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Home My WebLink About217-133MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 8, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1H-111 KUPARUK RIV UNIT 1H-111 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/08/2025 1H-111 50-029-23581-00-00 217-133-0 W SPT 3724 2171330 1500 1040 1040 1039 1037 90 90 90 90 4YRTST P Austin McLeod 8/20/2025 MITIA. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1H-111 Inspection Date: Tubing OA Packer Depth 520 2015 2000 1990IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250823130713 BBL Pumped:1.1 BBL Returned:1 Wednesday, October 8, 2025 Page 1 of 1             TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard Drive data drop 1H-111 50-029-23581-00 217133_1H-111_IPROFWFL_03JUL2023 1H-114 50-029-23584-00 217136_1H-114_IPROF_17Oct23 1H-115 50-029-23605-00 218053_1H-115_IPROF RSTWFL_09May2022 1H-116 50-029-23594-00 218012_1H-116_IPROFWFL_05Jul2023 1H-117 50-029-23602-00 218032_1H-117_PPROF-WFL_06July23 218032_1H-117_WFL_18Oct23 1H-119 50-029-23591-00 217178_1H-119_WFL_07Jul2023 1J-102 50-029-23317-00 206110_1J-102_RPPG_18Jul2023 1J-107 50-029-23366-00 207107_1J-107_PPROF_10May2022 1J-162 50-029-23360-00 207080_1J-162_LDL_03May2022 1J-170 50-029-23310-00 206062_1J-170_Temp-Pres_11Jul2023 1J-176 50-029-23364-00 207099_1J-176_LDL_11May2022 4of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38340 T38341 T38342 T38344 T38343 T38345 T38346 T38347 T38348 T38349 T38350 2/29/2024 1H-111 50-029-23581-00 217133_1H-111_IPROFWFL_03JUL2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:34:11 -09'00' MEMORANDUM To: Jim Regg1 ( J P.1. Supervisor I e. ,�� I � � FROM: Bob Noble Petroleum Inspector Well Name KUPARUK RIV UNIT 1H-1 I I Insp Num: mitRCN210802130302 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, August 6, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1H -III KUPARUK RIV UNIT 1H-11 I Sres Inspector Reviewed By: P.1. Suprv� Comm API Well Number 50-029-23581 -00-00 Inspector Name: Bob Noble Permit Number: 217-133-0 Inspection Date: 8/2/2021 Packer Well 111-n 1 Type Inj w TVD PTD 2171330 Type Test SPT Test psi BBL Pumped: 0.9 1 BBL Returned: Interval 4YRTST P/F Notes: Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 3724 - Tubing 1023 - 1023 1023 1023 1500 IA 520 1840 1820 1820 0.9 OA 386 389. 389 389 P Friday, August 6, 2021 Page I of 1 Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1A-01 50-029-20590-00 n/a Kuparuk River Packer Setting Record Field- Final 6-Dec-20 0 1 2 1A-01 50-029-20590-00 n/a Kuparuk River Packer Setting Record Field- Final 7-Dec-20 0 1 3 1C-25 50-029-22941-00 906866139 Kuparuk River Packer Setting Record Field- Final 15-Dec-20 0 1 4 1H-108B 50-029-23608-02 906811421 Kuparuk River Water Flow Record Field- Final 12-Nov-20 0 1 5 1H-109 50-029-23595-00 906810847 Kuparuk River Injection Profile Field & Processed 14-Nov-20 0 1 6 1H-111 50-02923581-00 906831134 Kuparuk River Injection Profile Field & Processed 21-Nov-20 0 1 7 1H-115 50-029-23605-00 906832402 Kuparuk River Injection Profile Field & Processed 23-Nov-20 0 1 8 1H-117 50-029-23602-00 906810277 Kuparuk River Injection Profile Field & Processed 20-Nov-20 0 1 9 1J-118 50-029-23337-00 906798402 Kuparuk River Plug Setting Record Field- Final 1-Nov-20 0 1 10 1Y-19 50-029-22391-00 906849383 Kuparuk River Leak Detect Log Field- Final 7-Dec-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the 01/08/2021 01/11/2021 Abby Bell PTD: 2171330 E-Set: 34542 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Monday, February 3, 2020 7:48 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: KRU 1 H-111 (PTD 217-133) Completion of 60 day monitor period update Attachments: 1 H-111 90 day TIO 2-3-20.pdf; 1 H-111.pdf Chris, KRU West Sak injector 1H-111 (PTD 217-133) was reported for unexplained IA pressure decrease on 12/5/20. DHD was mobilized and performed initial diagnostics that consisted of tubing and inner casing pack off tests and an MIT -IA, which all passed. After watching the TIO trends for the 60 -day monitor, it appears the IA pressure decrease is due to a thermal reaction from the tubing injection temperature slowly decreasing. The well will return to normal injection status. Attached is a wellbore schematic and 90 -day trend. Please let us know if you disagree with this plan. Thank you, Paul Duffy for Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM cornca'PMNP$ From: Wellrity Compliance Specialist CPF1 & 2 Sent: Thursday, DftRynber 5, 2019 7:46 AM To: 'chris.wallace@alasov'<chris.wallace@alaska.gov> Cc: CPA Wells Supt <n1030 ocophillips.com> Subject: KRU 1H-111 (PTD 217-13 eport of suspect IA pressure decrease Chris, KRU West Sak injector 1H-111 (PTD 217-133) is exhibits unexplained IA pressure decrease. DHD will mobilize to the well to perform initial diagnostics after which the well will ut on a 60 day monitor due to the slow nature of the phenomenon. The proper paperwork for continued injection or forward has been determined. A wellbore schematic and 90 day Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. action will be submitted once the path are attached. Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax -00 11-1-119 IH -115 IH -108B 1 H-116 nt Name Delivered to: AOGCC '�vk ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision •,.� 333 W. 7th Ave, Suite 100 • Anchorage, AK 99501 2 17 133 3 196 8 TRANSMMALOATr24Jan-20 24Ja n20JW 02 .,..vn niv�rc wL IPROF FINAL FIELD 10 -Jan -20 1 KUPARUK Signature Please return via courier or sign/scan and email a copy WL WL RIVER RIVER 2 Date hlumberger and CPAI. —Com Schlumberger -Private WFL FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 17 -Jan -20 18 -Jan -20 19 -Jan -20 7 1 A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophill ips.com> Sent: Thursday, December 5, 2019 7:46 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1 H-111 (PTD 217-133) Report of suspect IA pressure decrease Attachments: 1 H-111.pdf, 1 H-111 90 day TIO 12.5.19.pdf Chris, KRU West Sak injector 1H-111 (PTD 217-133) is exhibiting unexplained IA pressure decrease. DHD will mobilize to the well to perform initial diagnostics after which the well will be put on a 60 day monitor due to the slow nature of the phenomenon. The proper paperwork for continued injection or corrective action will be submitted once the path forward has been determined. A wellbore schematic and 90 day TIO trend are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM ca�wcaHun�rx Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: n !' AOGCC . ATTN: Natural Resources Technician it Alaska Oil & Gas Conservation Commision \! 333 W. 7th Ave, Suite 100 �ft Anchorage, AK 99501 TRANSMITTALOATE TRANSMITTAL N 217133 WELL NAME API it ORDERSERVICE # FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA DATELOGGED Prints r 1H-114 1H-111 1H-105 1H-113 1H-116 3M•19 3G -07A 50-029.23584-00 50.029-23581-00 50-029-20727-01 50.029-23588.00 50.029.23594.00 50-029-21737-00 50-103-20127-01 EOSH-00071 EAI8-00022 E118-00075 E118-00076 El18.0 0077 E118.00078 E118-00079 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL WL WL IPROF IPROF-WFL (PROF-WFL IPROF-WFL IPROF-WFL Caliper PPROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 15Ju1-19 17JuIA9 19 -Jul -19 20JuI-19 21 -Jul -19 22 -Jul -19 23Jul-19 1 1 1 1 1 1 1 50-103.20133-00 E718-00081 KUPARUK RIVER WL (PROF FINAL FIELD 25Ju1.19 1 EB-163G-11 ALI 3N -14A 3G-08 50-029-21720-00 50-029.22457-60 50.029-22102-00 50.029-23015-00 50-029-21589.01 50-103.20128.00 E118-00084 EDEA -00009 E118-00085 E118-00086 EOSH-00074 EOSH-00075 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL Memory WL WL WL WL Caliper PPROF LDL IPROF LDL,Caliper LDL,Caliper FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 28•Jul-19 28 -Jul -19 29 -Jul -19 1 -Aug -19 2 -Aug -19 3 -Aug -19 1 1 1 1 1 2N-317 50-103-20266.00 EOSH-00076 KUPARUK RIVER WL LDL FINAL FIELD 4 -Aug -19 1 RECEIVED 15 return via courier or sign/scan and email a copy to and CPAI. Schlumberger -Private SCANNED AUG 0 71019 A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. " specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 6, 2019 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7�' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Hollis French: �/I-/33 MAY 0 8 2019 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, r Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Kuparuk Field Date 5/6/2019 1J & 1H Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal U-180 50029233290000 2061500 20'9" 2.80 1'5" 5/4/2019 5 5/5/2019 1H-101 50029235850000 2171380 2'10" 0.70 9" 5/4/2019 2.2 5/5/2019 1H-102 50029235800000 2170970 2'9" 0.65 8" 5/4/2019 1.7 5/5/2019 1H-103 50029235930000 2180030 212.5" 0.45 9" 5/4/2019 2.2 5/5/2019 1H-104 50029236100000 2180840 2'.5" 0.40 9" 5/4/2019 2.2 5/5/2019 1H-1086 50029236080200 2180820 3'8" 0.80 10" 5/4/2019 2.5 5/5/2019 1 H-109 50029235950000 2180130 27" 0.40 9" 5/4/2019 2.2 5/5/2019 11-1-110 50029236010000 2180310 2'6.5" 0.65 8.5" 5/4/2019 2 5/5/2019 11-1-111 50029235810000 2171330 2' 0.35 9" 5/4/2019 2.2 5/5/2019 1H-113 50029235880000 2171680 2'1" 0.40 8" 5/4/2019 1.7 5/5/2019 1H-114 50029235840000 2171360 1111" 0.25 7.5" 5/4/2019 1.8 5/5/2019 1H-115 50029236050000 2180530 2'2.5" 0.35 8.5" 5/4/2019 2 5/5/2019 1H-116 50029235940000 2180120 17" 0.25 7" 5/4/2019 1.7 5/5/2019 11-1-117 50029236020000 2180320 1'11" 0.35 7" 5/4/2019 1.7 5/5/2019 1 H-118 50029235780000 2170840 2'4" 0.50 8.5" 5/4/2019 2 5/5/2019 1 H-119 50029235910000 2171780 1 3' 1 0.80 8" 5/4/2019 1.8 1 5/5/2019 Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 ( 907) 273-1700 main RECEIVE® FEB 0 2 2018 AOGCC (907)273-4760 fax Delivered to: .