5,984.40 -5,913.40 1,497.71 -701.13 6,001,973.14 497,954.63 13.71 -1,497.71 MM (6) I 9,294.13 67.58 21146 5,985.33 5,914.33 1,472.54 -715.88 6,001,94798 497,939.88 8.45 -1,472.54 MWD (6) 9,32443 86.47 212.82 5,986.91 5,915.91 1,446.92 -731.98 6,001,92237 497,92378 5.79 -1,446.92 MVdD(6) 5 9,354.75 86.44 210.71 5,98678 5,917,78 1,421.19 -747.91 6,001,89664 497,907.84 6.95 -1,421.19 MM (6) 9,385.37 87.08 208.43 5.990.51 5,919.51 1,394.60 -762.99 6,001,870.06 497,892.76 7.72 -1,394.60 MWD (6) 9,414.63 87.33 206.03 5,991.94 5,920.94 1,368.62 -776.36 6,001,64408 497,879.38 8.24 -1,368.62 MWD (6) ) 9,445.05 88.28 203.92 5,993.10 -5,922.10 1,341.07 -789.20 6,001,81653 497,866.54 7.60 -1,341.07 MWD (6) 9,480.15 91.48 20260 5,993.18 5,922.18 1,308.82 -503.05 6,001,784.30 497,852.68 9.86 -1,308.82 MWD (6) 1 9,520.25 9369 200.50 5,991.37 5,920.37 1,271.57 617.77 6,001,74705 497,837.96 7.60 -1,271.57 MWD (6) 9,550.35 94,65 197.82 5,989.18 -5,918.18 1243.21 62762 6,001,71670 497,828.11 9.44 -1,243.21 MWD (6) 9,580.36 96.22 196.70 5,986.34 5,915.34 1,21469 636.48 6,001,690.18 497,81924 6.42 -1,214.69 MWD (6) 9,61163 95.29 193.54 5,983.20 -5,912.20 1,184.66 -84460 6,001,660.15 497,811.12 10.49 -1,184.66 MM (6) 9,644.55 95.02 190.93 5,980.24 5,909.24 1,152.62 -851.55 6,001,628.11 497,804.17 7.94 -1,152.62 MWD (6) p 9,675.76 94.39 185.91 5,977.68 -5,906.68 1,121.86 -858.10 6,001,59736 497,799.61 16.16 -1,121.86 MWD (6) 9,700.83 92.98 185,53 5,976.07 -5,905.07 1,096.96 -858.59 6,001,572.47 497,797.11 5.82 -1,096.96 MWD (6) 9,728.69 9366 18267 5,974.46 -5,903.46 1,069.22 660.58 6,001,544.73 49],]95.12 10.53 -1,069.22 MM (6) 9,765.13 94.03 1]9.0] 5,972.01 -5,901.01 1,03288 -861.13 6,001,508.39 497,794.56 9.91 -1,032.88 MM (6) 9,795.47 9255 177.10 5,970.27 -5,899,27 1,002.61 660.12 6,001,478.12 497,795.57 8.11 -1,002.61 MWD(6) s 9,825.13 9240 17441 5,968.99 -5,897.99 973.06 -857.93 6,001,448.57 49],]97.75 9.08 -973.06 MM (6) �t 9,860.35 92.43 17661 5,967.50 -5,896.50 937.98 -855.17 6,001,413.50 497,800.50 624 -937.98 MWD (6) i 9,896.09 91.88 178.86 5,966.16 -5,895.16 902.29 -853.76 6,001,377.82 497,801.91 648 -902.29 MWD (6) 9,931.87 93.01 18242 5,964.63 -5,893.63 86656 -854.16 6,001,34208 497,801.50 10.43 -866.56 MWD (6) 9,965.25 93.47 185.60 5,962.75 -5,891.75 833.32 -856.49 6,001,308.85 497,799.17 9.61 -833.32 MWD (6) 9,996.27 90.83 186.54 5,961.58 -5,890.58 802.49 -859.77 6,001,278.03 497,795.88 9.03 -802.49 MWD (6) L 10,026.05 88.37 186.74 5,961.79 -5,890.79 772.92 -863.21 6,001,248.45 497,792.44 8.29 -77292 MWD (6) 10,056.35 85.61 187.11 5,963.38 -5,892.38 742.88 -866.86 6,001,218.42 497,788.78 9.19 -742.88 MWD (6) i{$ 10MS4 84.16 188.92 5,966.53 -5,895.53 708.08 6]1.76 6,001,183.62 49],]83.88 6.56 -708.08 MM (6) 10,115.87 8465 191.71 5,968.89 -5,897.89 684.36 -876.08 6,001,15991 497,779.56 11.64 -684.36 MWD (6) 10,147.25 84.% 194.56 5,97184 -590084 653.94 -883.17 6,001,129.49 497,77245 9.05 -653.94 MWD (6) ' 1217/2018 3:41:38PM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 31-1-13 Wellbore: 31-1-13AL1 PB2 Design: 3H-13AL1PB2 Survey ConocoPhillips Definitive Survey Report Local Go -ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3H-13 3H -13A @ 71.00usft (3H -13A) 3H -13A @ 71.00usft (3H -13A) True Minimum Curvature EDT 14 Alaska Production MD Inc An ND N +N/ -S -E/-W Map Map - OLS VerticalDSS (usft) (usft) (usft) (usft) (usft) Northing Easting ("7100-) Section Survey Tool Name (ft) (ft) (ft) 10.17591 84 8443 19 19683 5,974.59 -5,903.59 62647 -89089 6,001,102.03 497,764 73 7.90 -62647 MWD (6) 10,207.65 85.09 19966 5,977.49 -5,90649 596.46 -900.79 6,001,072.02 497,754.83 9.12 -59646 MWD (6) 10,235.93 83.66 202.89 5,980.26 -5,909.26 570.24 -910.99 6,001,045.80 497,744.62 12.44 -57024 MWD (6) 10,267.62 83.15 207.14 5,983.90 -5,912.90 54172 -924.30 6,001,01729 497,731.31 13.42 -591.72 MWD (6) 10,295.58 83.21 210.92 5,987.23 5,916.23 517.45 -937.77 6,000,993.02 497,717.83 13.43 51745 MWD (6) 10,325.80 83.14 210.81 5,990.82 -5,919.82 49169 -953.17 6,000,96727 497,702.44 0.43 491.69 MM (6) 10,355.52 83.45 212.54 5,999.29 5,923.29 466.57 -968.66 6,000,942.16 497,686.94 5.87 466.57 MWD (6) 10,385.57 83.51 215.45 5,997.70 -5,92670 441.82 -985.36 6,000,91741 497,67024 9.62 441.82 MWD(6) 10,415.70 82.86 216.93 6,001.28 -5,930.28 417.68 -1,003.02 6,000,893.27 497,652.58 5.33 417.68 MWO(6) 10,440.85 8023 21665 6,004.97 -5,933.97 397.76 -1,017.92 6,000,873.36 497,637.68 10.52 -397.76 MM (6) 10,470.49 77.03 217.00 6,010.82 -5,939.82 374.50 -1,035.33 6,000,850.11 497,620.26 10.86 -374.50 MWD (6) 10,500.39 73.69 216.68 6,018.37 -5,947.37 351.35 -1,052.67 6,000,82696 497,602.91 11.22 351.35 MWD(6) 10,535.00 73.69 216.68 6,028.09 -5,957179 324.71 -1,072.52 6,000,800.33 497,583.07 0.00 -324.71 PROJECTED to TO Annotation RA UER S 12172018 3:41:38PM Page 6 COMPASS 5000.14 Build 850 BA ER BAT a GEcompany DIF) 218135 30087 Letter of Transmittal Date: ---- — ---- December 7, 2018 Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Michael Soper Baker Hughes, a GE Company 795 East 941h Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 3H-13AL1PB1 3H-13AL1PB2 3H-13AL1-01PB1 3H-13AL1PB3 3H-13AL1 3 H -13A L1-02 3H-13AL1-03 (7) Total prints RECEIVED ED DEC 10 2018 AOGCC 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@BakerHughes.com ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-13AL1PB3 50-103-20089-73 Baker Hughes INTEQ Definitive Survey Report 07 December, 2018 BAT(ER UGHES a GE company 2 18 135 30087 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kupamk River Unit TVD Reference: Site: Kuparuk 3H Pad MD Reference: Well: 311-13 North Reference: Wellbore: 3H-13AL1 PB3 Survey Calculation Method: Design: 3H-13AL1PB3 Database: Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Emot solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Survey Well 3H-13 Tool Name Well Position +N/ -S 0.00 usft Northing: 5,900.00 +EI -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore Magnetics Design Audit Notes: Version: Vertical Section: Survey Program From (usft) 9500 6,113.56 7,315.00 7,426.34 3H-13ALiPB3 Model Name BGGM2018 3H-13AL1PB3 1.0 Phase: ACTUAL Depth From (TVD) (usft) 71 00 Sample Data 11/1/2018 Well 3H-13 3H -13A@ 71.00usft (311-13A) 3H -13A@ 71.00usft (311-13A) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 6,000,475.46usft 498,655.42usft usft Declination (°) 16.83 Tie On Depth: 7,260.49 +N/ -S (usft) 0.09 BA ER F�UGHES i Latitude: 70° 24'45. 119 N Longitude: 150° 0'39.419 W Ground Level: 0.00 usft Dip Angle Field Strength l°I (nT) 80.91 57,435 i +E/ -W Direction (usft) (I 0.00 180.00 12!72018 3:43:52PM Page 2 COMPASS 5000.14 Build 85D Date TO Survey Survey (usft) Survey (Wellbore) Tool Name Description Start Date End Date 5,900.00 3H-13 (31-1-13) GCT -MS Schlumberger GCT multishot 1/12/2001 7,260.49 3H-13AATDB(3H-13A) MWD MWD -Standard 9/18/2001 7,396.26 311-13AL1 P133 MWD -INC (3H-13AL1 PB3 MWD-INC_ONLY MWD -INC ONLY_FILLER 11/11/2018 11/11/2018 8,766.05 311-13AL1 P133 MWD (3H-13ALl PB3) MWD MWD- Standard 11/11/2018 11/13/2018 12!72018 3:43:52PM Page 2 COMPASS 5000.14 Build 85D 12/7/2018 3: 43:52PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BA(ER Definitive Survey Report UGESConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 3H-13 Project: Kuparuk River Unit TVD Reference: 3H -13A @ 71.00usft (3H -13A) Site: Kuparuk 3H Pad MD Reference: 3H -13A @ 71.00usft (3H -13A) Well: 31-1-13 North Reference: True Wellbore: 3H-13AL1PB3 Survey Calculation Method: Minimum Curvature Design: 3H-13AL7 PB3 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc AN TVD TVDSS +N1 -S +E/ -W Northing Easting OLS Section (usft) r) (1) (usft) (usft) (waft) (usft) (°1100') Survey Tool Name Annotation (ft) (ft) (ft) 7,260.49 57.88 31.70 5,944.06 5,873.06 2,976.09 -836.14 6,003,451.40 497,819.90 0.40 -2,976.09 MV1D-iNC_ONLY (3) TIP 7,315.00 58.22 31.81 5,972.91 -5,901.91 3,01542 -811.80 6,003,490.72 497,844.25 0.65 -3,015.42 MWD-INC_ONLY (3) KOP 7,336.93 61.54 31.81 5,983.91 -5,912.91 3,031.53 -801.60 6,003,506.83 497,854.24 15.14 -3,031.53 MWD -INC ONLY(3) Interpolated Azimuth 7,366.82 74.84 31.81 5,994.99 -5,923.99 3,055.06 487.21 6,003,530.36 497,868.84 44.50 3,055.06 MM -INC _ONLY (3) Interpolated Azimuth 7,396.26 88.40 31.81 5,999.27 -5,928.27 3,079.76 -771.69 6,003,555.05 497,884.16 46.06 3,079.76 MM -INC ONLY (3) Interpolated Azimuth 7426.34 99.27 3167 5,997.26 -5,926.26 3,105.24 -756.13 6,003,580.53 497,899.93 36.14 3,105.24 MWD (4) 7,456.57 97.82 46.59 5,992.74 -5,921.74 3,128.36 -737.31 6,003,603.64 497,918.75 49.04 -3,128.36 MWD (4) 7,486.47 95.04 60.96 5,989.38 -5,918.38 3,145.86 -713.40 6,003,621.13 497,942.66 48.65 -3,145.86 MWD(4) 7,516.26 9375 76.30 5,987.08 -5,916.08 3,156.65 £85.82 6,003,631.91 497,970.23 51.52 -3,156.65 MWD (4) 7,546.81 93.10 92.51 5,985.25 -5,914.25 3,159.61 -655.58 6,003,634.87 498,000.48 53.01 -3,159.61 MWD(4) 7,576.27 91.20 106.57 5,984.13 -5,913.13 3,154.74 526.62 6,003,630.00 498,029.43 48.12 -3,154.74 MWD(4) 7,608.76 WAS 122.75 5,983.74 -5,912.74 3,141.23 597.19 6,003,616.48 498,058.85 49.89 -3,141.23 MIND (4) 7,640.06 90.00 138.37 5,983.69 -5,912.69 3,120.94 -573.49 6,003,596.19 498,082.55 49.91 -3,120.94 MWD (4) 7,670.87 9101 153.51 5,983.42 -5,912.42 3,095.49 -55628 6,003.570.74 498,099.75 49.25 -3,095.49 MWD (4) 7,700.85 90.06 168.30 5,983.14 -5,912.14 3,037.24 -546.50 6,003,54249 498,109.52 49.43 -3,067.24 MWD (4) 7,73166 89.94 183.97 5,983.14 -5,912.14 3,036.60 544.43 6,003,511.65 498,111.59 50.85 -3,036.60 MWD (4) 7,763.03 8919 196.41 5,983.21 5,912.21 3,005.78 -549.97 6,003,481.04 498,106.04 3965 -3,005.78 MWD(4) 7,79321 89.26 198.86 5,983.46 -5,912.46 2,97702 -559.11 6,003,45229 498,096.90 8.31 -2,977.02 MIND (4) 7,822.54 88.93 198.57 5,98392 -5,912.92 2,94925 -568.52 6,003,424.51 498,08]48 1.50 -2,949.25 MWD (4) 7,854.65 89.91 200.73 5,984.25 5,913.25 2,919.01 -579.32 6,003,39428 498,076.68 7.39 -2,919.01 MWD(4) 7,882.68 89.51 202.42 5,984.39 5,913.39 2,892.95 -589.63 6,003,368.22 498,066.37 6.20 -2,892.95 MIND (4) 7,915.07 89.94 202.84 5,984.55 5,913.55 2,863.05 502.09 6,003,338.33 498,053.91 1.86 -2,863.05 MIND (4) 7,943.18 89.88 200.64 5,994.59 5,913.59 2,836.94 512.50 6,003,312.23 498,043.49 7.83 -2,836.94 MWD (4) 7,973.65 91.90 200.83 5,984.12 5,913A2 2,80845 523.29 6,003,283.74 498,03270 6.66 -2,808.45 MWD (4) 8,006.15 92.58 199.39 5,982.85 -5,911.85 2,777.95 -634.44 6,003,253.25 498,021.55 5.04 -2,777.95 MIND (4) 8,033.20 92.27 19671 5,98170 5,91070 2,752.25 542.80 6,003,227.55 498,013.18 9.78 -2,752.25 MWD (4) 8,063.60 92.91 19418 5,980.33 5,909.33 2,722.98 550.89 6,003,19829 498,005.09 8.58 -2,722.98 MM (4) ',. 8,092.57 93.99 196.59 5,978.59 -5,907.59 2,695.10 558.55 6,003,170.41 497,997.41 9.10 -2,695.10 MWD (4) 8,121.33 94.48 19751 5,976.46 5,905.46 2,667,68 -666.97 6,003,143.00 497,989.00 3.62 -2,66]68 MWD (4) 8,153.03 93.59 198.71 5,974.23 5,903.23 2,637.60 -676.81 6,003,112.92 497,979.16 4.70 -2,63760 MWD (4) 12/7/2018 3: 43:52PM Page 3 COMPASS 5000.14 Build 85D ✓ ConocoPhillipsER uE�s ConocoPhillips Definitive Survey Report +N/ -S Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 3H-13 Project: Kuparuk River Unit TVD Reference: 3H -13A @ 71.O0usft (3H -13A) Site: Kuparuk 3H Pad MD Reference: 3H -13A @ 71.00usft (3H -13A) Well: 3H-13 North Reference: True Wellbore: 3H-13AL1PB3 Survey Calculation Method: Minimum Curvature Design: 3H-13AL1PB3 Database: EDT 14 Alaska Production Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map S Vertical (usft) (') V) (usft) (usft) (usft) (usft) Northing Easting (oD 1 Section Survey Tool Name Annotation (ft) (ft) IN 8,182.15 92.82 200.43 5,972.60 -5,90160 2,61024 -686.53 6,003,085% 497,969.42 6.47 -2,610.24 MWD (4) 8,212.92 92.15 201.87 5,971.27 -5,900.27 2,581.57 897.63 6,003,056.89 497,958.33 5.16 -2,581.57 MWD (4) 8,252.57 91.81 205.66 5,969.90 -5,898.90 2,545.31 -71359 6,003,02064 497,942.36 9.59 -2,545.31 MWD (4) 8,272.85 90.95 207.46 5,969.41 5,898.41 2,527.17 -722.66 6,003,002.51 497,933.29 9.83 -2,527.17 MND (4) 8,304.85 89.63 208.56 5,96825 5,89825 2,498.92 -737.68 6,002,97427 497,918.26 5.37 -2,498.92 MWD(4) 8,331.50 88.34 208.93 5,969.72 5,898.72 2,475.56 -750.50 6,002,95091 497,905.44 5.04 -2,475.56 MWD(4) 8,366.21 86.99 207.07 5,971.13 5,900.13 2,444.94 -766.78 6,002,920.30 497,889.16 662 -2,444.94 MWD(4) 8,407.79 87.14 203.44 5,973.26 -5,902.26 2,407.39 -784.49 6,002,882.75 497,871.44 8.73 -2,407.39 MWD (4) 8,438.37 8847 201.61 5,974.43 -5,903.43 2,379.17 -79620 6,002,854.53 497,859.73 7.39 -2,379.17 MWD (4) 8,468.37 88.50 200.79 5,975.23 -5,904.23 2,351.21 -807.04 6,002,826.58 497,848.88 2.73 -2,351.21 MVtD (4) 8,497.67 90.83 197.46 5,975.40 -5,904.40 2,323.53 816.64 6,002,798.91 497,839.28 13.87 -2,323.53 MWD(4) 8,526.13 91.14 195.84 5,974.91 -5,903.91 2,296.27 -824.79 6,002,771.65 497,831.12 5.79 -2,296.27 MWD (4) 8,556.61 88.06 192.96 5,975.12 5,904.12 2,266.75 -832.37 6,002,742.14 497,823.54 13.83 -2,266.75 MVVD (4) 8,587.65 87.39 191.64 5,976.35 5,905.35 2,236.45 838.98 6,002,711 84 497,816.93 4.77 -2,236.45 MWD (4) 8,618.09 87.97 189.23 5,977.59 5,906.59 2,206.54 844.49 6,002,68193 497,811.42 8.14 -2,206.54 MWD (4) 8,648.42 88.00 187.79 5,978.65 -5,907,65 2,176.57 -84897 6,002,651.96 497,806.92 4.75 -2,176.57 MWD (4) 8,676.89 89.09 186.11 5,979.38 -5,908.38 2,148.32 852.42 6,002,623.71 497,803.48 7.03 -2,148.32 MVtD(4) 8,707.49 89.05 18529 5,979.87 -5,908.87 2,117.87 855.45 6,002,593.27 497,800.43 2.68 -2,117.87 MWD(4) 8,735.93 88.96 181.82 5,980.37 -5,909.37 2,089.49 -857.22 6,002,564.90 497,798.66 12.20 -2,089.49 MWD (4) 8,766.05 88.62 180.38 5,98100 -5,910.00 2,059.39 -857.80 6,002,534.80 497,798.08 4.91 -2,059.39 MWD (4) 8,810.00 88.62 18038 5,98206 -5,911.06 2,01545 -858.09 6,002,490.86 497,797.78 0.00 -2,015.45 PROJECTED to TD 12172018 3:43:52PM Page 4 COMPASS 5000.14 Build 850 EZ( 314-13A L 1 P -It Ole 1350 Regg, James B (DOA) From: Regg, James B (DOA) r Sent: Thursday, November 8, 2018 9:26 AM /may > ll(tPJ �� 6 To: Herring, Keith E; Loepp, Victoria T (DOA); Kanady, Randall (/ 11 Cc: Starck, Kai; Ohlinger, James J; Nabors CDR3 Company Man; Schwartz, Guy L (DOA); Cook, Guy D (DOA) Subject: Re: KRU 31-1-13A BOPE Testing Extension 24hr extension is granted as a contingency should the BOPE test not start before midnight tonight. AleAt rs MC3A- , Sent via the Samsung Galaxy S8 Active, an AT&T 4G LTE smartphone -------- Original message -------- From: "Herring, Keith E" <Keith.E.Herring@conocophillips.com> Date: 11/8/18 8:59 AM (GMT -09:00) To: "Loepp, Victoria T (DOA)" <victoria.loepp@alaska.gov>, "Kanady, Randall B" <Randall.B.Kanady@conocophillips.com>, "Regg, James B (DOA)' <jim.regg@alaska.gov> Cc: "Starck, Kai"<Kai.Starck@conocophillips.com>, "Ohlinger, lames J" <James.J.Ohlinger@conocophillips.com>, Nabors CDR3 Company Man <NaborsCDR3CompanyMan@conocophillips.com>, "Schwartz, Guy L (DOA)" <guy.schwartz@alaska.gov>, "Cook, Guy D (DOA)' <guy.cook@alaska.gov> Subject: KRU 31-1-13A BOPE Testing Extension Jim, As per your request in the attached email (Re: KRU 3H -13A BOPE Testing Extension). Early this morning ConocoPhillips was successful in obtaining a cut of the coiled tubing at 7357' ELMD. E -line was rigged down and we are currently rigging down scaffolding that was utilized on the rig floor during coiled tubing recovery operations. The plan forward is to install a spool able coil connector and begin pulling coiled tubing from the well. It appears that ConocoPhillips will be able to begin testing BOPE by 23:59 hours on November 08, 2018 as requested by the attached email for AOGCC test witness notification sent on November 07, 2018. However, ConocoPhillips requests an extension to the BOPE test if an operational issue prevents ConocoPhillips from testing BOPE by 23:59 hours on November 08, 2018. On a side note ConocoPhillips will be submitting a Sundry application to run and set a second whipstock to mill a window and drill the permitted laterals as per plan. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith.EKe E.Herrin(nlconocophillips.comllips.con ConocoPhillips ,ala:; ,a From: Herring, Keith E Sent: Wednesday, November 7, 2018 10:23 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Kanady, Randall B <Randall.B.Kanady@conocophillips.com>; jim.regg@alaska.gov Cc: 'Kai Starck'<Kai.Starck@conocophillips.com>; 'James Oh linger' <James.J.Ohlinger@conocophiIli ps.com>; Nabors CDR3 Company Man <NaborsCDR3CompanyMan@conocophillips.com>; Schwartz, Guy L (DOA) <guy.schwa rtz@alaska.gov>; guy.cook@alaska.gov Subject: KRU 31-1-13A BOPE Testing Extension Jim, ConocoPhillips CTD has drilled and completed the first lateral 3H-13AL1 (PTD #218-135) of 4 planned laterals. However, while conducting a cleanout run on the 31-1-13AL1-01 (PTD #218-136) the bottom hole assembly (BHA) became stuck at 10462' MD. ConocoPhillips has been unsuccessful in getting the BHA free and has moved forward with coiled tubing recovery operations which has included killing the well with 11.8 ppg NaBr. Our next BOP test is due at 23:59 hours on November 08, 2018. ConocoPhillips is requesting an extension to this BOP test in order to remove the stuck coiled tubing. Once we have removed the coiled tubing CDR3 with conduct a BOPE test. If you have questions or concerns please let me know. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith.E.Herring( conocophi I lips.com ConocoPhillips AIBSka From: Herring, Keith E Sent: Wednesday, November 7, 2018 4:23 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov>; Kanady, Randall B <Randall.B.Kanadv@conocophillips.com> Cc: 'Kai Starck'<Kai.Starck@conocophillips.com>; 'James Ohlinger' <James.J.Ohlineer@conocophillips.com>; Nabors CDR3 Company Man <NaborsCDR3CompanyMan@conocophillips.com>; Schwartz, Guy L (DOA) <guy. schwa rtz@a laska.aov> Subject: KRU 31-1-13A BOPE Testing Extension Good evening Victoria, ConocoPhillips CTD has drilled and completed the first lateral 3H-13AL1 (PTD #218-135) of 4 planned laterals. However, while conducting a cleanout run on the 31-1-13AL1-01 (PTD #218-136) the bottom hole assembly (BHA) became stuck at 10462' MD. ConocoPhillips has been unsuccessful in getting the BHA free and has moved forward with coiled tubing recovery operations. Our next BOP test is due at 23:59 hours on November 08, 2018. ConocoPhillips is requesting an extension to this BOP test in order to remove the stuck coiled tubing. Once we have removed the coiled tubing CDR3 with conduct a BOPE test. If you have questions or concerns please let me know. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith.E. HerringPconocophi I lips.com ConocoPhillips From: Herring, Keith E Sent: Tuesday, November 6, 2018 4:45 PM To: 'Loepp, Victoria T (DOA)' <victoria.loepp@alaska.aov_> Cc: 'Kai Starck' <Kai.Starck conocophillips.com>; 'James Oh linger' <James.J.Ohlinger@conocophillips.com> Subject: KRU 3H -13A Good afternoon Victoria, ConocoPhillips CTD has drilled and completed the first lateral 3H-13AL1 (PTD #218-135) of 4 planned laterals. However, while conducting a cleanout run on the 3H-13AL1-01 (PTD #218-136) the bottom hole assembly (BHA) became stuck at 10462' MD. ConocoPhillips has been unsuccessful in getting the BHA free and has moved forward with coiled tubing recovery operations. Our next BOP test is due at 23:59 hours on November 08, 2018. Depending upon our operational success we may need to request a BOP testing extension. Attached is the current CTD schematic of 3H -13A. If you have questions or concerns please let me know. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith.E.Herring@conocoph ill ips.com ConocoPhillips Loepp, Victoria T (DOA) From: Sent: To: Cc: Subject: Attachments: Follow Up Flag: Flag Status: Jim, pro ;415-135- Herring, Keith E <Keith.E.Herring@conocophillips.com> ! 3 Thursday, November 8, 2018 8:59 AM 3-9 Loepp, Victoria T (DOA); Kanady, Randall B; Regg, James B (DOA) Starck, Kai; Ohlinger, James J; Nabors CDR3 Company Man; Schwartz, Guy L (DOA); Cook, Guy D (DOA) KRU 3H -13A BOPE Testing Extension [EXTERNAL]Re: KRU 3H -13A BOPE Testing Extension; FW: [EXTERNAL]Re: AOGCC Test Witness Notification Request: BOPE, Nabors CDR3-AC, 3H -pad, well 13A, Kuparuk River Unit Follow up Flagged As per your request in the attached email (Re: KRU 3H -13A BOPE Testing Extension). Early this morning ConocoPhillips was successful in obtaining a cut of the coiled tubing at 7357' ELMD. E -line was rigged down and we are currently rigging down scaffolding that was utilized on the rig floor during coiled tubing recovery operations. The plan forward is to install a spool able coil connector and begin pulling coiled tubing from the well. It appears that ConocoPhillips will be able to begin testing BOPE by 23:59 hours on November 08, 2018 as requested by the attached email for AOGCC test witness notification sent on November 07, 2018. However, ConocoPhillips requests an extension to the BOPE test if an operational issue prevents ConocoPhillips from testing BOPE by 23:59 hours on November 08, 2018. On a side note ConocoPhillips will be submitting a Sundry application to run and set a second whipstock to mill a window and drill the permitted laterals as per plan. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Kith. F.. 11 coin Gteoi;oo r,hillq�..com ConocoPhillips Alaska From: Herring, Keith E Sent: Wednesday, November 7, 2018 10:23 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Kanady, Randall B <Randall.B.Kanady@conocophillips.com>; jim.regg@alaska.gov Cc:'Kai Starck' <Kai.Starck@conocophillips.com>;'James Ohlinger' <James.J.Ohlinger@conocophillips.com>; Nabors CDR3 Company Man <NaborsCDR3CompanyMan@conocophillips.com>; Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; guy.cook@alaska.gov Subject: KRU 31-1-13A HOPE Testing Extension Jim, ConocoPhillips CTD has drilled and completed the first lateral 3H-13AL1 (PTD #218-135) of 4 planned laterals. However, while conducting a cleanout run on the 3H-13AL1-01(PTD #218-136) the bottom hole assembly (BHA) became stuck at 10462' MD. ConocoPhillips has been unsuccessful in getting the BHA free and has moved forward with coiled tubing recovery operations which has included killing the well with 11.8 ppg Na Br. Our next BOP test is due at 23:59 hours on November 08, 2018. ConocoPhillips is requesting an extension to this BOP test in order to remove the stuck coiled tubing. Once we have removed the coiled tubing CDR3 with conduct a BOPE test. If you have questions or concerns please let me know. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 F cil h.L Heniit :� eonocoph d ip... om ConocoPhillips Alaska From: Herring, Keith E Sent: Wednesday, November 7, 2018 4:23 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov>; Kanady, Randall B <Randall B Kanady@conocophillips.com> Cc: 'Kai Starck' <Kai.StarckCa@conocophillips.com>;'James Ohlinger'<JameslOhlinger conocophillips.com>;Nabors CDR3 Company Man <NaborsCDR3CompanyMan@conocophillips.com>; Schwartz, Guy L (DOA) <guy.schwa rtz@a laska.xov> Subject: KRU 31-1-13A BOPE Testing Extension Good evening Victoria, ConocoPhillips CTD has drilled and completed the first lateral 3H-13AL1 (PTD #218-135) of 4 planned laterals. However, while conducting a cleanout run on the 3H-13AL1-01 (PTD #218-136) the bottom hole assembly (BHA) became stuck at 10462' MD. ConocoPhillips has been unsuccessful in getting the BHA free and has moved forward with coiled tubing recovery operations. Our next BOP test is due at 23:59 hours on November 08, 2018. ConocoPhillips is requesting an extension to this BOP test in order to remove the stuck coiled tubing. Once we have removed the coiled tubing CDR3 with conduct a BOPE test. If you have questions or concerns please let me know. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith.E.Heaing@conocophillips.com ConocoPhillips Alaska From: Herring, Keith E Sent: Tuesday, November 6, 2018 4:45 PM To: Toepp, Victoria T (DOA)' <victoria.loepp@alaska.gov> Cc: 'Kai Starck' <Kai.Starck@conocophillips.com>;'James Oh linger' <James J Ohlineer@conocophillips.com> Subject: KRU 3H -13A Good afternoon Victoria, ConocoPhillips CTD has drilled and completed the first lateral 3H-13AL1 (PTD #218-135) of 4 planned laterals. However, while conducting a cleanout run on the 3H-13AL1-01(PTD #218-136) the bottom hole assembly (BHA) became stuck at 10462' MD. ConocoPhillips has been unsuccessful in getting the BHA free and has moved forward with coiled tubing recovery operations. Our next BOP test is due at 23:59 hours on November 08, 2018. Depending upon our operational success we may need to request a BOP testing extension. Attached is the current CTD schematic of 31-1-13A. If you have questions or concerns please let me know. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith.E.Hem ng@conocophiIIip, coni ConocoPhillips Alaska Loepp, Victoria T (DOA) From: Nabors CDR3 Company Man <NaborsCDR3CompanyMan@conocophillips.com> Sent: Wednesday, November 7, 2018 10:06 PM To: Herring, Keith E Subject: FW: [EXTERNAL]Re: AOGCC Test Witness Notification Request: BOPE, Nabors CDR3-AC, 3H -pad, well 13A, Kuparuk River Unit From: Cook, Guy D (DOA) <guy.cook@alaska.gov> Sent: Wednesday, November 07, 2018 10:05 PM To: Nabors CDR3 Company Man <NaborsCDR3CompanyMan@conocophillips.com> Cc: DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe. bay@alaska.gov> Subject: [EXTERNAL]Re: AOGCC Test Witness Notification Request: BOPE, Nabors CDR3-AC, 3H -pad, well 13A, Kuparuk River Unit Scott, As per our conversation, send Jim Regg an email informing him of your situation and please keep us updated as to your progress and BOP test timing. Thank you, Guy Cook AOGCC Sent from my iPhone On Nov 7, 2018, at 9:53 PM, Scott Kiser <noreply@formresponse.com> wrote: M Question Answer Type of Test Requested: BOPE Requested Time for 11-08-2018 12:00 AM Inspection Location Nabors CDR3-AC, 3H -pad, well 13A, Kuparuk River Unit Name Scott Kiser E-mail ncdr3cm@conocophillips.com Phone Number (907) 670-6050 Company Conocophillips Other Information: Please call rig, Stuck in hole. Loepp, Victoria T (DOA) From: Regg, James B (DOA) <jim.regg@alaska.gov> Sent: Wednesday, November 7, 2018 10:36 PM To: Herring, Keith E; Loepp, Victoria T (DOA); Kanady, Randall B Cc: Starck, Kai; Ohlinger, James J; Nabors CDR3 Company Man; Schwartz, Guy L (DOA); Cook, Guy D (DOA); Loepp, Victoria T (DOA) Subject: [EXTERNAL]Re: KRU 3H -13A BOPE Testing Extension We will address this request in the morning after you give us a progress update around 0900 hrs. Sent via the Samsung Galaxy S8 Active, an AT&T 4G LTE smartphone i THE STATE °fALASKA GOVERNOR BILL WALKER James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 31-1-13AL1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-135 Surface Location: 1182' FNL, 281' FWL, SEC. 12, T12N, R8E, UM Bottomhole Location: 972' FNL, 793' FEL, SEC. 11, TI2N, R8E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 218-135, API No. 50-103-20089- 60-00. 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 DATED this Z}r day of October, 2018. STATE OF ALASKA ALhaKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL - 20 AAC 25.005 1 a. Type of Work: • , 1 b. Proposed Well Class: Exploratory - Gas LJ Service - WAG Service - Disp ❑ 1c. Specify if well is proposed for: Drill ❑ Lateral ❑� Stratigraphic Test ❑ Development - Oil I PI ' Service - Winj ❑ Single Zone ❑' ' Coalbed Gas ❑ Gas Hydrates ❑ Reddll ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 KRU 3H-13AL1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Boz 100360 Anchorage, AK 99510-0360 MD: 10600' TVD: 6011' Kuparuk River Field / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1182' FNL, 281' FWL, Sec 12, T12N, R8E, UM ADL 25531 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 3434' FNL, 520' FEL, Sec 02, T12N, R8E, UM LONS 84-134 & LONS 84-149 10/24/2018 ' Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 972' FNL, 793' FEL, Sec 11, T12N, R8E, UM 2560 4760' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 76' - 15. Distance to Nearest Well Open Surface: x- 498655 ' y- 6000475 • Zone- 4 GL / BF Elevation above MSL (ft): 34' to Same Pool: ' 703', 3H -12A 16. Deviated wells: Kickoff depth: 7338 • feet 17. Maximum Potential Pressures in psig (see 20 AAG 25.035) Maximum Hole Angle: 95 degrees Downhole: 4897 • Surface: 4299 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 2850' 7750' 6008' 10600'. 6011' 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): 7755' 6203' N/A 7653' 6150' N/A Casing Length Size Cementvolume MD TVD Conductor/Structural 74' 16" 245 sx AS 1 110' 110' Surface 3037' 9-5/8" 1300 sx ASIII, 400 sx G, 70 sx ASI 3072' 2929' Production 5937' 7" 300 sx G, 175 sx AS 1 5970' 5173' Liner 1947' 3-1/2" 311 sx G 7755' 6203' Perforation Depth MD (ft): 7229'- 7249', 7258'- 7308' Perforation Depth TVD (ft): 5927'- 5938', 5943'- 5969' 7356' - 7366', 7372' - 7380' 5994'- 6000', 6002'- 6007' Hydraulic Fracture planned? Yes ❑ No ❑i ' 20. Attachments: Property Plat ❑ BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch e Seabed Report a Drilling Fluid Program e 20 AAC 25.050 requirements e 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Keith Herring Authorized Name: James Ohlinger Contact Email: Keith. E. HerrinqCcDcop.com Authorized Title: Staff TD Engineer Contact Phone: 907-263-4321 Authorized Signature: Dale: Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other �t v Number: y. q 3 5 50- 103 .:00 D -O Date: O 2 requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: r BCP ttst 7 4BGc rEr Samples req'd: Yes E]No L� Mud log req'd: Yes [-]No L� —.^nvGar zS—D0/y,Y$rmseza.,sures: Yes L7 No,❑,/ Directional svy req'd: Yes [�]•/No❑ �4 Gam/ v5� J ' + P Spacing exceptierf req'd: Yes ❑ No LAS Inclination -only svy req'd: Yes ❑ No[V]' Post initial injection MIT req'd: Yes ❑ NoE]� APPROVED BY I I Approved by: COMMISSIONER THE COMMISSION Date: 1 Z3 t mL .Z-,3� L /'� ^ 1 ///'''��� 1 A 1 y� Submit Form and IL\y{� Fm091 i Revised 512017 his permit is valid for�2q r�p�tl�s�i��aA Ipt 0 26.006(8) attachments in \O� U'\I 'v„L_; V t�.Z�.� (x3%18 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 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 four laterals out of the KRU 3H -13A (PTD# 196-197) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin on October 24, 2018. The objective will be to drill four laterals KRU 3H- 13AL1, 3H-13AL1-01, 3H-13AL1-02 and 3H-31AL1-03 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 3H-13AL1, 3H-13AL1-01, 3H-13AL1-02, & 3H-13AL1-03 — Detailed Summary of Operations — Directional Plans for 3H-13AL1, 3H-13AL1-01, 3H-13AL1-02, & 3H-13AL1-03 — 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 0 3H-13AL1, 3H-13AL1-01, 3H-13AL1-02, & 3H-13AL1-03 Application for Permit to Drill Document 1. 2. 3. 4. 5. 6. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b))...................................................................................................................2 LocationSummary .......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2 Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005 (c)(3)) ................................... .................... ........ ....... -........ .......... ...................................................... .2 Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2 Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2 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)(8))...................................................................................................................................................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 3H-13AL1, 3H-13AL1-01, 31-1-13AL1-02, & 3H-13AL1-03 laterals ..........................6 Attachment 2: Current Well Schematic for 3H-13A.........................................................................................................6 Attachment 3: Proposed Well Schematic for 3H-13AL1, 3H-13AL1-01, 31-1-13AL1-02, & 31-1-13AL1-03 laterals ............6 Page 1 of 6 October 23, 2018 PTD Application: 3H-13AL1, 3H-13AL1-01, 3H-13AL1-02, & 3H-13AL1-03 1. Well Name and Classification (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b)) The proposed laterals described in this document are 3H-13AL1, 3H-13AL1-01, 3H-13AL1-02, and 3H-13AL1- 03. 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 31-1-13AL1, 31-1-13AL1-01, 31-1-13AL1-02, and 31-1-13AL1-03. 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 4,800 psi. Using the maximum formation pressure in the area of 4,897 psi in 31-1-22 (i.e. 15.5 ppg EMW), the maximum potential surface pressure in 31-1-13A, assuming a gas gradient of 0.1 psi/ft, would be 4,299 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 3H -13A was measured to be 2,567 psi (8.3 ppg EMW) on 9/16/2015. The maximum downhole pressure in the 31-1-13A vicinity is the 31-1-22 at 4,897 psi (15.5 ppg EMW) measured on 6/17/2018. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 31-1-13A have injected gas, so there is a possibility of encountering free gas while drilling the 3H -13A 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 3H -13A 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 3H -13A 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 23, 2018 PTD Application: 3H-13AL1, 3H-13ALI-01, 3H-13ALl-02, & 3H-13ALl-03 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 3H-13AL1 7,750' 10,600' 5,932' 5,935' 2-3/8", 4.7#, L-80, ST -L slotted liner; 0' 110' . 