�Y{i Makana K Bender �Natt.ralReseurr_•esTechimciar. 11 _....... i;.. (;as n=.; 21 7133 29 025 � 1 -Feb -18 OtFeb18JW 03 -- DATA LOGGED 2 /\2/201$ K. BENDER Transmittal Receipt A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the Print Name X �_ package have been verified to match the media noted above. The Signature Date specific content of the CDs and/or hardco / py prints may or may Please return via courier or sign/scan and email a copy to Schlumberger and CPAI. not have been verified for correctness or quality level at this Alaska PT SPnntCentend)slh mm Tn—n,t—L......a,,._- _. point. DATA SUBMITTAL COMPLIANCE REPORT 2/6/2018 Permit to Drill 2171330 Well Name/No. KUPARUK RIV UNIT 1H-111 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23581-00-00 MD 8066 TVD 4216 Completion Date 11/5/2017 Completion Status WAGIN Current Status WAGIN UIC No REQUIRED INFORMATION Mud Log No / / V Samples✓No Directional Survey Yes v DATAINFORMATION List of Logs Obtained: Gr/Res/Den/Sonic/CBL (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 28768 Digital Data _ 2554 6558 11/2/2017 Electronic Data Set, Filename: CPAI_1H- 111_CBL_ 30Oct17_ConCu_R02_L007Up_MainP ass.las ED C 28768 Digital Data 11/2/2017 Electronic File: CPAI-1H- PAI1H-111 111CBL_300ct17_ConCu_R02_L007Up_MainP . ass.dlis ED C 28768 Digital Data 11/2/2017 Electronic File: CPAI_1H- D 1 111 C13L_30Oct17_FieldPrint.Pdf - Log C 28768 Log Header Scans 0 0 2171330 KUPARUK RIV UNIT 1H-111 LOG HEADERS ED C 28779 Digital Data 82 1865 11/9/2017 Electronic Data Set, Filename: CPAI 1H-111 VISION Semice_RM_LW0001.1as ED C 28779 Digital Data 1651 8066 11/9/2017 Electronic Data Set, Filename: CPAI 1H-111 VISION Service_ RM_LWD002.las ED C 28779 Digital Data 82 8066 11/9/2017 Electronic Data Set, Filename: CPAI 1H-111 , VISION Service RM.las ED C .28779 Digital Data 122 8066 11/9/2017 Electronic Data Set, Filename: CPAI 1H-111 - - VISION Service Customer Channel LAS.Ias ED C 28779 Digital Data 11/9/2017 Electronic File: CPAI 1H-111 VISION Service RM LWD002 DLIS.dlis ED C 28779 Digital Data 11/9/2017 Electronic File: CPAI 1H-111 VISION Service RM LWD002 OLIS.html ED C 28779 Digital Data 11/9/2017 Electronic File: CPAI 1H-111 VISION Service RM LWD001 DLIS.dlis ED C 28779 Digital Data 11/9/2017 Electronic File: CPAI 1H-111 VISION Service RM. LWD001 DLIS.html AOGCC Page I of Tuesday, February 6, 2018 DATA SUBMITTAL COMPLIANCE REPORT 21612018 Permit to Drill 2171330 Well Name/No. KUPARUK RIV UNIT iH-111 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23581-00-00 MD 8066 ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C Log C AOGCC TVD 4216 28779 Digital Data 28779 Digital Data 28779 Digital Data 28779 Digital Data 28779 Digital Data 28779 Digital Data 28779 Digital Data 28779 Digital Data 28779 Digital Data 28779 Digital Data 28779 Digital Data 28779 Digital Data 28779 Digital Data 28779 Digital Data 28779 Digital Data 28779 Digital Data 28779 Digital Data Completion Date 11/5/2017 28779 Digital Data 28779 Log Header Scans Completion Status WAGIN Current Status WAGIN UIC No 11/9/2017 Electronic File: CPAI 1H-111 VISION Service RM DLIS.dlis 11/9/2017 Electronic File: CPAI 1H-111 VISION Service RM DLIS.html P 11/9/2017 Electronic File: CPAI _1H- 111 VISION_Service_2in_MD.pdf 11/9/2017 Electronic File: CPA[ 1H- 111_VISION_Service_2[n_TVD.pdf' Electronic File: CPAI 411/9/2017 _1H- 111 _VIS ION_Service_5in_MD. pdf• 11/9/2017 Electronic File: CPAI - P _1H 111_VISION_Service_5in_TVD.pdf ; 11/9/2017 Electronic File:1H-111gyro.docx ` 11/9/2017 Electronic File: 1H-111 NAD27 EOW Compass . Survey [Canvas].txt 11/9/2017 Electronic File: 1H-111 NAD27 EOW Compass ' Survey [Macro].txt 11/9/2017 Electronic File: 1H-111 NAD27 EOW Compass - Survey [Petrel].txt 11/9/2017 Electronic File: 1H-111 NAD27 EOW Compass . Survey [Survey].txt 11/9/2017 Electronic File: 1H-111 NAD27 EOW Compass Survey.pdf 11/9/2017 Electronic File: 1H-111 NAD83 EOW Compass , Survey [Canvas].txt 11/9/2017 Electronic File: 1H-111 NAD83 EOW Compass ` Survey [Macro].txt 11/9/2017 Electronic File: 1H-111 NAD83 EOW Compass. , Survey [Petrel].txt 11/9/2017 Electronic File: 1 H-111 NAD83 EOW Compass• Survey [Survey].txt 11/9/2017 Electronic File: 1H-111 NAD83 EOW Compass Survey.pdf 11/9/2017 Electronic File: CPAI_11-1-111_Surveyl-ist.csv - 0 0 2171330 KUPARUK RIV UNIT 1H-111 LOG HEADERS Page 2 of 4 Tuesday, February 6, 2018 DATA SUBMITTAL COMPLIANCE REPORT 21612018 Permit to Drill 2171330 Well Name/No. KUPARUK RIV UNIT 1H-111 MD 8066 TVD 4216 Completion Date 11/5/2017 ED C 28798 Digital Data ED C 28798 Digital Data ED C 28798 Digital Data ED C 28798 Digital Data ED C 28798 Digital Data Log C 28798 Log Header Scans ED C 28858 Digital Data ED C 28858 Digital Data ED C 28858 Digital Data ED C 28858 Digital Data ED C 28858 Digital Data Log C 28858 Log Header Scans Well Cores/Samples Information: Name Interval Start Stop Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23581-00-00 Completion Status WAGIN Current Status WAGIN UIC No 6946 7314 11/17/2017 Electronic Data Set, Filename: CPAI_1H- 111 Correlation_04Novl7_ConCu_RO6_LO02Up_ - Main.las 6949 7305 11/17/2017 Electronic Data Set, Filename: CPAI_1H- 111_Correlation_04N007_ConCu_R06_LOO6Up_, Repeat.las 11/17/2017 Electronic File: CPAI_IH- Ill _Correlation_04Novl 7_ ConCu_RO6_L002Up_. MainAlis 11/17/2017 Electronic File: CPAI_1H- 111_Correlation_04Novl7_ConCu_R06_L006Up_ . Repeat.dlis 11/17/2017 Electronic File: CPAI_1H- 111_Correlation_04Novl7_FieldPrint.Pdf ` 0 0 2171330 KUPARUK RIV UNIT 1H-111 LOG HEADERS 2508 7877 12/13/2017 Electronic Data Set, Filename: CPAf_1 H- 11 USIT_DSLT_01Novl7_ConCu_R03_L010Up_ ` MainPass.las 2470 2748 12/13/2017 Electronic Data Set, Filename: CPAI_1 H- 11_USIT_DSLT_01Novl7_ConCu_R03_L012Up_, RepeatPass.las 12/13/2017 Electronic File: CPAI1H- 11 USIT_ OSLT_Olt_ovl7_ConCu_R03_L010Up_. MainPass.dlis 12/13/2017 Electronic File: CPAI_1 H- 11_USIT_DSLT_O1Novl7_ConCu_R03_L012Up_ , RepeatPass.dlis 12/13/2017 Electronic File: CPAI_1 H- Q 111_USIT_DSLT_O1Novl7_FINAL.Pdf 0 0 2171330 KUPARUK RIV UNIT 1H-111 LOG HEADERS Sample Set Sent Received Number Comments %()t,( l Page 3 of Tuesday, February 6, 2018 DATA SUBMITTAL COMPLIANCE REPORT 2/6/2018 Permit to Drill 2171330 Well Name/No. KUPARUK RIV UNIT 1H-111 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029.23581-00-00 MD 8066 TVD 4216 INFORMATION RECEIVED Completion Report 0 Production Test Information Y / N� Geologic Markers/Tops YO COMPLIANCE HISTORY Completion Date: 11/5/2017 Release Date: 10/17/2017 Description Comments: Completion Date 11/5/2017 Completion Status WAGIN Current Status WAGIN UIC No p, Directional / Inclination Data D Mud Logs, Image Files, Digital Data Y /® Core Chips Y/ IA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Core Photographs Y/40 Daily Operations Summary O Cuttings Samples Y /® Laboratory Analyses Y M6 Date Comments Compliance Reviewed By: "'_ Date: 1 w ( v A0G t Page 4,,1'4 Tuesday. Pebmary 6. 2019 Originated: RECEIVED Schlumberger PTS - PRINT CENTER DEC 13 2017 6411 A Street Anchorage, AK 99518 AOGCC (907) 273-1700 main (907)273-4760 fax Delivered to: ryMakanaK Bender Natural Resources Technician II Alaska Oil & Gas Conservation Commission 1 333 W. 7' Ave, Suite 100 Anchorage. AK 995o 1 21 7133 TRANSMITTAL DATE TRANSMITTAL# -� DATA LOGGED v2 A3i2ot-T M. K. BENDER SERVICE ORDER WELL NAME API # It SERVICE FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED Color Prints CD's 50-029-21576-00 nsmittal Receipt 22 Name Signature Date e send signed transmittal to CPAI via email or post. Alaska Inc. A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Auditor - MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg2�DATE: 1�1 Thursday, December 07, 2017 P.I. Supervisor I` y u117 SUBJECT: Mechanical Integrity Tests 1 CONOCOPHILLIPS ALASKA, INC. IH -III FROM: Guy Cook KUPARUK RIV UNIT IH -1I I Petroleum Inspector Ste: Inspector Reviewed By: P.I. Suprv� 5p— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1H -1I I IInsp Num: mitGDC171205173007 Rel Insp Num: API Well Number 50-029-23581-00-00 Inspector Name: Guy cook Permit Number: 217-133-0 Inspection Date: 12/5/2017 Packer Depth Well IH -Iii TypelnjFSWPT TVD 3724 PTD 2171330 Type TestNestpsi 1500 BBL Pumped: 13 � IBBL Returned: Interval — _— INITAL �p/F P - _. I—_ Notes: Little Red Services pump truck used for testing. Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 0119 IWO WS 1011-1 IA 2190 ?C00 1980 11961 OA i00 100 10C 100 Thursday, December 07, 2017 Page 1 of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development❑ Exploratory El GINJ ❑ WINJ ❑ WAGO- 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.: 11/5/2017 _ 217-133 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 10/21/2017 50-029-23581-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 169' FSL, 778' FEL, Sec 28, T12N, R10E, UM 10/27/2017 KRU IH -111 Top of Productive Interval: 9. Ref Elevations: KB:92.72 17. Field / Pool(s): 312' FSL, 709' FEL, Sec 27, T12N, R103, UM GL: 54.10 BF: Kuparuk River Field/West Sak Oil Pool . Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 368' FSL, 67' FEL, Sec 27, T12N, RI OE, UM N/A ADL 25639 , 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 549562.21 y- 5980872.05 Zone- 4 8066/4216 , 80-261 TPI: x- 554909 y- 5981053 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MDTTVD. Total Depth: x- 555551 y- 5981113 Zone- 4 N/A 1699/1639 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) I N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary RECEIVED G R/Res/Den/Son is/CBL DEC 0 5 201 AOGCC 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 94 H-40 39 118 39 118 42 Existing cement TO surface 103/4 45.5 L-80 41 1857 41 1775 13 1/2e1 �. sx 11.0 ppg Class ALC, q sx 15.8 Ppg Class G 7 26 L-80 38 8056 38 4211 83/4 VTy 678 sx 15.8 ppg Class G 24. Open to production or injection? Yes ❑Z No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/iVD) Size and Number; Date Perfd): 31/2 1 7823 7211/3723, 7374/3813 PERFORATIONS @: COMPLETION 7276 - 7356 MD and 3758 - 3803 TVD 7408.7467 MD and 3832 - 3867 TVD DAT 7497 - 7524 MD and 3884 - 3900 TVD ___II_�_ 7619 - 7636 MD and 3955 - 3965 TVD VERIFIED 7481/3875 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7690 - 7721 MD and 3996 - 4014 TVD Lt 7735 - 7769 MD and 4022 - 4042 TVD 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): INJECTION ONLY - NOT PRE -PRODUCED Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casino Press: I Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate Form 10-407 Revised 5 2017 VTL NTINUED ON PAGE 2 REIM°AS DLL O 6 ZO17 Submit ORIGINIAL on[ 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No ❑+ If Yes, list formations and intervals cored (MDff VD, 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 ❑Q Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Permafrost - Base 1699 1639 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7275 3761 information, including reports, per 20 AAC 25.071. Formation @ TPI - W SAK D UGNU 5233 3048 WEST SAK SAND 7275 3761 TD 8066 4216 Formation at total depth: W SAK BASE ' 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloalcal report, production orwell 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: G. L. ALVORD Contact Name: Ben Tolman bi Authorized Title: Alaska Drilling Manager Contact Email: ben.v.tolman co .com Authorized / Contact Phone: 265-6828 r�' Signature: ,'C-.�,.� Date: 'S� INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item Is: 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 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only -= Wellhead/Tubing Hanger/Tree, 3-3/8"1H-111 NEWS Injector 1x 4-'G" IBTM. SM (Post Rig) Insulated Canduemr' Cr verbelow TH: 4-12"x3-12"Tubing 20" Casing 3 ln'%934,1. BII,EU&AB 10-14"45.54,1.80 �4 HYD563 a: 18566 R MDJ Surface Cuing Tags 3-I/2"MMGw.&SOVRAMP ®3009;&7,013-MD FormaUpA Tops 5 Base at Permahas1: 1,699 MD 11639WD p Feed Through Packer 43 (Baker): RI VMD Ugnu Top: 5,233 MO/ 3,048' TVD 4 Gauge Mandrel: 7225'MD "D" Sand Pertomdane: 7276'-7356'MO NSanda: 6.798'Me/3,564'TVO 2612" Camra DS Nipple: 724,1-MDWesl Bak Dr ],2]5'MD/3,]fii'ND Upper MMGW: 7251'MD West Bak B: 7,407' MD 13,835' WD Loxrs MMGW: 7291 'MD West Bak A: 7,473' Me l3,]]4' WD Feed Through Pxka 42 (Baker): 7374'MD "8" Used Pertoraliana: 7408'-7467'MO Gauge Mandrel: T386MD Upper MMGW:]402402'MD Lowv MMGW: 7dd2'MD Fad Through Packer#1(Baker): 7482'MD A4 pedsO497'452CMD Gsuge Mandrel: ]d96'MD A3 pergs:]6IT-7636'MO 2813" Cameo% Nipple:]514'MD A2 parts: 7690'-7769'MD UppsrMMGW: 752VMD Lown MMGW:7562'MD T' 264, 4W, HYD563?1.P Baker WIV:]e 12'MD (6.216' ID, 6.151" DRIFT) ®8056.9' MD ScrapenMagndA _1:7814'MD 3a g9 Dumb bon muluhoe:]921'MD TDQ 6,066' MD 14.2a8' TVD v KUP INJ 1H-111 ConocI3 h111ips " , weu n=, L We z Mgl IG To Afasba.IhC, VNIIMae apwan l'im.f ms. "mmereslatn, iml-t MDpmnl AmaNniume1 None I I lLaStWO' Anmbaon Tag; Oegn111NB1 Entl Dah emanationslaslM%BY Rev Reason NEW WELL, GLV GO INSTALLED WFR in ManOrel M3,N5,#J) PProven MONa 12/5-/201] RalGea, Le a_ _.,, _ sin ng nnge casing UCTO lion pp pnl 1plinl Tap (FK 0)set Oeptn (n ll set Oepnlrv0l... wvLen 6-. GmEe Top rnreaa CONDUCTOR 20 19.200 39.0 118D 118.0 )8.6Cau7 B SURFOescrlp4on ODlip mlln) Tap lnK4 ael0epf111XKB1 Set Oapin (NDL.. Wvten Q... GeNe TOp Tllmtl SURFACE 10 W4 9.950 40.6 1,856.fi 17753 4550 L-80 Hytl 563 Caslna MM76on Oplin)IO PnI Top IXKBI—'Oepin nll(BI Bet Oepin lNDl... WtlLen 11... Grata TOP Threat PRODUCTION ] 6.276 376 8,056.3 4,210.6 26.00 L-80 TXP BTC mhaa De:<npmn TUBING smnp Ma... Ip Onl Toa INKB) see pepin (X. sa Oean Irvo16.. wl pwp Grme mp eonneceion 312 2.992 33.0 ],822.] 4,0]3 J 930 L-80 EUE-m Completion Details Tep (SiTopITyD11XKB Top Incl (') IIeT Des Co. Nominal lDlint CONDUCTOR; at tai 330 33.0 0.00 HANGER Now 4-112"Tubing M1anger 5,750 7,210.8 3,723.5 58.59 PACKER Baker Feed Through Packer p3 2,940 ( Assy r10) 7,225.1 3,731.0 58.09 GUAGE SGM 83, (C15GM-0738) singte gauge, Torme a pressure 2913 BURFaCE:0.6-1.1gage 7,243.6 3,740.9 57.45 - 1PPl Cam. 2.813 D5 nipple EUE 8rbMotl (Sr 3651-180) 2.813 ( Ass, p9) 7,373.6 3,812.8 55.35 PACKER Baker Feetl Through Packer r2 2950 ( May Y7) CAP LIFT; 26x.6 7,386.0 3,8199 55.13 GUAGE BEN #2 EUE 8rbMOd,(Cl %M-91"uki drop gauge, 2.913 annulus pressure 7,4815 3,8752 So 42 PACKER Baker feed through Packer 41 2,960 (Assy 44) 7,4958 3,883.6 54.46 GUAGE SGM a 1 EUE Brol (C15GM4]26) single gauge, 2.913 annulus Pressure 7,513.8 3,896.0 %50 NIPPLE Camm 2.813"X nipple@ 7497'MD(28131(Sr C- 2813 3562597) ],8120 4,0674 53.94 WIV 312"Baker WIVEUE-MOD two PACKER; 7,,2108 7,816.4 4,068.9 53.95 Casing Baker Trailbawnr CSG scrapper I brush )Mag Combo 2.150 Suacer (Assykl) G.E. 7,2M1 7,820) 4,072.6 5396 Mule SM1oe 312" MuleshcewbingtuI 2.990 NIPPLE: 7.x3.5 Perrorations & Slob Ban GAS LIFT. 7,2500 Topless) OW go(B)MB) TOP Orion atm mD)D=na MKB) Lw a W4 (=hr mrose c0m 7,2780 7,356.0 3,7584 3,802.8 WS D, 1H- 112209 601PERFRF pas UFT', 7,291.1 111 7,4080 7,467,0 3,832.5 3,886.8 WSB, 111- 114MM17 6.0 IPERF -/PERE] M07,3560— 111 7,6970 7,524.0 3,884.33,899.9 WS A4, 1H- 1122017 601PERF 111 PACKER; ja74.a 7.619.0 7,6360 3,955.0 3,9849 WS A3,1H- 111212017 6.0 IPERF 111 Gual 7 M 7,690.0 7,7210 3,996.2 4,014.2 WS A2, 11+ 1122017 So IPERF ll un 7,401 a ),]35.0 ],]69.0 4,022.4 4,0622 WS A2, 1H- 111 11-/272017 6.0 PERFGAa IPERF:1L09a7497.0� Mandrel Inserts GAsuFT,r.0 aL as PACeER74ats H Top MKS) TOP Yang Valve latch PDX8Ue TRO Run (Intel Maks, M,M00 (in) Sam Type Type g1q (Pail Run Oaks COM 1 2,5289 2,234.7 Camco MMGW 5968 GAS LIFT DMY RK 11rz22017 2 7,2509 3,744.8 Carom MMGW 5908 GAS LIFT MY RK 1114201] waGE:44Bs.e 3 7,291.1 37667 GamCO MMGW 5968 GAS LIFT GLV RK 0.297 11rz4rz017 WR IPERF:IPPLE, ,5a,0�� NIPPLE; 7,S1Aa 4 7,401.6 3,8288 Camw MMGW 5968 GAS LIFT DMY RK 11/42017 5 7,4420 3,8522 Carom MMGW 5968 GAS LIFT GLV RK I 0.297 11242017 WFR GAS.Fr:75a6 I 6 7, 16 3,898.5 Camco MMGW, 5.968 GAS LIFT DMY RK 1 142017 pas LIFT: 7.. 7 ],562.1 3,922.0 Carom MMGW, 5.968 GAS LIFT GLV RK 029] 1124201] WFR Notes: General & Safety PERF', 7,618.0-7.PI Ens pas Amromion 12752017 Nor, IPERF:7,®DLLIr MIA IPERF: ].M D7.MO. PRO0.11014; 3],69,0'4,3 Operations Summary (with Timelog Depths) 1H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End lime Our hr our(hr Phase Op Catle Activity Cale Time P -T -X Operation Start Depth (flK8) End OSPm (aKB). 10/20/2017 10/21/2017 8.00 MIRU MOVE MOB P Move rig from 1H-102 to 1H-111 0.0 0.0 16:00 00:00 10/21/2017 10/21/2017 8.00 MIRU MOVE MOB P Moving rig and spotting up over 1H- 0.0 0.0 00:00 08:00 111 10/21/2017 10/21/2017 2.75 MIRU MOVE RURD P Continue riging up perfial equipment. 0.0 0.0 08:00 10:45 RU surface pitchin nip. take RKB measurements. Install riser and mousehole. Load pipeshed with 5" HWDP and DP. Rig accepted at 0800 hrs. 10/21/2017 10/21/2017 1.25 MIRU MOVE RURD P MU and RIH with on estand of pipe to 0.0 0.0 10:45 12:00 tag bottom of conductor. Install casing valves. 10/21/2017 10/21/2017 1.00 MIRU MOVE BOPE P Perform diverter test. Closing times = 0.0 0.0 12:00 13:00 knife vale= 5 sec, Ann = 22 sec, DD test - ACC = 3,025 PSI. Man 1,375 PSI. After function ACC = 2,050 PSI. Man 1,350 PSI, 200 PSI build with 2 Elect pumps = 8 sec. Full system press = 37 sec. 6 bottle Avg = 2,208 PSI. Test witness waived by AOGCC Jeff Jones. 10/21/2017 10/21/2017 1.00 MIRU MOVE BHAH P LD stand of DP and bring BHA 0.0 0.0 13:00 14:00 sections to rig floor. 