670 Surface aluminum billet on to 3H-13AL1-01 7,430' 10,600' 5,940' 5,900' 2-3/8", 4.7#, L-80, ST -L slotted liner; 92 29' 3520 2020 Production 7" aluminum billet on to 3H-13AL1-02 7,650' 10,000' 5,929' 5,984' 2-3/8", 4.7#, L-80, ST -L slotted liner; 4980 4320 Liner 3-1/2" 9.3 aluminum billet on to 3H-13AL1-03 7,330' 10,000' 5,910' 5,942' 2-3/8", 4.7#, L-80, ST -L slotted liner; 10540 Tubing 3-1/2" 9.3 J-55 with de to ment on to Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded 0' 110' 0' 110' 1640 670 Surface 9-5/8" 36.0 J-55 B TC 0' 3072' • 0' 92 29' 3520 2020 Production 7" 26.0 J-55 BTC 0' 5970" 0' 5173' 4980 4320 Liner 3-1/2" 9.3 L-80 BTC -MOD 5808' 7755' • 5049' 6203' 10160 10540 Tubing 3-1/2" 9.3 J-55 ELIE 8rd 0' 5836' 0' 5071' 6980 7400 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 3H -13A 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 Page 3 of 6 October 23, 2018 PTD Application: 3H-13AL1, 3H-13AL1-01, 3H-13AL1-02, & 3H-13AL1-03 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. Pressure at the 3H-13 Window (7338' MD. 5985' TVD) Usina 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 Well KRU 3H -13A is a Kuparuk A -sand producer equipped with 3-1/2" tubing and 3-1/2" production liner. The CTD sidetrack will utilize four laterals to target the A sand to the north and south of the 3H -13A parent wellbore. The laterals will increase recovery and add additional resources. Pre -CTD Work 1. RU Slick]ine: Drift tubing with dummy whipstock and obtain SBHP. 2. RU Service Coil: Mill out "D" nipple and conduct fill cleanout. 3. Prep site for Nabors CDR3-AC rig. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3H-13AL1 Lateral (Al sand- south) a. Set top of whipstock at 7338' MD. Page 4 of 6 October 23, 2018 Pumps On 1.8 bpm) Pumps Off A -sand Formation Pressure 8.3 2567 psi 2567 psi Mud Hydrostatic 8.6 2677 psi 2677 psi Annular friction i.e. ECD, 0.08psi/ft) 587 psi 0 psi Mud + ECD Combined no chokepressure) 3264 psi Overbalanced -697psi) • 2677 psi Overbalanced -110 si • Target BHP at Window 11.8 . 3672 psi 3672 psi Choke Pressure Required to Maintain Target BHP 408 psi 995 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 Well KRU 3H -13A is a Kuparuk A -sand producer equipped with 3-1/2" tubing and 3-1/2" production liner. The CTD sidetrack will utilize four laterals to target the A sand to the north and south of the 3H -13A parent wellbore. The laterals will increase recovery and add additional resources. Pre -CTD Work 1. RU Slick]ine: Drift tubing with dummy whipstock and obtain SBHP. 2. RU Service Coil: Mill out "D" nipple and conduct fill cleanout. 3. Prep site for Nabors CDR3-AC rig. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3H-13AL1 Lateral (Al sand- south) a. Set top of whipstock at 7338' MD. Page 4 of 6 October 23, 2018 PTD Application: 3H-13AL1, 3H-13AL1-01, 311-13AL1-02, & 3H-13AL1-03 b. Mill 2.80" window at 7338' MD. c. Drill 3" bi-center lateral to TD of 10600' MD. d. Run 2-3/8" slotted liner with aluminum billet from TD up to 7750' MD. 3. 3H-13AL1-01 Lateral (A2/A3 sand -south) a. Kickoff of the aluminum billet at 7750' MD. b. Drill 3" bi-center lateral to TD of 10600' MD. c. Run 2-3/8" slotted liner with aluminum billet from TD up to 7430' MD. 4. 3H-13AL1-02 Lateral (Al sand - north) a. Kickoff of the aluminum billet at 7430' MD. b. Drill 3" bi-center lateral to TD of 10000' MD. c. Run 2-3/8" slotted liner with aluminum billet from TD up to 7650' MD. 5. 3H-13AL1-03 Lateral (A2/A3 sand -north) a. Kick off of the aluminum billet at 7650' MD. b. Drill 3" bi-center lateral to TD of 10000' MD. c. Run 2-3/8" slotted liner with deployment sleeve from TD up to 7330' MD. 6. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 1. Obtain SBHP. 2. Change out gas lift design. 3. 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 3H -13A 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 Page 5 of 6 October 23, 2018 PTD Application: 3H-13AL1, 3H-13AL1-01, 3H-13AL1-02, & 3H-13AL1-03 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. 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 3H-13AL1 4760' 3H-13AL1-01 4820' 3H-13AL1-02 6630' 3H-13AL7-03 6850' - Distance to Nearest Well within Pool Lateral Name Distance Well 3H-13AL1 703' 31-1-12A 3H-13AL1-01 703' 31-1-12A 3H-13AL1-02 155' 31-1-13A 3H-13AL1-03 155' 3H -13A 16. Attachments Attachment 1: Directional Plans for3H-13AL1, 3H-13AL1-01, 3H-13AL1-02, & 3H-13AL1-03 laterals Attachment 2: Current Well Schematic for 3H -13A Attachment3: Proposed Well Schematic for 3H-13AL1, 3H-13AL1-01, 3H-13AL1-02, &3H-13AL1-03 laterals Page 6 of 6 October 23, 2018 ConocoPhillips Project: Kuparuk River Unit aemwlawme xona Ltamalm HwlM1. Ma WELLBORE DETAILS: 3H-13AL1 REFERENCE wfoRMA310w 3i-2 Sill Co ral,(NE) Refererrz: MIN W-13, Rye worm Site: Kuparuk 3H Patl Maprelic. Parent Milbone: 3H -13A VKW MD)%Weln: 3+13®76.110ury 13H.13) Well: 3H-13 ctarle. a 74 al.5; Te on MD:7300.00 seclioe (ve) Ral.i 3lm-(I o.mE) Wellbore: 3H-13AL1 owa . mai MeeanM cloth Relaelcr 3+13 78Ao1af1(3H-13) Plan: 3H-13AL1 wPO4 (SH-13/SH-13ALi) uoG1bFee cAnda. Weed Mo.. CulvAl BA ER FGIHES �U GE wmyany 3111 WeS*)/E1I*+) vlolnn. 3H-13 0 713.00usR (3H-13) 3114)1 3i-2 Sill l 1-112 :II-tl/111JIA1.1 ]H32/3n-221,1-IAPItI :II 31n111i1n { 'II-, I BSSO{4 mwu n.l� m wilI'll 1. 8100 11 601x1 !oi 9560'! "11i='zai aopi ' n"1111 .-n-2Jn1-z? 0200. _:o-^_zn11a21.1 6]50, � filM1t _ JI ,:Ii zW l+rz II It 111 IiAll� l i :300 X04+ I �: 11 I 191 I ill -11y1-19 ally ill 5850 I TF_tl4u-2.`P �o t - f, 11nzll., sr ! e roW Ili L'I�A.I+ ?hI 5400 —_ ,IY_ II / b 11 11 1]11141] .jt., 4�M10 4950 a!/ is __.. W 1 hyauLl. uuu >m:v:14: n.uv1 45001 _. I. �3 l(b Llnu.w l+imm I��.HIIII-ulsll. p ]1f_ flI a1ao1 ' 4050 N Loy sow n1- 1811i,11.1112 �/T -11-I�I41e111 1 SII=91114 . 1-�F'ill x.1'51 � 3500 11 111.' t; :14 l 1I.IiA""r,fj 'tfb�Pl j"Illll ilfll.l �+ ➢I 1 11 1" „6 " _ h� IM1 Bl. - 0 3150 II 1= 111h H2. 'I If 111 1 II I' .IlfNlldi }111 _ 2100 -� E + 11614U1I I'OI _ c o tIHVAII-IaN 6 - 1111 IIINL'�b2 I800� dills -- 1D1! )y `'F 11311111-'.N: �/ll_ IlF AIS If II 11 MALI all .�nlld9M 3nl II-'� II A1Y11 .i -111-11 11 IIAl.lsil I350 IL:" 11 r1Y1�� rIll-11,U1.111 9001 31I-11v1u Iru: AI + 1 n 450 II 10'(11-141 I .i/!14]� I _ _ d b'II I E ]II -I I-II -450 ' ➢4].nll-"n1111 ?II-I✓nl4lpCl.l SUi1p 11-1!.il!-11ir\I'xl 1115 MJiI ICY. °{i1=111111-».\1.11`131 _ _13501 n1-1 ti11-14n _._ 9650 7'D0 0950 -6300 -5850 -5400 -4950 -4500 AM 3600 -3150 -2700 _250 -1800 450 90D � Ie50 IB00 2SD., 2900 3150 36D0 4050 Y500 495D 5400 B50 0300 (SO '200 3111 WeS*)/E1I*+) vlolnn. 3H-13 0 713.00usR (3H-13) 3114)1 ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 3H Pad 3H-13 3H-13AL1 Plan: 3H-13AL1_wp04 Standard Planning Report 22 October, 2018 BA UGHES a GE company ConocoPhillips Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kupamk River Unit Site: Kuparuk 3H Pad Well: 31-1-13 Wellbore: 3H-13AL1 Design: 3H-13AL1_wp04 ConocoPhillips Planning Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Wall 3H-13 Mean Sea Level 31-1-13 @ 76.00usft (31-1-13) True Minimum Curvature BA ER 01 F UGHES a GE company 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 Kupamk 3H Pad Site Position: From: Map Northing: Easting: 6,000,110.73 usft 498,655.44 usft Latitude: Longitude: 70'24'4L531N 150° 0' 39.416 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: -0.01 ' Well 3H-13 Well Position -NAS •E/ -W Position Uncertainty 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: Wellbore 3H-13AL1 Magnetics Model Name Sample Date BGGM2018 11A/2018 Design Audit Notes: Version: Vertical Section: 3H-13AL1_wp04 6,000,475.46 usft Latitude: 498,655.42 usft Longitude: usft Ground Level: Declination Dip Angle 16.83 80.91 Phase: PLAN Tie On Depth: Depth From (TVD) *N/S +E/ -W (usft) (usft) (usftl 0.00 0.00 0.00 70" 24'45 .119 N 150" 0' 39.419 W 0.00 usft Field Strength (nT) 57.435 7,300.00 Direction (I 180.00 10/22/2018 6:19:44PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BA ER ConocoPhillips Planning Report F IIGHES aGEmmpany Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 31-1-13 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 31-1-13 @ 76.00usft (31-1-13) Site: Kuparuk 3H Pad North Reference: True Well: 31-1-13 Survey Calculation Method: Minimum Curvature Wellbore: 31-1-13AL1 Azimuth System Design: 3H-13AL1 wp04 Rate Rate Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System -NIS +El -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°I100usft) (°I100usft) (°NOOusft) (°) Target 7,300.00 58.10 31.77 5,891.35 3,000.97 -820.75 0.00 0.00 0.00 0.00 7,338.00 58.36 31.86 5,911.36 3,028.43 -803.72 0.72 0.70 0.23 15.79 7,359.00 60.92 33.54 5,921.98 3,043.67 -793.93 14.00 12.18 8.01 30.00 7,431.69 90.00 49.22 5,940.14 3,095.29 -747.59 45.00 40.01 21.57 30.00 7,675.00 91.89 158.72 5,934.21 3,045.20 -545.86 45.00 0.77 45.00 88.00 8,000.00 90.19 181.41 5,928.24 2,727.22 -490.17 7.00 -0.52 6.98 94.00 8,175.00 90.19 193.66 5,927.65 2,554.07 -513.08 7.00 0.00 7.00 90.00 8,275.00 66.69 199.73 5,930.37 2,458.37 -541.77 7.00 -3.49 6.07 120.00 8,550.00 89.51 180.67 5,939.57 2,189.14 -590.18 7.00 1.02 -6.93 278.00 8,850.00 89.54 201.67 5,942.10 1,896.48 -647.98 7.00 0.01 7.00 90.00 9,100.00 90.46 184.20 5,942.10 1,653.77 -703.72 7.00 0.37 -6.99 273.00 9,400.00 90.43 205.20 5,939.74 1,365.21 -779.41 7.00 -0.01 7.00 90.00 9,700.00 83.71 185.27 5,955.23 1,077.80 -857.83 7.00 -2.24 -6.64 251.00 10,000.00 91.12 204.95 5,968.91 790.13 -935.65 7.00 2.47 6.56 70.00 10,300.00 94.61 184.21 5,953.77 501.81 -1,010.74 7.00 1.17 -6.91 280.00 10,500.00 93.27 198.18 5,939.96 306.58 -1,049.40 7.00 -0.67 6.98 95.00 10,600.00 92.39 191.23 5,935.02 210.03 -1,074.74 7.00 -0.87 -6.95 263.00 101222018 6:19:44PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BAT ConocoPhil�,lips Planning Report IGHES a GEwmpany Database: EDT 14 Alaska Production Local Coordinate Reference: Well 31-1-13 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 31-1-13 @ 76.00usft (3H-13) Site: Kuparuk 3H Pad North Reference: True Well: 31-1-13 Survey Calculation Method Minimum Curvature Wellbore: 3H-13AL1 Design: 3H-13AL1_wPO4 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N1 -S +Ef-W Section Rate Azimuth Northing Easting (usft) (_) V) (usft) (usft) (usft) (usft) (°HOOusft) V) (usft) (usft) 7,300.00 58.10 31.77 5,891.35 3,000.97 -820.75 -3,000.97 0.00 0.00 6,003,476 28 497,835.29 TIP 7,338.00 • 58.36 31.86 5,911.36 3,028.43 -803.72 -3,028.43 0.72 15.79 6,003,503.73 497,852.33 KOP 7,359.00 60.92 33.54 5,921.98 3,043.67 -793.93 -3,043.67 14.00 30.00 6,003,518.97 497,862.12 End 14 dis, Start 45 dis 7,400.00 77.20 42.88 5,936.61 3,073.51 -770.22 -3,073.51 45.00 30.00 6,003,548.80 497,885.83 7,431.69 90.00 49.22 5,940.14 3,095.29 -747.59 -3,095.29 45.00 26.62 6,003,570.58 497,908.46 4 7,500.00 91.02 79.94 5,939.52 3,124.26 -686.63 -3,124.26 45.00 88.00 6,003,599.54 497,969.42 7,600.00 91.94 124.95 5,936.79 3,103.28 -591.51 -3,103.28 45.00 88.28 6,003,578.54 498,064.53 7,675.00 91.89 158.72 5,934.21 3,045.20 -545.86 -3,045.20 45.00 89.51 6,003,520.45 498,110.16 End 45 dis, Start 7 dis 7,700.00 91.76 160.46 5,933.42 3,021.78 -537.15 -3,021.78 7.00 94.00 6,003,497.03 498,118.87 7,800.00 91.26 167.45 5,930.78 2,925.77 -509.54 -2,925.77 7.00 94.06 6,003,401.03 498,146.46 7,900.00 90.73 174.43 5,929.05 2,827.09 493.80 -2,827.09 7.00 94.24 6,003,302.36 498,162.18 8,000.00 90.19 181.41 5,928.24 2,727.22 490.17 -2,727.22 7.00 94.36 6,003,202.50 498,165.79 6 8,100.00 90.19 188.41 5,927.90 2,627.65 -498.73 -2,627.65 7.00 90.00 6,003,102.94 498,157.21 8,175.00 90.19 193.66 5,927.65 2,554.07 -513.08 -2,554.07 7.00 90.02 6,003,029.36 498,142.85 7 8,200.00 89.31 195.18 5,927.76 2,529.85 -519.30 -2,529.85 7.00 120.00 6,003,005.15 498,136.62 8,275.00 86.69 199.73 5,930.37 2,458.37 -541.77 -2,458.37 7.00 119.99 6,002,933.69 498,114.15 8 8,300.00 86.94 197.99 5,931.76 2,434.75 -549.84 -2,434.75 7.00 -82.00 6,002,910.07 498,106.07 8,400.00 87.95 191.06 5,936.23 2,338.11 -574.88 -2,338.11 7.00 -81.90 6,002,813.44 498,081.02 8,500.00 88.98 184.13 5,938.91 2,239.08 -588.08 -2,239.08 7.00 -81.59 6,002,714.42 498,067.80 8,550.00 89.51 180.67 5,939.57 2,189.14 -590.18 -2,189.14 7.00 -81.41 6,002,664.48 498,065.70 9 8,600.00 89.51 184.17 5,940.01 2,139.19 -592.29 -2,139.19 7.00 90.00 6,002,614.54 498,063.57 8,700.00 89.51 191.17 5,940.86 2,040.15 -605.63 -2,040.15 7.00 89.97 6,002,515.52 498,050.22 8,800.00 89.53 198.17 5,941.70 1,943.48 -630.95 -1,943.48 7.00 89.91 6,002,418.86 498,024.89 8,850.00 89.54 201.67 5,942.10 1,896.48 -647.98 -1,896.48 7.00 89.85 6,002,371.86 498,007.85 10 8,900.00 89.72 198.18 5,942.43 1,849.48 -665.02 -1,849.48 7.00 -87.00 6,002,324.87 497,990.80 9,000.00 90.09 191.19 5,942.59 1,752.80 -690.35 -1,752.80 7.00 -86.98 6,002,228.21 497,965.46 9,100.00 90.46 184.20 5,942.10 1,653.77 -703.72 -1,653.77 7.00 -86.97 6,002,129.19 497,952.06 11 9,200.00 90.46 191.20 5,941.30 1,554.73 -717.11 -1,554.73 7.00 90.00 6,002,030.17 497,938.66 9,300.00 90.45 198.20 5,940.51 1,458.07 -742.46 -1,458.07 7.00 90.06 6,001,933.52 497,913.29 9,400.00 90.43 205.20 5,939.74 1,365.21 -779.41 -1,365.21 7.00 90.11 6,001,840.68 497,876.33 12 9,500.00 88.15 198.58 5,940.98 1,272.49 -816.66 -1,272.49 7.00 -109.00 6,001,747.97 497,639.07 9,600.00 85.90 191.94 5,946.17 1,176.20 -842.94 -1,176.20 7.00 -108.92 6,001,651.70 497,812.78 9,700.00 83.71 185.27 5,955.23 1,077.80 -857.83 -1,077.80 7.00 -108.57 6,001,553.31 497,797.87 13 9,800.00 86.14 191.86 5,964.10 979.37 -872.66 -979.37 7.00 70.00 6,001,454.89 497,783.02 9,900.00 88.62 198.41 5,968.68 883.00 -898.73 -883.00 7.00 69.42 6,001,358.53 497,756.94 10,000.00 91.12 204.95 5,968.91 790.13 -935.65 -790.13 7.00 69.12 6,001,265.68 497,720.01 14 10,100.00 92.32 198.05 5,965.91 697.19 -972.26 -697.19 7.00 -80.00 6,001,172.75 497,683.38 10,200.00 93.49 191.14 5,960.84 600.60 -997.42 -600.60 7.00 -80.21 6,001,076.18 497,658.21 10/222018 6:19:44PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips BATH Conohillips Planning Report F�UGI coPES a GE. ,, Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kupamk River Unit +N/ -S Site: Kupanik 3H Pad Rate Well: 3H-13 Easting Wellbore: 3H-13AL1 (usft) Design: 3H-13AL7_wp04 (usft) Planned Survey 501.81 -1,010.74 Measured 7.00 TVD Below Depth Inclination Azimuth System (usft) V) (_) (usft) 10,300.00 94.61 184.21 5,953.77 15 -1,049.40 -306.58 10,400.00 93.97 191.20 5,946.28 10,500.00 93.27 198.18 5,939.96 16 7.00 -97.00 r 10,600.00 . 92.39 191.23 05,935.02 Planned TD at 10600.00 2,458.37 Casing Points Plan Annotations Local Co�ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-13 Mean Sea Level 3H-13 Q 76.00usft (3H-13) True Minimum Curvature Measured Vertical Vertical Dogleg Toolface Map Map +N/ -S +EI -W Section Rate Azimuth Northing Easting (usft) (waft) (usft) (°/100usft) (°I (usft) (usft) 501.81 -1,010.74 -501.81 7.00 -80.56 6,000,977.40 497,644.88 403.05 -1,024.10 403.05 7.00 95.00 6,000,878.66 497,631.49 306.58 -1,049.40 -306.58 7.00 95.52 6,000,782.19 497,606.18 210.03 -1,074.74 -210.03 7.00 -97.00 6,000,685.66 497,580.83 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (1n) (in) 10,600.00 5,935.01 23/8" 2.375 3.000 Measured Vertical Local Coordinates Depth Depth -NIS +E/ -W (usft) (usft) (usft) (usft) Comment 7,300.00 5,891.35 3,000.97 -820.75 TIP 7,338.00 5,911.36 3,028.43 -803,72 KOP 7,359.00 5,921.98 3,043.67 -793.93 End 14 dis, Start 45 die 7,431.69 5,940.14 3,095.29 -747.59 4 7,675.00 5,934.21 3,045.20 -545.86 End 45 dls, Start 7 dls 8,000.00 5,928.24 2,727.22 -490.17 6 8,175.00 5,927.65 2,554.07 -513.08 7 8,275.00 5,930.37 2,458.37 -541.77 8 8,550.00 5,939.57 2,189.14 -590.18 9 8,850.00 5,942.10 1,896.48 -647.98 10 9,100.00 5,942.10 1.653.77 -703.72 11 9,400.00 5,939.74 1,365.21 -779.41 12 9,700.00 5,955.23 1,077.80 -857.83 13 10,000.00 5,968.91 790.13 -935.65 14 10,300.00 5,953.77 501.81 -1,010.74 15 10,500.00 5,939.96 306.58 -1,049.40 16 10,600.00 5,935.02 210.03 -1,074.74 Planned TD at 10600.00 10222018 6.19:44PM Page 5 COMPASS 5000.14 Build 85D '- ConocoPhillips BER ConocoPhillips Travelling Cylinder Report F�UGHES aGEcompany Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kupamk 3H Pad Site Error. 0.00 usft Reference Well: 3H-13 Well Error: 0.00 usft Reference Wellbore 3H-13AL7 Reference Design: 3H-13ALi_wp04 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-13 31-1-13 @ 76.00usft (3H-13) 3H-13 @ 76.00usft (3H-13) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference 3H-13AL1_wp04 Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD interval 25.00usft Error Model: ISCWSA Depth Range: 7,300.00 to 10,600.