10/21/2017 10/21/2017 1.00 MIRU MOVE SFTY P Pre -spud with operations and drilling 0.0 0.0 14:00 15:00 reps. 10/21/2017 10/21/2017 1.25 MIRU MOVE BHAH P MU 13 1/2" surface hole cleanout 0.0 74.0 15:00 16:15 BHA. to 74' as per DD. 10/21/2017 10/21/2017 0.75 MIRU MOVE SEQP P Fill conductor and check for leaks. PU 74.0 74.0 16:15 17:00 surface equipment to 3,000 PSI. 10/21/2017 10/21/2017 1.00 SURFAC DRILL DDRL P Drill 13 1/2" surface hole from 74' MD 74.0 132.0 17:00 18:00 to 132' MD. @ 450 GPM, 420 PSI, 30% F/O, 40 RPM. 1-2K TQ with 51K WOB. OB = 365 PSI, UP WT = 52K, DWN WT = 57K, ROT = 55K. 1 K TO. 10/21/2017 10/21/2017 2.25 SURFAC DRILL DDRL P Continue to diril from 132' MD to 200' 132.0 200.0 18:00 20:15 MD. - 200' TVD. with 450 GPM 615 PSI DPP, 32% FIC, @ 40 RPM. 1-21K TQ. 61K WT off BTM. 1021/2017 10/21/2017 2.25 SURFAC DRILL BHAH P RIB two stands HWDP & MU BHA#1 200.0 200.0 20:15 22:30 to 190' as per DD. 10/21/2017 10/22/2017 1.50 SURFAC DRILL DDRL P Drill 131/2" surface hole from 200' to 200.0 280.0 22:30 00:00 280' MD 280' TVD with 462 GPM, 652 PSI DPP, 43% F/O 10/22/2017 10/222017 6.00 SURFAC DRILL DDRL P Drill 13-1/2" Surface hole F/280' MD - 280.0 684.0 00:00 06:00 T/684' MD (684' TVD). Pump rate 500 GPM, 1,020 psi. Flo out 40% 60 rpm, 31K torque, 25K bit wt. P/U 81 k S/O 89k Rot wt.82k..5k toque off bottom. Off bottom pump pressure 820 psi. AST= 1.55 ART= 1.67 ADT= 3.22. Total bit hrs = 5.22, Total jar hrs. _ 108.54 Page 1/23 ReportPrinted: 1 112 812 01 7 ,- - Operations Summary (with Timelog Depths) r 1H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Sreq Tmw End lune bur(W Phase op code Activity Code Trme P -T -X Operation (ftKB) EM Depth MKB) 10/22/2017 10/22/2017 6.00 SURFAC DRILL DDRL P Drill 13-1/2" Surface hole F/684' MD - 684.0 1,252.0 0600 12:00 T/1,240' MD (1,240' TVD). Pump rate 525 GPM, 1,285 psi. Flo out 33%60 rpm, 6K torque, 28K bit wt. P/U 95k SIO 99k Rot wt.93k. 1 k toque off bottom. Off bottom pump pressure 1030 psi. AST= 2.91 ART= 3.02 ADT= 5.93. Total bit hm,= 11.15, Total jar hrs. 114.47 10/22/2017 10/22/2017 6.00 SURFAC DRILL DDRL P Drill 13-1/2" Surface hole 1,240' MO 1,252.0 1,865.0 12:00 18:00 (1,240' TVD) to 1,865' MD 1,783' TVD, . Pump rate 500 GPM, 1,310 psi. Flo out 31% 60 rpm, 4K torque, 28K bit UP WT= 110k DWN WT= 1051k Rot wt. 104k. 2k toque off bottom. Off bottom pump pressure 1090 psi. AST= 2.11 ART= 1.82 ADT= 3.93. Total bit hrs.= 13.08, Total jar hrs. _ 116.4 10/22/2017 10/22/2017 0.50 SURFAC CASING CIRC P Circulate bottoms up while recip from 1,865.0 1,824.0 18:00 18:30 1,865'MD-1,824'MD. UP WT= 109K, DWN WT= 108K, Rol= 108K. 2-3K TQ. 10/22/2017 10/2212017 0.50 SURFAC CASING OWFF P OWFF / some gas breaking out. 1,824.0 1,824.0 18:30 19:00 10/22/2017 10/22/2017 2.50 SURFAC CASING BKRM P BKRM OOH from 1,824' MD to 780' 1,824.0 780.0 19:00 21:30 MO. 525 GPM @ 890 PSI DPP. 33% F/O, 60 RPM, 2-3K TQ, UP WT = 87K, DWN wT = 93K. monitor disp via pit 1 -5. 10/22/2017 10/22/2017 0.50 SURFAC CASING PMPO P Pump two stands out from 780' MD - 780.0 592.0 21:30 22:00 592' MD. 525 GPM @ 890 PSI. 33% F/O, 60 RPM, 1K TO. UP WT=81 K, DWN WT=89K. 10/22/2017 10/22/2017 0.25 SURFAC CASING RURD P BD top drive 592.0 592.0 22:00 22:15 10/22/2017 10/23/2017 1.75 SURFAC CASING BHAH P LD BHA #1 from 592' MD - 69' MD. 592.0 69.0 22:15 00:00 Monitor disp via Pits 1-5. 10/2312017 10/23/2017 1.00 SURFAC CASING BHAH P Continue to lay down BHA from 69' to 69.0 0.0 00:00 01:00 surface. Monitor well via pits 1-5. 10/23/2017 10/23/2017 0.75 SURFAC CASING BHAH P Wash mud and such from rig floor. 0.0 0.0 01:00 01:45 Clear rig floor. 10/23/2017 10/23/2017 1.25 SURFAC CASING RURD P Rig up casing running equpment and 0.0 0.0 01:45 03:00 tesat same. Volant, spiders and bail extensions + elevators. 10/23/2017 10/23/2017 1.00 SURFAC CASING PUTS P Pick up 10 3/4" 45.5# L-80 563 Casing 0.0 167.0 03:00 04:00 and begin to RIH to 167' MD. Baker Lock connections below float collar and TQ all connections to 19.5K FT/LB. Pump on joint 4 with 8 BPM 24% F/O, 6 BPM @ 19% F/O, 4 BPM @ 16% F/O and 2 BPM @ 13% F/O. Floats tested (GOOD). 10/23/2017 10/23/2017 4.75 SURFAC CASING PUTB P Continue to RIH with casing from 167' 167.0 1,812.0 04:00 08:45 to 1,812' MD. TQ all connections to 19.4 FT/LBS. Fill on fly every ten. Monitor disp via pits 1-5. DWN WT= 93K. UP WT 117K. 10/23/2017 10123/2017 0.50 SURFAC CASING HOSO P Make up 10 3/4" hanger landing joint. 1,812.0 1,812.0 08:45 09:15 Page 2123 ReportPrinted: 11128120171 - Operations Summary (with Timelog Uepths) IH -111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Star Time End Time our (hr) Phase Op Code Activity Code Time P -T-% operation (ftKB) End Depth (flKa) 10/23/2017 10/23/2017 1.25 SURFAC CEMENT CIRC P Circulate and condition mud while 1,812.0 1,856.0 0915 10:30 reciprocating from 1,856' MD to 1,836' MD staging pumps up to 7 BPM 100 PSI, 21% F/O, UP WT = 117K, OWN WT = 110K. 10/23/2017 10/23/2017 0.50 SURFAC CEMENT RURD P RU cement line. 1,856.0 1,856.0 10:30 11:00 10/23/2017 10/23/2017 1.50 SURFAC CEMENT CIRC P Continue to circulate while recip pipe 1,856.0 1,856.0 11:00 12:30 and pump 70 BBL Spill weighted RED DYE marker gauge pill @ 8 BPM, 270 PSI, 22% F/O. Calculated STKS = 2,965 Actual STKS = 3,900. FCP @ 8 BPM = 270 PSI, 22% F/O, UP WT = 120, DWN WT = 114. 10/23/2017 10/2312017 0.75 SURFAC CEMENT SFTY P PJSM with all hands and 1,856.0 1,856.0 12:30 13:15 SLB /ASRC/PEAK for cement program. 10/23/2017 10/23/2017 3.25 SURFAC CEMENT CMNT P Cementers on line with 5 BBLS CW 1,856.0 1,856.0 13:15 16:30 100, PT and chart all surface lines to 4K PSI. PUmp remaining 35 BBL of CW 100 @ 5 BPM 180 PSI 14% F/0, f/40.1 BBLS total. Chase with 76 BBLS of 10.5# using MP #2 @ 4 BPM 200 PSI. 13% F/O. Drop bottom plug chase with 322.5 BBLS 11# LEad cement @ 6 BPM, FCP = 130 PSI, 17% F/O, land casing with cement at shoe. UP WT= 122K, DWN WT= 114K. Pmp 61 BBLS 15.8# Tail cement @ 5.8 BPM 210 PSI with 21% FIC. Drop top plug with 10 BBLS water, swap to rig pump and displace cement at 6.7 BPM. for 1500 STKS. FCP = 560 PSI with 20% F/O. reduce to 3 BPM FCP = 400 PSI, 13% FIC. Bump plug at 1,592 STKS, increase pressure to 930 PSI and hold for 5 min. Bleed Pressure and check floats (GOOD). Cement in place at 16:16. 97 BBLS cement returned to surface. 10/232017 10/23/2017 2.50 SURFAC CEMENT RURD P RD and BD all surface lines. RD 1,856.0 1,856.0 16:30 19:00 10/34" handling equipment, drain and flush stack / flow lines. Clean pits and trough. Pull and LD landing joint. Blowd down topddve & clean out cement manifold. At 1720 10 BBLS spill via diverter line to pad occurred. All notifications made. 10/232017 10/232017 3.00 SURFAC CEMENT NUND P Pull off diveder system. 1,856.0 1,856.0 19:00 22:00 101232017 10/2412017 2.00 SURFAC WHDBOP NUND P Clean wellhead, install seal sub, and 1,856.0 1,856.0 22:00 00:00 hold down flange. NU Vetco Gray wellhead per GE & align to punch marks on conductor. Test seal sub to 1800 psi for 15 min witnessed by CPAI rep. Find TOC @ 4" outlet valves, cap valves. Page 3123 Report Printed: 1112912017 Operations Summary (with Timelog Depths) IH -111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log stare Depth Start Time EM Time Dur (hr) Phase Op Code Acli,,ity Code Time P -T -x Operation (ftKB) EM Depth (ftKB) 10/24/2017 10/24/2017 4.50 SURFAC WHDBOP NUND P NU BOPE, install high pressure riser 0.0 0.0 00:00 04:30 and BOPE stack. NU pitcher nipple and low pressure riser. MU choke and kill lines. Install 1502 unions on IA/OA/tubing flanges. 10/24/2017 10/24/2017 1.25 SURFAC WHDBOP RURD P RU test equipment and MU floor 0.0 0.0 04:30 05:45 valves. PU 7" test joint and set lower test plug. Flood stack with H2O and Perform shell test to 3500 psi. 10/24/2017 10/24/2017 7.25 SURFAC WHDBOP BOPE P Test BOPE. All tests to 250/3500 psi 0.0 0.0 05:45 13:00 for 5/5 minutes, charted, with exception of super and manually operated choke to 250/2000 psi for 5/5 minutes, charted. Test annular, 7" upper rams, choke valves #1, 6, 7, 8, 9, 10, 11, 12, 13, & 14, 4" kill, mezzanine kill, HCR & manual kill valves, 4" dart & FOSV, 5" dart & FOSV, blind rams and choke valves #2 & 5 with 7" test joint. Test annular, 3-1/2" x 6" lower rams, upper and lower IBOP with 3-1/2" test joint. Test annular, 3-1/2" x 6" lower rams, HCR & manual choke valves with 5" lest joint. Perform accumulator drawdown test. Initial pressures, accumulator = 3000 psi, manifold = 1600 psi. After function, accumulator = 1825 psi, manifold= 1475 psi, 200 psi build with 2 electric pumps = 13 seconds, full system pressure with electric and air pumps = 52 seconds, 6 bottle back up N2 average = 2216 psi. Tested all 1-12S and gas sensors, PVT and flow alarms both audio and visual, and functioned primary and remote BOP controls — all good. Test witness waived by AOGCC Rep Jeff Jones Q 03:00 10/24/17. 10/24/2017 10/24/2017 1.25 SURFAC WHDBOP RURD P RD & blow down test equipment. Pull 0.0 0.0 13:00 14:15 test plug and drain stack. MU running tool to 5" test joint and set wear bushing, RILDS, & LD 5" test joint. 10/24/2017 10/24/2017 2.50 SURFAC CEMENT BHAH P PJSM. MU 8-3/4" Production Drilling 0.0 400.0 14:15 16:45 BHA #3 with Smith MDi616 PDC bit nozzled with 6 x 16's per SLB Directional Driller. Load RA source in EcoScope. Monitor displacement vai pit #1. PUW 67k, SOW 77k 10/24/2017 10/24/2017 0.50 SURFAC CEMENT TRIP P RIH w/ BHA #3 on 5" DP stands from 400.0 1,442.0 16:45 17:15 derrick to 1,442' MD. PUW 90k, SOW 88k. 10/24/2017 10/24/2017 0.75 SURFAC CEMENT DHEQ P Break circulation and perform shallow 1,442.0 1,442.0 17:15 18:00 hole test on MWD @ 550 gpm, 875 psi, 30% flow out. 10/24/2017 10/24/2017 0.50 SURFAC CEMENT CIRC P RIH to 1,625' MD and CBU @ 588 1,442.0 1,625.0 18:00 18:30 gpm, 1000 psi, 31 % flow out, MW in & out 9.6 ppg. PUW 96k, SOW 93k, ROT 94k. Page 4123 Report Printed: 1112 812 01 7 e Operations Summary (with Timelog Depths) IH -111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Ttme our(hr) Phase Op Code naroity Code Time P -T -X Operation start Depth (RKB) End OepM(XKB) 10/24/2017 10/24/2017 1.25 SURFAC CEMENT PRTS P Rig up and pressure test 10-3/4" 1,625.0 1.625.0 18:30 19:45 surface casing to 3,000 psi for 30 min, charted. Blow down and rig down test equipment. 10/24/2017 10/2412017 4.00 SURFAC CEMENT DRLG P Wash down and tag cement @ 1,625.0 1,770.0 19:45 23:45 1758.5' MD. Drill out cement & plugs to 1,770' MD with 550 gpm, 880 psi, 30% flow out, 75 rpm, 1-7k torque, 10- 19k WOB. Top of plugs @ 1769.5' MD. PUW 99k, SOW 96k. SPRs 1723' MD, MW = 9.6 ppg, 20:22 hours MP#1: 30 spm = 50 psi, 40 spm = 80 psi. MP #2: 30 spm = 50 psi, 40 spm = 80 psi. 10/24/2017 10/25/2017 0.25 SURFAC CEMENT SVRG P Service topdrivve, change out IBOP 1,770.0 1,770.0 2345 00:00 actuator ram. - 10/25/2017 10/25/2017 0.25 SURFAC CEMENT SVRG P Continue to service topdrive and 1,770.0 1,770.6- 00:00 00:15 change out IBOP actuator ram. 10/25/2017 10/25/2017 2.75 SURFAC CEMENT DRLG P Continue to drill out shoe track from 1,770.0 1,865.0 00:15 03:00 1,770' MD to 1,865' MD with 600 gpm, 1080 psi, 5k WOB, 80 rpm, 3-8k torque. Top of shoe seen Q 1855.4' MD and bottom at 1856.6' MD 10/25/2017 10/25/2017 0.25 SURFAC CEMENT DDRL P Drill 20' of new hole from 1,865' MD to 1,865.0 1,885.0 03:00 03:15 1,885' MD with 500 gpm, 690 psi, 29% flow out, 80 rpm, 1-5k torque, Sk WOB. ADT = 0.2 hrs, Bit = 0.2 hrs, Jars = 0.2 hrs. 10/25/2017 10/25/2017 0.75 SURFAC CEMENT CIRC P Circulate with rotation and 1,885.0 1,885.0 03:15 04:00 reciprocation from 1,885' MD to 1,825' MD with 600 gpm, 950 psi, 31 % flow out, 40 rpm, 2k torque. Total strokes pumped = 4100 and MW in & out = 9.2 ppg. PUW = 102k, SOW = 97k. 10/25/2017 10/25/2017 1.75 SURFAC CEMENT LOT P Line up to pump down drill pipe and 1,885.0 1,885.0 04:00 05:45 annulus, Gose bag, and use mud pump #2. Perform LOT to 12.2 ppg EMW with 9.2 ppg spud mud @ 1,782' TVD. Pressure up to 350 psi in 7 strokes. Pressure bled off to 140 psi in 10 minutes. 0.7 bbls bled back. RD and blow down test equipment. 10/25/2017 10252017 6.25 PROD1 DRILL DDRL P Directionally drill 8-3/4" production 1,885.0 2,404.0 05:45 12:00 hole from 1,885' MD to 2,404' MD I 2,169' TVD @ 600 gpm, 830 psi, 31% flow out, 10.22 ppg ECD, 140 rpm, 2- 4k torque, 6k WOB, off bottom 820 psi, PUW 105k, SOW 99k, ROT 101 k, 2.6k torque. Max gas of 163 units. ADT = 4.03 hrs, Bit = 4.23 hrs, Jar = 4.23 hrs. SPRs @ 2,007' MD 11,909' TVD, MW = 9.0 ppg, 07:15 hrs MP#1: 30 spm = 100 psi, 40 spm = 120 psi. MP#2: 30 spm = 100 psi, 40 spm = 120 psi. Page 5123 ReportPrinted: 1112 812 01 7 Operations Summary (with Timelog Depths) r 1H-111 NW Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tim Ed Time Dur(hr) Phase Op Code A imy Code Time P -T -X openison (M(B) EW Depto(WB) 10/25/2017 10/25/2017 6.00 PROD1 DRILL DDRL P Directionally drill 8-3/4" production 2,404.0 2,983.0 12:00 18:00 hole from 2,404' MD to 2,983' MD / 2,409' TVD @ 700 gpm, 1115 psi, 32% flow out, 10.22 ppg ECD, 120- 160 rpm, 3-8k torque, 3k WOB, off bottom 1080 psi, PUW 108k, SOW 91 k, ROT 100k, 5k torque. Max gas of 46 units. Pump 30 bbl weighted sweeps with 5 ppb nut plug medium every 400' MD. Increase Lotorq from 0% to 1 % to help with erratic torque. ADT = 3.82 hrs, Bit = 8.05 hrs, Jar = 8.05 hrs. 10/25/2017 10125/2017 3.50 PRODt DRILL DDRL P Directionally drill 8-3/4" production 2,983.0 3,351.0 18:00 21:30 hole from 2,983' MD to 3,351' MD / 2,518' TVD @ 700 gpm, 1265 psi, 34% flow out, 10.25 ppg ECD, 110- 180 rpm, 3-8k torque, 5k WOB, off bottom 1260 psi, PUW 106k, SOW 95k, ROT 102k, 4k torque. Max gas of 32 units. ADT = 2.39 hrs. Observe minor pack offs from 3,292' MD to 3,351' MD with 250 psi increase in pump pressure and spike in ECD. Attempt to drill ahead, but observe high WOB with diminishing ROP. Pump 30 bbl weighted sweeps with 5 ppb nut plug medium every 400' MD, seeing 20-30% increase in cuttings and mainly clay. SPRs @ 3,048' MD / 2,428' TVD, MW = 9.1 ppg. 18:26 hrs MP#1: 30 spm = 120 psi, 40 spm = 140 psi. MP#2: 30 spm = 100 psi, 40 spm = 140 psi. 10/25/2017 10/25/2017 1.00 PRODt DRILL CIRC T Rack back 1 stand of drill pipe and 3,351.0 3,351.0 21:30 22:30 circulate 35 bbl 4% Drillzone pill with reciprocation and rotation from 3,280' MD to 3,236' MD @ 744 gpm, 1210 psi, 34% flow out, 180 rpm, 4k torque to help with possible bit balling/low ROP. 10/25/2017 10/26/2017 1.50 PROD1 DRILL DDRL P Directionally drill 8-3/4" production 3,351.0 3,428.0 22:30 00:00 hole from 3,351' MD to 3,428' MD / 2,541' TVD @ 750 gpm, 1250 psi, 34% flow out, 10.22 ppg ECD, staging up rpm from 80 to 180 rpm, 5k torque, 5k WOB, off bottom 1250 psi, PUW 114k, SOW 92k, ROT 102k, 4.5k torque. Max gas of 35 units. Observe on gamma and resistivity logs coal stringers @ 3,315' MD, 3,337' MD, 8 3,361' MD along with small coal cuttings across shakers probably cause to reduction in ROP. ADT = 0.83 hrs, Bit = 11.27 hrs, Jar = 11.27 hrs. Page 6123 Report Printed: 11 /2812 01 7 Operations Summary (with Timelog Depths) 1H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time Our (hr) Phase Op Code Adivity Code Time P -T -X Operation scan oeptn (WS) End 0eptn (ftKB) 10/26/2017 10/26/2017 6.00 PRODt DRILL DDRL P Directionally drill 8-3/4" hole from 3,428.0 4,280.0 00:00 06:00 3,428' MD to 4,280' MD / 2,796' TVD with 750 gpm, 1440 psi, 34% flow out, 10.44 ppg ECD, off bottom 1430 psi,160 rpm, 6.5k torque, 8k WOB, PUW 120k, SOW 93k, ROT 105k, 6k torque. Max gas of 30 units. Pump 30 - bbl hi vis 11 ppg 5 ppb nut plug medium sweeps every 400' MD with 20-30% increase in cuttings. Begin trickling in nut plug as LCM. ADT 4.51 hrs, Bit 15.78 hrs, Jar 15.78 hrs. SPRs @ 4,280' MD 12,796' TVD, 9.0 ppg, 06:05 hrs MP#1: 30 spm = 160 psi, 40 spm = 190 psi. MP#2: 30 spm = 160 psi, 40 spm = 190 psi. 10/26/2017 10/26/2017 6.00 PROD? DRILL DDRL P Directionally drill 8-3/4" hole from 4,280.0 5,037.0 06:00 12:00 4,280' MD to 5,037' MD / 3,026' TVD With 750 gpm, 1,535 psi, 33% flow out, 10.64 ppg ECD, off bottom 1,520 psi, 160 rpm, 6-9k torque, 6k WOB, PEW 133k, SOW 97k, ROT 112k, 8.5k torque. Max gas of 145 units. Pump 30 ON hi vis 11 ppg 5 ppb nut plug medium sweeps every 400' MD with 20-30% increase in cuttings. ADT 4.47 hrs, Bit 20.25 hrs, Jar 20.25 hrs. 10/26/2017 10/26/2017 6.00 PROD1 DRILL DDRL P Directionally drill 8-3/4" hole from 5,037.0 5,765.0 12:00 18:00 5,037' MD to 5,765' MD / 3,249' TVD with 750 gpm, 1710 psi, 33% flow out, 10.77 ppg ECD, 160 rpm, 6-10k torque, 61k WOB, PUW 139k, SOW 98k, ROT 112k, 8.5k torque. Max gas of 145 units. Pump 30 ON hi vis 11 ppg 5 ppb nut plug medium sweeps every 400' MD with 10% increase in cuttings. Increase Lotorq to 1.5% v/v for increasing torque. ADT 4.54 hrs, Bit 24.79 hrs, Jar 24.79 hrs. 10/26/2017 10/27/2017 6.00 PROD1 DRILL DDRL P Directionally drill 8-3/4" hole from 5,765.0 6,600.0 18:00 00:00 5,765' MD to 6,600' MD /3,504' TVD with 750 gpm, 1850 psi, 33% flow out, 10.98 ppg ECD, off bottom 1850 psi, 150 rpm, 8-14k torque, 9k WOB, PEW 153k, SOW 100k, ROT 121 k, 12k torque. Stop pumping 30 bbl hi vis 11 ppg 5 ppb nut plug medium sweeps @ 6,076' MD. Seeing various hard spots while drilling. Max gas of 3354 units at 6,303' MD / 3,414' TVD correlating with the Ugnu B sand. Total losses for the day of 113 bbls. ADT 4.59 hrs, Bit 29.38 hrs, Jar 29.38 hrs. SPRs @ 5,792' MD / 3,257' TVD, 9.1+ ppg, 18:11 hrs MP#1: 30 spm = 220 psi, 40 spm = 260 psi. MP#2: 30 spm = 220 psi, 40 spm = 260 psi. Page 7123 ReportPrinted: 11/28/2017 Operations Summary (with Timelog Depths) 1H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EMT" Our hr ( ) Phase O Code p Actry Code nY Time P- T -X Operelion Stan Depth n De End Depth (frKB) 10/27/2017 10/27/2017 6.00 PROD1 DRILL DDRL P Directionally drill 8-3/4" production 6,600.0 .7,265.0 00:00 06:00 hole from 6600'to 7265' MD, 3754' TVD. Pump at 750 gpm, 2045 psi, 33% F/O, ECD 11.27 ppg, MW 9.3 ppg. Rotate at 160 rpm with 13k Tq on btm, 13k Tq off btm. 8k WOB. Max gas 40 units. PUW 163k, SOW 102k, ROT 126k. ADT 4.35 hrs, Bit 33.73 hrs, Jars 33.73 hrs. 10/27/2017 10/27/2017 6.00 PROD1 DRILL DDRL P Directionally drill 8-3/4" production 7,265.0 7,737.0 06:00 12:00 hole from 7265'to 7737' MD, 4027' TVD. Pump at 750 gpm, 2105 psi, 32% F/O, ECD 11.10 ppg, MW 9.25 ppg. Rotate at 160 rpm with 14k Tq on btm, 14k Tq off-btm. 1 O WOB. Max gas 2528 units. PUW 176k, SOW 109k, ROT 136k. ADT 4.79 hrs, Bit 38.52 hrs, Jars 38.52 hrs. SPRs @ 7309' MD 3775' TVD, MW=9.25 ppg, 06:35 hours MP#1: 30 spm=180 psi, 40 spm=240 psi. MP #2: 30 spm=190 psi, 40 spm=240 psi. 10/27/2017 10/27/2017 4.25 PROD1 DRILL DDRL P Directionally drill 8-3/4" production 7,737.0 8,066.0 12:00 16:15 hole from 7737' to TO of 8066' MD, 4219' TVD. Pump at 750 gpm, 2255 psi, 33% F/O, ECD 11.17 ppg, MW 9.3 ppg. Rotate at 160 rpm with 9-15k Tq on-btm, 14k Tq off-btm. 5k WOB. Max gas 218 units. PUW 184k, SOW 112k, ROT 142k. ADT 3.44 hrs, Bit 41.96 hrs, Jar 41.96 hrs. 10/27/2017 10/2712017 0.75 PROD1 CASING CIRC P Obtain final parameters on bottom and 8,066.0 7,970.0 16:15 17:00 backream out stand from 8066'to 7970' MD with 750 gpm, 2210 psi, 34% F/O, ECD 11.08 ppg, 150 rpm, 9- 15k Tq, circulating 1 x bottoms up. SPRs @ 8066' MD 4219' TVD, MW=9.20 ppg, 16:30 hours MP#1: 30 spm=260 psi, 40 spm=320 psi. MP #2: 30 spm=270 psi, 40 spm=320 psi. 10/27/2017 10/27/2017 0.50 PROD1 CASING OWFF P Monitor well for flow -observe fluid 7,970.0 7,970.0 17:00 17:30 level drop -1 bbl over 30 minutes (2 bbl/hr static loss rate). 10/27/2017 10/28/2017 6.50 PRODi CASING BKRM P Backream out of hole from 7970'to 7,970.0 5,672.0 17:30 00:00 5672' MD with 750 gpm, 1820 psi, 34% F/O, Initial ECD 11.05 ppg, Final ECD 10.69 ppg, MW 9.25 ppg, 150 rpm, 9-15k Tq. Lay out 5" DP stands offline via mousehole while backreaming out. Downhole losses over past 24 hours = 56 bbls. Page 8123 ReportPrinted: 11128/2017 Operations Summary (with Timelog Depths) 1H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Depth Start Tama EM Time Dur (hr) Phase op Cotle Actor Code 7 Tirtre P-T-X o perabon (nK8) EM Depth (flKa) 10/28/2017 10/28/2017 6.00 PROD1 CASING BKRM P Backream OOH from 5672'to 3337' 5,672.0 3,337.0 00:00 06:00 MD with 750 gpm, 1400 psi, 34% NO, 150 rpm, 8-10k Tq. Initial ECD 10.60 ppg, Final ECD 9.91 ppg. Observe one brief pressure and torque increase at 3875' MD but otherwise pulled smooth, staged up pulling speed to 1000 ft/hr and laid down 5" DP via mousehole offline. 