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,252.40 usft Error Surface: Pedal Curve Summary Program Date 10/2212016 To Offset Centre to No -Go (usft) Survey (Wellbore) i,118.56 Tool Name Description Measured 100.00 5,905.00 3H -13(3H-13) GCT -MS Schlumberger GCT multishot 7,300.00 3H -13A ATDB(3H-13A) MWD MWD -Standard Depth 7,300.00 10,600.00 3H-13AL1_wp04(3H-13A1-1) MWD MWD - Standard from Plan --- (usft) (usft) Casing Poihffi_ (usft) Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,600.00 6,011.01 2 3/8' Out of range 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 3H Pad 3H-10 - 3H-10 - 3H-10 Out of range 3H-10 - 3H -10B - 3H-108 Out of range 3H-10 - 3H -10C - 3H -10C Out of range 3H-10 - 3H-10CL1 - 3H-10CL1 Out of range 3H-10 - 3H-1 OCL2 - 3H-10CL2 Out of range 3H-10 - 3H-1 OC1-2-01 - 3H-10CL2-01 Out of range 3H-10 - 3H-1 OC1-2-02 - 3H-10CL2-02 Out of range 3H-10 - 3H-10CPB7 - 3H -i OCPB1 Out of range 31-4-11 -3H-11 -31-1-11 Out of range 31-1-11 -3H-11A-3H-11A Out of range 31-1-11 - 3H-11 AL1 - 31-1-11 AL1 Out of range 31-1-11 - 3H-11 AL1 -01 - 31-1-11 AL1 -01 Out of range 31-1-12 - 311-12 - 3H-12 Out of range 3H -12 -3H -12A -3H -12A 9,266.32 8,975.00 703.66 222.06 482.76 Pass - Major Risk 31-1-12 - 3H-12AL7 - 3H-12AL7 8,200.00 7,710.00 964.41 209.97 755.21 Pass- Major Risk 31-1-12-311-12AL2-3H-12AL2 8,635.08 8,075.00 776.69 211.24 567.05 Pass - Major Risk 3H-1 2 - 3H-1 2AL3 - 3H-1 2AL3 8,200.00 7,900.00 771.08 210.69 561.62 Pass - Major Risk 3H-12 - 3H-12APB1 - 3H-12APB1 Out of range 3H -13 -3H -13-3H-13 8,475.00 6,525.00 879.94 40.57 840.65 Pass - Major Risk 3H -13 -3H -13A -3H -13A 8,375.00 6,575.00 711.53 13.98 699.05 Pass - Major Risk 3H-13-3H-13AL7-01-3H-13AL1-01_wp01 9,399.33 9,425.00 15.95 0.35 15.73 Pass - Minor 1/10 3H-13-3H-13AL7-02-3H-13AL1-02_wp02 8,375.00 6,575.00 714.19 13.67 702.05 Pass - Major Risk 31-1-13-3H-13AL1-03-3H-13AL1-03_wp03 8,375.00 6,575.00 714.19 13.67 702.05 Pass - Major Risk 31-1-14 - 31-1-14 - 3H-14 Out of range 31-1-14 - 31-1-14A - 3H -14A Out of range 31-1-14 - 3H-14APB1 - 3H-14APB1 Out of range 3H-14 - 3H -14B - 3H-148 Out of range 3H-14-31-1-1481-1-3H-14BLI Out of ran e CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10222018 2:58:17PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Project: Kuparuk River Unit Slte: Kuparek 3H Pad /um,Wulo Tme noon Rlpneh xoa,:,a ayo.lK r; WELLBORE DETAILS' 311-13AL1 REFERENCE MFORIMTION Parent Wellbore: 3H -13A TmewM �yemm Well: 3W13 Eta saxo ne on MD'. 7300.00 RD) R.b,em: W4 a.13. ) N Wellbore: 3H-13ALi Op�Me: tba, Northing Relarerve: WN,o ME) Plan: 311.13AL1_wpe4(311-1WW13AL1 1 umel. ei;�Flu�.1 Longitude 3113 Meesurea Oegn ReNrel,kJN-1Jg i6A0,MInNtJ1 cW Date, 0.00 6000475.46 uaatrt, seaea: M,m,ure Crtwert 5415 5510 G 5605 � 5'/00 h 5795 t 5890 5985 U y 6080 i 61]5 6270 650C 6000 55M 50a 4500 c X900( o3s0c 0 ra0a K250( 0 200( s 0160 rn 100( 50( -500 West( -)/East(+) (500 usft/in) UGHES aeE<m ny �■■■■■■■■■■■■■■■■■■� WELL DETAILS: 3H-13 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 6000475.46 498655.42 70° 24'45.119 N 150° 0' 39.419 W Sec MD Inc An TVDSS +W -S +E/ -W Dleg TFace VSect Annotation 1 7300.00 58.10 31.77 5891.35 3000.97 -820.75 0.00 0.00 -3000.97 TIP 2 7338.00 58.36 31.86 5911.36 3028.43 -803.72 0.72 15.79 -3028.43 KOP 3 7359.00 60.92 33.54 5921.98 3043.67 -793.93 14.00 30.00 -3043.67 End 14 d1s, Start 45 dls 4 7431.69 90.00 49.22 5940.14 3095.29 -747.59 45.00 30.00 -3095.29 4 5 7675.00 91.89 158.72 5934.21 3045.20 -545.86 45.00 88.00 -3045.20 End 45 dls, Start 7 dls 6 8000.OD 90.19 181.41 5928.24 2727.22 490.17 7.00 94.00 -2727.22 6 7 8175.00 90.19 193.66 5927.65 2554.07 513.08 7.00 90.00 -2554.07 7 8 8275.00 86.69 199.73 5930.37 2458.37 541.77 7.00 120.00 -2458.37 8 9 8550.00 89.51 180.67 5939.57 2189.14 -590.18 7.00 278.00 -2189.14 9 10 8850.00 89.54 201.67 5942.10 1896.48 -647.98 7,00 90.00 -1896.48 10 11 9100.00 90.46 184.20 5942.10 1653.77 -703.72 7.00 273.00 -1653.77 11 12 9400.00 90.43 205.20 5939.74 1365.21 -779.41 7.00 90.00 -1365.21 12 13 9700.00 83.71 185.27 5955.23 1077.80 -857.83 7.00 251.00 -1077.80 13 14 10000.00 91.12 204.95 5968.91 790.13 -935.65 7.00 70.00 -79D.13 14 15 10300.00 94.61 184.21 5953.77 501.61 -1010.74 7.00 280.00 -501.81 15 16 10500.00 93.27 198.18 5939.96 306.58 -1049.40 7.00 95.00 -306.58 16 17 10600.00 92.39 191.23 5935.02 210.03 -1074.74 7.00 263.00 -210.03 Planned TD at 10600.00 5415 5510 G 5605 � 5'/00 h 5795 t 5890 5985 U y 6080 i 61]5 6270 650C 6000 55M 50a 4500 c X900( o3s0c 0 ra0a K250( 0 200( s 0160 rn 100( 50( -500 West( -)/East(+) (500 usft/in) UGHES aeE<m ny �■■■■■■■■■■■■■■■■■■� �I t- I �I $ n _ m G Q d 19 Is155e P K P 45 d . .......... n Z 311-13311-13. LI -0 4; \ 3H- 3AH- 3AL1 1 311.1] 1143 1-0 Id 5 dls, 6 ren 7 Is 7 B ti0 I I 1 1313H 13AL1 3 14131113A 311-1 I3H-1 SII■■■■■�■_,1m���®�■■■■■' 3H 13AL A2 Fa It2 3 13A Fault ■■■00011�111H■■■■■■■■' �'■MEN J1■■■■��_�®��■■■■' 6365 Mean Sea L N N N N Vertical Section at 180.00° (95 usft/in) u �I t- I �I $ n _ m G Q d 19 Is155e P K P 45 d . .......... n Z 311-13311-13. LI -0 4; \ 3H- 3AH- 3AL1 1 311.1] 1143 1-0 Id 5 dls, 6 ren 7 Is 7 B ti0 I I 1 1313H 13AL1 3 14131113A 311-1 I3H-1 3H 13AL A2 Fa It2 3 13A Fault 6365 Mean Sea L N N N N Vertical Section at 180.00° (95 usft/in) u 'he", JW KUP PROD 3H -13A ConocoPhillips Well Athlbutes Max Angle & MD TD ABSILa Inc WeI1GOre APIIUWI Fieltl Name Wellbore Status 501032008901 KUPARUK RIVER UNIT PROD Incl Pl MOIXMB) ACI BIm IXNBf 5934 6,97611 7,755.0 Comment H2S(rKne Dale SSSV: NIPPLE 250 4/2/2015 AnnmYcn Ino, L.MM, 1/0/199] KB Grtl 911 Po9 Releaze CaM 37.01 11911988 3Hd3A99(10ld4:1964pe1 AnmiMcn CeptN (me, EnE WIe AnndMion LaslMctl By End Dah Last Tag. SLM 7,6240 9/16/2015 Rev Reason: GLVC/0, TAG, H23 pp,Oven 9)29/2015 XANGCF, Causing Strings Casing 0 --pion TO) Top IHKB) set0eptn (XKB) seleepin(NDT.. WI/Len (I.. Grvle Top Tn,oin CONDUCTOR 5062 350 1100 1100 62.50 H40 WELDED Casing 0 --pi.. iop lnK8) set Depth IXKB/ SN CepM (NDI... WULen (I... Grtle Top Th,mtl SURFACE .9213603.0]1.8 2,9284 3OW 755 BTC Caslnp N-1pWn )iop(M(B)sat Gogh IHKB) sN CepM nV01... WIILen IL.. Grad TopTh,. PROMOTION Past6.276 330 5,9700 5.1725 2800755 BTC SR Lasing 0esctlp11on OD lin) /Ohio) Tap(XnBI .1 Depm(ft B1 sN cepin nvOl... widen 9._ Gmce IT.Innnead LINER 312 2.992 5,803.4 7.7550 9.30 L-80 BTC -MOD Liner Details Namin) IDS Top (5,8 Top 9V TUP 140,5) nem om Co. Ilio) 5,8000 5,049.] 4D.50 TIEBACK/ BAKER LINER TIEBACK SLEEVE wIBAKER G2 5.250 5,049.) cOxDUcTee ; ad.11voD PACKER ZXP LINER TOP PACKER 5.322.3 50603 4046 HANGER BAKER HMC LINER HANGER 4.375 NIPPLE: WIS 5.829.1 50654 4047 SeE BAKER SEAL BORE EXTENSION 4000 Tubing Strings Toeing Demipnoo slung Ma... IO(in) TOpInKB1 Set Oepin ln. sel0epinlrvol4.. wll5tt0 Gentle Topeonnemion GMLIR;L12aI TUBING 312 2.992 270 50364 5,8]10 930 J-55 EUE BrO Completion Details xomin Ilan Dem (in) Top (HKBI Top (Tela MKS) Top IndIlas W 27.0 0.16S HANGER MCEvoy3112"SOOOb GEN III TUCing Nangerwl J-55 Pup 2.992 Z7.0 EUE BN lop 5015 501.4 0.85 NIPPLE 312- Campo' USNipple 4.50"OD, 2.812'ID 2.812 SURFiieE 35113.0718- 5,8029 5,045.5 40.51 NIPPLE 31¢'CAMC79NIpplewl2. 5D' No -GO Profile 2.750 51809.9 5,050.9 40.5) LOCATOR BAKER LOCATOR 3.000 GAS UFT', 4126 5,812.0 5052.4 40.5) SEAL ASSY BAKER GBH SEAL ASSEMLY w/1 U'STROKE & 3.000 SPECIAL LOCATOR TO STAB INTO LINER TIE -BACK SLEEVE/PACKER GAS LIFT 5041 Other in Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top(NO TOP In<I Top IXKB/ IXKB/ °1 Oes Lom Run -in ID lin) 5946.0 5,1559 41061MNDOW SIOETRAOK CASING WINNOW 1/6/199] 6000 perforations & Slots GAS LIFT "I sne'i Den Top I.) Bbn Tva) 1an01de Top(HKB) sto III (HKBI MKB) IDne Dale n Type Com 7.229.0 7.2490 5.927,2 5,937.9174, UNIT B. 5/92002 40 RPERF 2.5"-SD.PJDPCH9s, 311-13A 60 deg pe wPPLE; s.m29 7.2500 7,308.0 5,942.7 5.969.2 AJ. A2. 3H- 13A 1121/199] 4.0 (PERE 100deg. 11SO phesing212' Carder 7,3560 7,366.0 58944 59993 A-1,31413.0 82512 9 6.0 APERF 2" HIM Millie... 60 cl ].3]2.0 7.380.0 6,002.7 6.006.9 A -1.311-13A 0252009 60 APERF 2"HMXMillenixm,60 LOCATOR: 5.e09.9 cl Mandrel Inserts st an SEALASSY;S8120 on N Top IHKB) TopINDI IHHBI Mile Medw Co9n)LG�U� vale Type lakn Type Pontine 9n) TRORU0 Ipeil Run DYe Co. 2.]201 2,651.1 Cemw KBUG 1GLV BK 0.156 1.3180 8252015 91132 INS 015 2 4,1176 3,7440 Cie. KBUG tGLV BK .1 1,28009252015 930 911312015 3 5,07].1 4,487.9 Ca. KBUG 1GLV BK 0.188 1,303.0 9252015 900 wIx00W5918A915015en04 3300,9700 57572 50100 Cameo MMM 11/2OV RK 0.188 0.0 91292015 230 W13/2 015 Notes: General & Safety End Dane Annotation 1/611997 NOTE:VeELL SIDETRACKED- ORIGINAL COMPLETION DATE 11411988 RPERF'. 