10/28/2017 10/28/2017 4.75 PROD1 CASING BKRM P Backream OOH from 3337'to 1882' 3,337.0 1,822.0 06:00 10:45 inside rasing shoe at 700 grpm, 1125 psi, 32% F/O, ECD 9.6 ppg, 100 rpm, 2K Tq, PUW 97k, SOW 97k. Slowed pulling speed while pulling BHA across coal stringer section. Observe some packoff tendencies from 3337' to 2950' MD, slowing pulling speed and pump rate as needed. 10/28/2017 10/28/2017 0.75 PROD1 CASING CIRC P Circulate hole clean with reciprocation 1,822.0 1,822.0 10:45 11:30 from 1822' to 1720' MD with 700 gpm, 1055 psi, 32% F/O, 100 rpm, 2k Tq, PUW 97k SOW 97k. Total 6600 strokes pumped. 10/28/2017 10/28/2017 0.50 PROD1 CASING OWFF P Blowdown topdrive and monitor well 1,822.0 1,822.0 11:30 12:00 for flow - well static. 10/28/2017 10/28/2017 1.75 PROD1 CASING PULD P Pull OOH on elevators from 1822 to 1,822.0 401.0 12:00 13:45 401' MD, laying out 5" DP sideways, monitoring displacement via trip tank. PUW 72k, SOW 74k. 10/28/2017 10/28/2017 0.25 PROD1 CASING OWFF P Monitor well for flow at top of BHA- 401.0 401.0 13:45 14:00 well static. 10/28/2017 10/28/2017 2.00 PROD1 CASING BHAH P PJSM. Pull OOH and lay down BHA, 401.0 0.0 14:00 16:00 removing radioactive source from EcoScope per SLB, monitoring displacement via trip tank. Bit graded 1-3-BT-S-X-1-CT-TD. Tercel stabilizer had a few chipped cutters and broken inserts in the gauge area and a small groove worn on the downhole end of the taper on the stabilizer. SonicScope stabilizers were wom down to body OD. EcoScope stabilizer was in good condition. Xceed stabilizers were worn significantly. 10/28/2017 10/28/2017 0.75 PRODi CASING BHAH P Clean and clear rig floor of BHA 0.0 0.0 16:00 16:45 equipment. 10/28/2017 10/28/2017 0.75 COMPZN CASING WWWH P Make up 2 xjoints 5" DP and stack 0.0 0.0 16:45 17:30 washer. Jet stack at 19 bpm, 35 psi, 35% F/O, total 158 bbls pumped. Lay . down stack washer and drill pipe. Blow down lop drive. 10/26/2017 10/28/2017 1.00 COMPZN CASING RURD P Make up wearbushing running tool, 0.0 0.0 17:30 18:30 RIH and attempt to pull wearbushing. Pull out and inspect running tool, no issues observed. Load remaining 7" casing in shed, confirm pipe count and placement of marker joints. Page 9123 ReportPrinted: 11/2812017 Operations Summary (with Timelog Depths) 1H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tmie End Time Omhr ( ) Phase C Code p Aebv Code by i X Time P-- Operation Start Depth en(ftKB)De End Depth (flKe) 10/28/2017 10/28/2017 1.75 COMPZN CASING RURD T RIH with wearbushing running tool. 0.0 0.0 18:30 20:15 Attempt to pull with tugger - unsuccessful. Latch elevators and pull 10k over with topdrive and try to work free- unsuccessful. Pull out and inspect running tool - no issues observed. Discuss with town. RIH, latch wearbushing and pull 15k over with topdrive and try to work free - unsuccessful. Pull 20k over with topdrive and try to work free - unsuccessful. Pull out and inspect running tool, no issues observed. 10/28/2017 10/28/2017 1.25 COMPZN CASING WWWH T Make up stack washer, RIH and jet 0.0 0.0 20:15 21:30 wellhead with 18.5 bpm, 75 psi, 36% F/O. Function lock down screws in and out while circulating. Lay down wash tool and blow down topdrive. 10/28/2017 10/28/2017 0.75 COMPZN CASING RURD T RIH with wearbushing running tool, 0.0 0.0 21:30 22:15 latch wearbushing, pull 20k over, and try to work free - unsuccessful. Discuss with town. 10/28/2017 10/28/2017 1.00 COMPZN CASING RURD T Rig up line to IA. Bring on mud pump 0.0 0.0 22:15 23:15 at 2 spm, observe pressure build up to 590 psi and then breakover. Slowly stage up to 3 bpm, 250 psi, 8% F/O. Circulate 64 bbls total while pulling 20k overpull and working it using the link tilt- observe wearbushing come - free. Pull to surface and inspect wearbushing - no galling or marks observed on the exterior of the wearbushing. A small amount of solids/debris was observed on the top of the wearbushing. 10/28/2017 10/29/2017 0.75 COMPZN CASING RURD P Lay out wearbushing running tool and 0.0 0.0 23:15 00:00 drill pipe joint. Clear floor and start rigging up GBR volant and casing handling equipment for running 7" casing. No downhole formation losses observed over past 24 hours. 10/29/2017 10/29/2017 1.50 COMPZN CASING RURD P Rig up to run 7" production casing. 0.0 0.0 00:00 01:30 Make up GBR volant tool, 150 ton side -door elevators, bail extensions, and spiders. 10/29/2017 10/29/2017 0.75 COMPZN CASING RURD T Change out air fitting on spiders. 0.0 0.0 01:30 02:15 10/29/2017 1029/2017 0.25 COMPZN CASING SFTY P Hold PJSM for running 7" production 0.0 0.0 02:15 02:30 casing. 10/29/2017 10/29/2017 0.75 COMPZN CASING PUTB P Make up shoelrack and RIH to 172' 0.0 172.0 02:30 03:15 MD. Bakedock shoetrack and pin end of joint #4, torque to 10000 fl-lbs. Both Shoe and Float collar are 7" 26# L-80 H563 Davis Lynch anti-rotational dual- float valves. XO joint used to go from H563 to TXP. Centralizers and stop collars pre-installed on casing in pattern of 3 x centralizers per 2 joints. Page 10123 ReportPrinted: 1112812017 Operations Summary (with Timelog Depths) 1H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stall `r m End Time 0u (hr) Phase Op Code Advity Code Time P -T -X Operation Start Depth (MB) E1d 0epM (fiKe) 10/29/2017 10/29/2017 0.25 COMPZN CASING CIRC P Fill pipe and circulate 10 bbls through 172.0 172.0 03:15 03:30 shoetrack. Pick up and check floats - floats holding. 10/29/2017 10/29/2017 4.00 COMPZN CASING PUTS P RIH with 7" 26# L-80 TXP casing from 172.0 1,816.0 03:30 07:30 172' to 1816' MD, monitoring displacement via pit#1, filling pipe on the fly using volant tool and topping off every 10 joints. SOW 85k. Use JetLube Run-NSeal dope and torque to 17500 ft -lbs. Centralizers and stop collars pre-installed on casing in pattern of 3 x centralizers per 2 joints. Note: Install 20' joint with RA tag installed in collar at 7013' MD (on-btm depth) 10/29/2017 10/29/2017 0.75 COMPZN CASING CIRC P Circulate bottoms up with 1,816.0 1,850.0 07:30 08:15 reciprocation from 1816' to 1850' MD, staging up pumps to 6 bpm, 52 psi, 17% F/O. SOW 89k. 10/29/2017 10/29/2017 4.75 COMPZN CASING PUTS P RIH with 7" 26# L-80 TXP rasing from 1,850.0 3,851.0 08:15 13:00 1850' to 3851' MD, monitoring displacement via pit91, filling pipe on the fly using volant tool and lopping off every 10 joints. SOW 88k. Use JetLube Run -N -Seal dope and torque to 17500 ft -lbs. Centralizers and stop collars pre-installed on casing in pattern of 3 x centralizers per 2 joints. Note: Centralized up to joint #93. Once casing is on bottom, top centralizer will be at 4287' MD. Total of 140 x Volant 7"x8-1/4" hydroform centralizers and 280 x set -screw type stop collars run in hole. 10/29/2017 10/29/2017 0.75 COMPZN CASING CIRC P Observe decreasing displacement. 3,851.0 3,883.0 13:00 13:45 Slop and circulate bottoms up with reciprocation from 3851'to 3883' MD, staging up pumps to 6 bpm, 165 psi, 17% F/O. SOW 89k. 10/29/2017 10/29/2017 3.25 COMPZN CASING PUTS P RIH with 7" 26# L-80 TXP casing from 3,883.0 5,329.0 13:45 17:00 3883' to 5329' MD, monitoring displacement via pit#1, filling pipe on the fly using volant tool and topping off every 10 joints. SOW 82k. Use JetLube Run -N -Seal dope and torque to 17500 ft -lbs. Note: Install 20' joint with RA tag installed in collar at 3009' MD (on-btm depth) 10/29/2017 10/29/2017 1.00 COMPZN CASING CIRC P Observe decreasing displacement. 5,329.0 5,329.0 17:00 18:00 Stop and circulate bottoms up with reciprocation from 5329'to 5299' MD, staging up pumps to 6 bpm, 195 psi, 16% F/O. SOW 84k. MW in 9.15ppg / Vis 48, MW out 9.25 ppg, Vis 54. Page 11/23 ReportPrinted: 11/28/2017 Operations Summary (with Timelog Depths) 1H-111 16 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tme End Tune Dur(hr) Phase op co Advly Code Tome P -T -X Opembw srertDept (flK0) End Depin(flKB) 10/29/2017 10/29/2017 2.00 COMPZN CASING PUTS P RIH with 7" 26# L-80 TXP casing from 5,329.0 6,137.0 18:00 20:00 5239' to 6137' MD, monitoring displacement via pit#1, filling pipe on the fly using volant tool and topping off every 10 joints. SOW 82k. Use JetLube Run -N -Seal dope and torque to 17500 fi-lbs. 10/29/2017 10/29/2017 1.50 COMPZN CASING PUTB P Make up XO and RIH with 7" 26# L-80 6,137.0 6,992.0 20:00 21:30 Hydril 563 doped rasing from 6137'to 6992' MD, monitoring displacement via pit# 1, filling pipe on the fly using volant tool and topping off every 10 joints. Use SealGuard dope and torque to 9400 ft -lbs. SOW 81k. 10/29/2017 10/29/2017 1.50 COMPZN CASING CIRC P Observe decreasing displacement. 6,992.0 6,992.0 21:30 23:00 - Stop and circulate bottoms up with reciprocation from 6992'to 6962' MD, staging up pumps to 6 bpm, 290 psi, 16% F/O. SOW 87k. MW in 9.2ppg / Vis 48, MW out 9.3 ppg, Vis 51. 10/29/2017 10/30/2017 1.00 COMPZN CASING PUTB P RIH with 7" 26# L-80 Hydril 563 doped 6,992.0 7,590.0 23:00 00:00 casing from 6992' to 7590' MD, monitoring displacement via pit# 1, filling pipe on the fly using volant tool and topping off every 10 joints. Use SealGuard dope and torque to 9400 ft - lbs. SOW 88k. Downhole losses over past 24 hours = 25 bbls. 10/30/2017 10/30/2017 0.75 COMPZN CASING PUTB P RIH with 7" 26# L-80 Hydril 563 doped 7,590.0 8,018.0 00:00 00:45 casing from 7590'to 8018' MD, monitoring displacement via pit# 1, filling pipe on the fly using volant tool and topping off every 10 joints. Use SealGuard dope and torque to 9400 fi- Ibs. PUW 206k, SOW 90k. 10/30/2017 10/30/2017 0.50 COMPZN CASING HOSO P Make up Vetco 7" mandrel casing 8,018.0 8,056.0 00:45 01:15 hanger using Volant tool to 9400 ft -lbs. Make up landing joint, RIH and land off at 8056.34' MD. Calculated displacement = 71.8 bbls, Actual displacement = 39.3 bbls (32.5 bbls lost on casing run). 10/30/2017 10/30/2017 1.25 COMPZN CEMENT CIRC P Circulate and condition mud with 8,056.0 8,056.0 01:15 02:30 reciprocation, staging up pumps to 8 bpm, 520 psi, 24% F/O, MW 9.1 ppg in/ 9.3 ppg out, PUW 203k, SOW 721k. SIMOPS - Start loading, strapping, and tallying 255 xjoints 4" DP in shed. 10/30/2017 10/30/2017 0.50 COMPZN CEMENT RURD P Blow down topdrive and rig up cement 8,056.0 8,056.0 02:30 03:00 line. Page 12123 Report Printed: 11/28/2017 Operations Summary (with Timelog Depths) ft 1H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start oepm sten Time End Time our(hr) Phase Op Code Actively Code Time P-T-X Opermion thKB) End NPM (WB) 10/30/2017 10/30/2017 1.00 COMPZN CEMENT CIRC P Continue circulating and conditioning 8,056.0 8,056.0 03:00 04:00 mud with reciprocation, staging up pumps to 8 bpm, 580 psi, 24% F/O, MW 9.2ppg in/out, PUW 204k, SOW 75k. SIMOPS - Hold PJSM for cementing and rig up SLB cementers. 10/30/2017 10/30/2017 3.00 COMPZN CEMENT CMNT P Pump cement job as follows: SLB 8,056.0 0.0 04:00 07:00 pump 5 bbls freshwater and pressure test lines to 600 14500 psi - good test. Pump 30 bbls 12.5ppg Mudpush at 3 bpm, ICP 260 psi, FCP 153 psi. Drop Davis Lynch anti-rotational bottom plug. Batch mix cement, cement wet at 04:48 hrs. SLB pump total of 140 bbls 15.8ppg Class G cement at 5.5 bpm, ICP 273 psi, FCP 146 psi. Drop Davis Lynch anti-rotational top plug. SLB pump 10 bbls freshwater at 6 bpm, 150 psi. Reciprocate pipe —13 R, PUW 185k, SOW 82k. Displace cement using SLB pump truck with 9.Oppg NaCl brine w/ 3% KCI at 6 bpm, ICP 100 psi, FCP 1247 psi for 275 bbls. Drop rate to 4 bpm, ICP 1015 psi, FCP 1100 psi for 10 bbls. Drop rate to 2 bpm, ICP 890 psi, FCP 1034 psi. Did not observe plugs bumping. Pumped total of 296.9 bbls of brine (displacement plus 112 of shoetrack volume). Hold pressure for 5 minutes. Bleed off and check floats - floats holding. Cement in place 06:35 hrs. Note: No downhole losses observed throughout cement job 10/3012017 10/30/2017 1.25 COMPZN CEMENT RURD P Drain stack, Pull and lay down landing 0.0 0.0 07:00 08:15 joint, Rig down GBR volant tool and T' casing handling equipment. 1013012017 10/30/2017 2.00 COMPZN CEMENT W WSP P Make up 7" packoff, RIH and install 0.0 0.0 08:15 10:15 per Vetco. Pressure test to 5000 psi / 10 minutes, witnessed by CPAI -good test. Pull running tool, make up and install short wearbushing, 9" ID. Lay down running tool. 10/30/2017 10/30/2017 1.75 COMPZN WELLPR RURD P Change out saver sub for XT39. 0.0 0.0 10:15 12:00 10/30/2017 10/30/2017 0.50 COMPZN WELLPR SVRG P Service and inspect topdrive and D.0 0.0 12:00 12:30 blocks. Page 13123 ReportPrinted: 11/28/2017 Operations Summary (with Timelog uepths) IH -111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start DepM Start TTme End Tmre Dur (hr) Phase Op code Ac fifty Code Torre P -T -X Operation (ftKB) End Depth(flKB) 10/30/2017 10/30/2017 2.50 COMPZN EVALWB QEVL P PJSM. Rig up SLB E -line unit and 0.0 0.0 12:30 15:00 sheaves on rig floor. Mobilize tools to dg floor and make up CBL logging BHA. Note: Due to not bumping plugs and uncertainty of where top will be inside casing, decision made to call out E - line earlier than planned and run a CBL log first and tag up TOC inside casing. Then POOH and RIH w/ USIT logging BHA. This ensures we won't damage the bottom of USIT logging BHA 10/30/2017 10/30/2017 7.00 COMPZN EVALWB QEVL P RIH on E -line to 2800' MD and then 0.0 0.0 15:00 22:00 tractor in hole at 50 ft/min from 2800' to 6600' MD. Tag up at 6600' MD. Pick up -100 ft with no overpull, PUW 2400 lbs. Increase arm force on tractor and run back in hole. Tag up at 6600' MD. Pick up and observe 1600 lbs overpull, then breakover and continue picking up -50 ft with some drag. Discuss with town, decision made to log out of hole and then perform cleanout run. Tum on logging tool and perform CBL log out of hole from 6600' MD at 50 ft/min. Note: Data suggests TOC at -3380' MD. 10/30/2017 10/30/2017 0.50 COMPZN EVALWB QEVL P Lay out CBL tools and rig down E -line 0.0 0.0 22:00 22:30 unit. Clean and clear floor. 10/30/2017 10/30/2017 1.00 COMPZN EVALWB SHAH T Make up cleanout BHA with 6-1/8" 0.0 284.0 22:30 23:30 Baker STX-1 Mill -tooth bit jetted with 3 x 20's, bit sub, float sub with ported flapper float installed, XO, and 9 x joints 4" HWDP to 284' MD, monitoring displacement via trip tank. 10/30/2017 10/31/2017 0.50 COMPZN EVALWB PULD T Trip in hole with cleanout BHA on 4" 284.0 757.0 23:30 00:00 DP singles from shed from 284'to 757' MD, monitoring displacement via trip tank, allowing pipe to self -fill. 10/31/2017 10/31/2017 5.50 COMPZN EVALWB PULD T Trip in hole with cleanout BHA on 4" 757.0 6,535.0 00:00 05:30 DP singles from shed from 757'to 6535' MD, monitoring displacement via trip tank, allowing pipe to sett -fill. PUW 125k, SOW 76k. 10/31/2017 10/31/2017 3.00 COMPZN EVALWB WASH T Wash down on 4" DP stands from 6,535.0 7,822.0 05:30 08:30 6535'to 7822' MD with 400 gpm, 1400 psi, 24% FIO, PUW 120k, SOW 691k, Make up stands offline via mousehole. Note: Did not see more than 0.5-1 k drag throughout the section. Page 14123 Report Printed: 1112812017 Operations Summary (with Timelog Depths) 1H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth stag Time End Time Dur (hr) Phew Op Code Activity Code Time P-TA Operabon (AKB) End DepM{fIKB) 10/31/2017 10/31/2017 1.00 COMPZN EVALWB COCF T Tag up at 7822' MD with 5k weight 7,822.0 7,888.0 0830 09:30 twice. Engage rotary and ream cement from 7822' to 7888' MD with 400 gpm, 1570 psi, 25% F/O, 60 rpm, 7k Tq, 200-300 fl/hr ROP, 1-3k WOB. PUW 140k, SOW 70k. Tag up at 7888' MD on lop plug twice with 6k weight (77' above goat collar). Discuss with town and confirm depth is enough to accomodate perforation run and upper completion. 10/31/2017 10/31/2017 1.25 COMPZN EVALWB CIRC T Circulate and condition hole from 7,888.0 7,855.0 09:30 10:45 7882' to 7855' MD with 450 gpm, 1935 psi, 26% F/0, 70 rpm, 7.5k Tq. Pump 15 bbl hi-vis sweep and chase at 500 gpm, 2330 psi, 26% F/O - dump all of the sweep out to rockwasher once returned to surface. 10/31/2017 10/31/2017 3.00 COMPZN EVALWB TRIP T Blowdown topdrive and confine well 7,855.0 284.0 10:45 13:45 static. Pull OOH on elevators from 7855'to 284' MD, racking back 4" DP and monitoring displacement via trip tank. 10131/2017 10131/2017 0.50 COMPZN EVALWB BHAH T Pull OOH from 284'to surface, laying 284.0 0.0 13:45 14:15 out cleanout BHA. Observe small metal ring and small chunk of top plug lodged in bit. Bit graded 0-0-NO-A-E-0 -NO-LOG. Clean and dear rig floor. 10131/2017 10/3112017 3.75 COMPZN EVALWB QEVL P PJSM. Rig up SLB E-line. Determine 0.0 0.0 14:15 18:00 tractor tool and CBL tool needed to be swapped out - change out with new tools. Make up USIT / CBL BHA on dg floor. SIMOPS - Install new enclosure for vac system on rockwasher, Service and prep drill pipe slips. 10/31/2017 10/31/2017 4.00 COMPZN EVALWB QEVL P RIH to 7862' MD with USIT/CBL BHA 0.0 0.0 18:00 22:00 1 on tractor at -50 ft/min. 10/31/2017 11/1/2017 2.00 COMPZN EVALWB QEVL P Perform USIT/CBL log of cement from 0.0 0.0 22:00 00:00 7862' to 4350' MD at 30 ft/min. Performed repeat pass on bottom - tool working fine. 11/1/2017 11/1/2017 2.50 COMPZN EVALWB QEVL P Perform USIT/CBL log of cement from 0.0 0.0 00:00 02:30 4350'to 2554' MD at 30 fl/min. No repeat pass required at top. Estimated top of cement at 3350' MD. Continue POOH to surface with tools. SIMOPS - Once logging tool turned off, flush 10-314" x 7" annulus with 100 WE freshwater using rig's mud pump #1. Bring on pump at 0.5 bpm and observe pressure steadily build to 350 psi. Discuss with town. Continue injecting at 0.5 bpm and pressure build to 430 psi and stabilize after 9 bbls pumped. Moderate rate between 0.5 - 1.3 bpm keeping pressure at or below 500 psi, total 100 bbls pumped. Page 15123 Report Printed: 11128/2017 Operations Summary (with Timelog Depths) 1H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Dept, StartTime End Time Dur (hr) Phase Op Code Ac viy Code Time RT -X Opemton (ftKB) End Depth (flKB) 11/1/2017 11/1/2017 1.50 COMPZN EVALWB QEVL P Lay down E -line tools and dg down E- 0.0 0.0 02:30 04:00 1 line. 11/1/2017 111112017 1.00 COMPZN WELLPR PRTS P Purge lines, close blind rams, and 0.0 0.0 04:00 05:00 pressure lest 7" production casing with 9.0 ppg brine using mud pump #1 to 3500 psi 130 minutes - good test. Pumped 6.1 bbls, returned 6.1 bbls. 11/1/2017 11/1/2017 0.25 COMPZN PERF SFTY P PJSM for making up perforation 0.0 0.0 05:00 05:15 assembly. 