7 M7 M0- 1/2012004 NOTE:WAIVEREDWELL: LAxOAOOMMUNICATION 8116/2009 NOTE: GWSPOT1/-]260'-]313' 11/292010 INCITE: Yew Shcematicw/Alaska ScbematiL90 PERF:7158.0-7.M0- APERE.7,]W0,7.M0- ApERF: 7S]207,390.0� LINER', 5,8[9.4�7700 3H -13A Proposed CTD Schematic at 110' MD at 3072' MD icketl at MD (1997) C -sand parts 7229-7249' MD sand ped" 7256'-7308' MD 7356'-7366MD 7372'-7380' MD r1/2", 9.3#, L-80 liner 08'-7755' MD 3-1/2" Camco DS -nipple at 502' MD (2.813" min ID) 3-1/2" 9.3# L-80 EUE Brd Tubing to surface 3-1/2" Camco KBUG gas lift mandrels 2720', 4118', & 5077' MD 3-1/2" Camco MMM gas lift mandrel 5757' MD 3-1/2" Cemoo D -nipple at 5803' MD (2.750" min ID) Baker 3-1/2" GBH -22 seal assembly at 5812' MD (3" ID) Liner too Baker 5" x 7" ZXP liner top packer at 5808' MD Baker 5" x 7" HMC liner hanger at 5822' MD Baker SBE (12' length with 4" ID seal bore) Landing collar at 7654' MD Tight spot in 3-'I" finer 72.V373 KOP at 7338' MD Baker 3.1/2' XL Monobore whipstock 31-1-13AL1-03 wP03 TO @ 10,000' MD Liner top at 7330' MD 31-1-13AL1-02 wp02 TO @ 10,000' MD Liner Billet at 7650' MD 3H-13AL1-01 wp01 TO @ 10,600' MD Liner Billet @ 7430' MD 3H-13AL1 wp04 TO @ 10,600 MD Liner Billet @ 7,750' MD Loepp Victoria T (DOA) From: Long, William R <William.R.Long@conocophillips.com> Sent: Tuesday, October 23, 2018 8:49 AM To: Loepp, Victoria T (DOA) Cc: Starck, Kai; Ohlinger, James J; Herring, Keith E; McLaughlin, Ryan Subject: KRU 2G-06 CTD Backup Window Unsuccessful Victoria, Unfortunately CDR3 was unsuccessful in milling the backup window. Data indicates that the backup high expansion wedge, whipstock, slid downhole. CDR3 plans to rig down and move off this well. 4//S/ We will plan to submit a Sundry Report (10-404) for KRU 2G-06 (184-082) and a Completion Report (10-407) for the L1 (218-112) plug back lateral within 30 days. Included will be an operations summary report and a updated schematic. If further analysis indicates that it will be possible to come back to this well and successfully mill a window, we will submit an Application for Sundry Approvals prior to doing so in the future. Please let me know if you would like any further information, or us to use any different forms to document these operations. Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372 (office) 281-723-6000 (cell) William.R.Long@ConocoPhillips.com From: Long, William R Sent: Saturday, October 20, 2018 5:41 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Ohlinger, James J <James.J.Ohlinger@conocophillips.com>; Starck, Kai <Kai.Starck@conocophillips.com>; Herring, Keith E <Keith.E.Herring@co nocophillips.com>; McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com>; Nabors CDR3 Company Man<NaborsCDR3CompanyMan@conocophillips.com> Subject: KRU 2G-06 CTD Backup Window Victoria, CDR3 is currently rigged up on KRU 2G-06 (184-082) and has been attempting to drill the Ll lateral (218-112). We have made multiple attempts to drill the build section of the hole and conducted multiple fill cleanouts. We continue to experience excess cuttings returns, hole problems, and pack offs. We plan to move up hole approximately 40' and set another high expansion wedge, a type of whipstock, cut a backup window, and make another attempt to drill the L1 lateral. The window exit style, lateral targets, and overall drilling program plan and objectives remain unchanged. Please let us know if any approval or further documentation is required. Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372 (office) 281-723-6000 (cell) William R.Long(@ConocoPhillips.com TRANSMITTAL LETTER CHECKLIST WELL NAME: K R Cl_ 3t -f— 13 A L PTD: -a18-135 t.Development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: k'14 P&VWL R 1 VQ V- POOL: tA D alr al< D 1 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 -:J LATERAL No. 4 q6 — 1 q API No. 50- I D J" 514 -_L-_• (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 from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample' than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of 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 l 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. hi 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 PTD#:2181350 10 Appr Date 11 12 DLB 10/23/2018 . _ RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 'H-13A_L1 Program DEV Well bore seg :ND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal n Geologic Engineering Public Commissioner: Date: Commission r: Date in rssi Date D�5 Io)z31J8 18 Nonconven, gas conforms to AS31.05.030Q.1.A).Q-2.A-D)----- - -- -----NA- ------------------------------------- - ------------------------ Permitfeeattached-- ---- ------ ------------ ------- ----- --- _.NA------- --- - -------.......--........ --- _-------- -- Lease number appropriate- .. - - - - - - .. - - - - _ _ Yes Unique well name and number _ _ .... _ - - - - - - - - - _ Yes - - --- - - - - - - - - -- - - .Well located in -a defined. pool. _ _ _ _ _ ... _ _ __ _ ___ _ _ _ _ _ _ _ _ _ Yes Well located proper distance from drilling unit. boundary. _ _ _ _ _ _ _ _ _ . .... _ Yes Well located proper distance from other wells . . . . . . . ....... . . _ _ _ _ _ Yes _ _ _ ... Sufficient acreage. available indrillingunit .. _ _ _ _ _ _ _ _ Yes If deviated, is wellbore plat. included _ _ _ _ . . . . . . ........... . . No _ Directional -plan view enclosed Operator only affected party... _ _ _ _ _ _ _ - . - - - - - Yes Operator hasappropriate bond in farce _ ....... Yes Permit can be issued without conservation order. _ _ _ _ _ _ _ _ _ Yes _ Permit can be issued without administrative approval _ _ _ _ - - _ _ _ _ _ _ _ Yes Can permit be approved before 15 -day wait... _ _ _ _ ........ Yes _ Well located within area and. strata authorized by Injection Order # (put 10# incomments)(For. NA At wells within 1/4 mile area of review, identified (For service well only) _ .... NA .. _ Pre -produced injector; duration of pre production less than 3 months (For service well only) - - NA _ _ _ ...... Geologic Engineering Public Commissioner: Date: Commission r: Date in rssi Date D�5 Io)z31J8 18 Conductor stringprovided.. _ _ _ _ _ _ _ _ _ _ _ _ _____ _ _ _ _ _ _ _ NA Conductor set -for -KRU- 3H-13 Engineering 19 Surface casing. protects all known USDWs _ _ _ _ _ _ _ .......... _ _ NA Surface casing set for KRU 3H-13 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 slotted liner 23 Casing designs adequate for C,. T, B &. permafrost _ _ _ _ _ _ _ ____ _ _ _ Yes 24 Adequate tankage or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ ..... _ _ _ _ _ _ Yes _ Rig has steel tanks; all waste. to approved disposal wells 25 If a re -drill, has a 10-403 for abandonment been approved _ _ _ _ _ _ - - - - - NA 26 Adequate wellbore separation proposed ... _ _ _ _ ..... _ Yes _ Anti -collision analysis complete; no major risk failures _ 27 If. diverter required, does it meet regulations _ . _ _ _ _ _ _ _ _ _ _ NA Appr Date 28 Drilling fluid program schematic .& equip list adequate _ _ _ _ Yes Max formation pressure is. 4897 psig(15.5 ppg.EMW ); will drill w/ 8,6 ppg EMW and maintain overbal w/ MPD VTL 10/23/2018 29 BOPEs, do they meet regulation _ _ _ _ _ _ - - - - - - - Yes 130 BOPE.press rating appropriate; test to (put psig in comments)_ _ _ _ _ _ .. _ Yes _ MPSP is 4299 psig; will test BOPs.to 4600_psig. 31 Choke. manifold complies w/API RP -53 (May 84) _ _ _ _ _ _ Yes 32 Work will occur without operation shutdown ....... .. ................ Yes.... 33 Is presence of H2$ gas probable . . . . . . .. . . . . .... _ _ Yes _ _ H2S measures required _ 34 Mechanical condition of wells within AOR verified (For service well only) . _ _ _ _ _ _ _ ...NA .... 35 Permitcan be issued w/o hydrogen sulfide measures. - - _ _ _ _ ..... ..... _ No _ - 3H -Pad wells are H2S-bearing. H2S measures are required. Geology 36 Datapresented on potential overpressure zones _ ____ _ _ _ _ _ ____ _ _ _ _ _ _ _ Yes Appr Date 37 Seismic analysis of shallow gas zones _ _ _ .. - _ _ _ _ _ ......... NA DLB 10/23/2018 38 Seabed oondition survey (if off -shore) _ _ _ _ _ . - - - - - - - - - - NA _ _ _ _ ... - - 39 Contact name/pbone for weekly progress reports [exploratory only] . . . . . . . ...........NA Geologic Engineering Public Commissioner: Date: Commission r: Date in rssi Date D�5 Io)z31J8