11/1/2017 11/1/2017 2.25 COMPZN PERF BHAH P Make up Halliburton Millienium 0.0 - 637.0 05:15 07:30 express perforation gun assembly with bottom and top time delayed firing heads. P/U 2 x joints 4" DP, then make up safety disconnect (120k shear) and Champ packer per Halliburton. Make up 1 x joint 4" DP and then 9.63' marker sub (4" drill pipe pup) to 637' MD. Monitor displacement via trip tank. 11/112017 111112017 0.50 COMPZN PERF TRIP P Trip in hole on 4" DP stands from 637' 637.0 921.0 07:30 08:00 to 921', filling pipe on the fly via fill -up hose with 9.0ppg brine. Monitor displacement via trip tank. 11/1/2017 11/1/2017 0.50 COMPZN PERF SVRG P Service rig. Inspect ST -100 iron 921.0 921.0 08:00 08:30 roughneck. SIMOPS - Rig up LRS and freeze protect 10-3/4" x 7" annulus with 90 bbls Isotherm at 1.5 bpm, 650 psi. Shut in OA with 290 psi. 11/112017 1111/2017 3.00 COMPZN PERF RGRP T Troubleshoot ST -100 iron roughneck. 921.0 921.0 08:30 11:30 11/1/2017 1111/2017 3.25 COMPZN PERF TRIP P Trip in hole on 4" DP stands from 921' 921.0 5,756.0 11:30 14:45 to 5756' MD, filling pipe on the fly via fill -up hose with 9.0 ppg brine. Monitor displacement via trip tank. 11/1/2017 11/1/2017 1.25 COMPZN PERF TRIP P Trip in hole on 4" DP stands from 5,756.0 7,780.0 14:45 16:00 5756'to bottom, leaving drill pipe empty and monitoring displacement via trip tank. Tag cement plug at 7887.45' MD. Rack back stand #77 and lay down top 2 x singles on stand #76 to 7780.34' MD (on upstroke, string in tension). PUW 135k, SOW 71k. Guns -8ft below desired pert depth. Note: Target 800 psi underbalance in drill pipe to formation for perforating, assuming 8.6ppg pore pressure 11/1/2017 11/1/2017 1.00 COMPZN PERF ELOG P PJSM. Rig up E -line unit. 7,780.0 7780.0 16:00 17:00 11/112017 1111/2017 1.00 COMPZN PERF ELOG P RIH with E -line tools for depth 7,780.0 7,780.0 17:00 18:00 correlation run to 3100' MD. Observe tool failure. 11/1/2017 11/1/2017 2.00 COMPZN PERF ELOG T POOH and inspect tools at surface. 7,780.0 7,780.0 18:00 20:00 No good indication of why failure occured. Change out toolstring and RIH to 3100' MD. Page 16123 Report Printed: 1112 812 01 7 . Operations Summary (with Timelog uepths) 1H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log ^.><ertcepm $tart Time End Tune Q., (hr) Phase Op Cotle ActiNry Code Ttme P -T -X Operation (flKB) End Depth (ftKB) 11/1/2017 11/1/2017 1.50 COMPZN PERF ELOG P Unable to work past 3100' MD. 7,780.0 7,780.0 20:00 21:30 Discuss with town. Perform depth correlation off of upper marker joint/ upper PIP tag. Observe PIP tag at 3011.5' MD and top of marker joint at 3032' MD. To put guns on depth (marker joint 10.9' below PIP tag per prior logs), calculate string needs to be picked up total of 9.6'. Confirm depth correlation with town. POOH wl E -line. Note: Per tally, marker joint should be at 3030.46' MD. Per log, marker joint is at 3032.0', so 1.54' deep to tally. 11/1/2017 11/1/2017 1.00 COMPZN PERF ELOG P Rig down E -line. 7,780.0 7,780.0 21:30 22:30 11/1/2017 11/112017 0.25 COMPZN PERF MPSP P Mark pipe. Pick up 9.6' and mark pipe. 7,780.0 7,772.3 22:30 22:45 Pick up additional 1' (for packer travel) and mark pipe. Set Champ packer per Halliburton. Put in 3 x wraps and slack off to 48k HL (23k on packer), confirming packer set. PUW 135k, SOW 71 k. 11/1/2017 11/1/2017 0.25 COMPZN PERF SFTY P PJSM for perforating 7" casing. 7,772.3 7,772.3 22:45 23:00 11/1/2017 11/1/2017 0.75 COMPZN PERF RURD P Rig up line from DP to choke manifold 7,772.3 7,772.3 23:00 23:45 and line up to pump down IA. Purge lines and close annular. 11/1/2017 11/2/2017 0.25 COMPZN PERF PERF P Pressure up on IA to 1000 psi with 7,772.3 7,772.3 23:45 00:00 mud pump #1 and hold for 10 minutes - observe pressure holding steady. Continue pressuring up to 3500 psi and hold for 30 seconds. Bleed off IA pressure to 0 psi and monitor drill pipe. Observe good indication of guns firing 395 seconds after reaching minimum set pressure. Top perforation at 7276' MD Btm perforation at 7769' MD. 1112/2017 11/2/2017 0.25 COMPZN PERF OWFF P Monitor well for pressure buildup on 7,772.3 7,772.3 00:00 00:15 the drillpipe up against dosed rig choke - no pressure was observed after 10 minutes. Pressure up to 500 psi on the annulus and pick up to open bypass on packer - observe pressure dump giving good indication that bypass is open. Page 17123 ReportPrinted: 1112812017 Operations Summary (with Timelog uepths) IH -111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log scan oepth Stan Time End Titre Diu (hr) Phase Op Code Ad ty cad. Irma P -T -x Operation (8Ke) End Dep0 r1Ka) 11/2/2017 11/2/2017 1.00 COMPZN PERF CIRC P Withannular closed, reverse circulate 7,772.3 7,772.3 00:15 01:15 with mud pump #1 using drillers method isolated pit #1 with 9.Oppg brine, staging up to 2 bpm, 100 psi taking returns up the drill pipe through the rig choke to the MGS. Monitor returns and observe hydrocarbons at surface after 60 bbls pumped. Shut down and route returns through rig choke out dump line to the tiger tank. Stage up rate to 2 bpm, 100 psi and finish pumping total of 1.5 bottoms up (38 bbls diverted to tiger tank) - still observing crude strung out in brine at surface. Note: Estimate 5-10 bbls of crude returned to surface but was strung out. 11/2/2017 11/2/2017 0.50 COMPZN PERF OWFF P Shutdown and allow hydrocarbons to 7,772.3 7,772.3 01:15 01:45 migrate for 30 minutes. No pressure observed on drill pipe. 11/2/2017 11/2/2017 0.50 COMPZN PERF CIRC P Stage up rate to 2 bpm, 100 psi and 7,772.3 7,772.3 01:45 02:15 divert additional 48 bbls to tiger tank until clean brine observed at surface (total of 88 bbls diverted to tiger tank). 11/2/2017 11/2/2017 0.50 COMPZN PERF OWFF P Shut down and monitor well for 7,772.3 7,772.3 02:15 02:45 pressure - no pressure buildup observed. Open sample line and confirm no flow. Strip up through annular 6'to release champ packer per HES. Strip down through annular and confirm packer released. Blow down line to tiger tank and line up to circulate down the ddllpipe taking returns up the annulus through rig choke to MGS. 11/2/2017 11/2/2017 1.25 COMPZN PERF CIRC P Stage up mud pump to 4 bpm, 355 psi 7,772.3 7,772.3 02:45 04:00 and circulate 1 x surface-to-surface volume taking returns to MGS, isolated on pit #1. Minimal amount of hydrocarbon observed at shakers. Confirm good 9.Oppg brine in/out. Observe 5 bbl loss throughout circulation. 11/2/2017 11/2/2017 0.50 COMPZN PERF OWFF P Shut down, close choke and confine 7,772.3 7,772.3 04:00 04:30 no pressure buildup. Open sample line and confirm no flow. Open annular and monitor well for flow - well static. SIMOPS - Rig down lines for circulating. 11/2/2017 11/2/2017 0.50 COMPZN PERF RURD P Finish rigging down and blowing down 7,772.3 7,752.0 04:30 05:00 circulating assembly. Re -assemble stand #76 and rack back to 7752'. 11/2/2017 11/2/2017 3.00 COMPZN PERF TRIP P Trip OOH racking back 4" DP from 7,752.0 637.0 05:00 08:00 7752' to 637' MD, monitoring displacement via trip tank. Page 18/23 ReportPrinted: 1 7 12 812 01 7 . Operations Summary (with Timelog Depths) 1 H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time Ertl Torre Dur (hr) Phase Op Code AC" Code Torre P -T -X Operation Step DeW (ftKB) Erb Depth (ftKB) 11/2/2017 11/2/2017 2.00 COMPZN PERF BHAH P PJSM. Pull OOH laying down 637.0 0.0 08:00 10:00 Halliburton perforating assembly from 637'to surface, monitoring displacement via trip tank. All guns had fired and were in phase. 11/2/2017 11/2/2017 0.50 COMPZN PERF SHAH P Clean and dear dg floor. Mobilize 0.0 0.0 10:00 10:30 remaining scraper BHA to rig floor. 11/2/2017 11/2/2017 0.75 COMPZN WELLPR SHAH P PJSM. Make up scraper BHA per 0.0 52.0 10:30 11:15 Baker with bullnose, magnet, boot basket, scraper, boot basket, magnet, jar, and XO to 52'. 11/2/2017 11/2/2017 3.00 COMPZN WELLPR TRIP P Run in hole with 6 x singles 4" DP 52.0 7,250.0 11:15 14:15 from pipe shed followed by 4" DP stands from derrick from 52' to 7250' MD, monitoring displacement via trip tank. PUW 135k, SOW 75k. 11/2/2017 11/2/2017 2.75 COMPZN WELLPR CIRC P Break circulation and stage up to 5 7,250.0 7,888.0 14:16 17:00 bpm, 470 psi, 16% F/O. Wash down each stand through perforation zones from 7250' to 7630' MD. Pump 25bbl hi -vis sweep at 7630' MD and circulate around - nothing observed at surface. Continue washing down to bottom. Drop rate to 1 bpm, 40 psi, 3% F7O, wash down and tag up at 7888' MD. 11/2/2017 11/2/2017 1.25 COMPZN WELLPR CIRC P Stage up pumps to 5 bpm, 430 psi, 7,888.0 7,885.0 17:00 18:15 17% F7O and pump 17 bbl hi -vis sweep reciprocating from 7885'to 7855' MD. Observe -1 bbl of sand/crude mixture at surface at bottoms up, gas briefly spiked up to 517 units. When actual sweep came back to surface, no additional cuttings observed. Confirm good 9.Oppg in/out brine. Total of 3400 strokes pumped. 11/2/2017 11/2/2017 0.50 COMPZN WELLPR OWFF P Monitor well for flow -observe fluid 7,880.0 7,880.0 18:15 18:45 level dropping slightly. Blowdown topdrive. PUW 145k, SOW 83k. 11/2/2017 11/3/2017 5.25 COMPZN WELLPR PULD P Pull OOH sideways laying out 4" DP 7,880.0 1,600.0 18:45 00:00 from 7880'to 1600' MD, monitoring displacement via trip tank. Downhole losses over past 24 hours = 29 bbls OA pressure at midnight = 140 psi 11/3/2017 11/3/2017 1.00 COMPZN WELLPR PULD P Pull OOH sideways from 1600'to 52' 1,600.0 52.0 00:00 01:00 MD, laying down 4" DP and monitoring displacement via trip tank. 11/3/2017 11/3/2017 1.00 COMPZN WELLPR BHAH P PJSM. Lay down scraper BHA and 52.0 0.0 01:00 02:00 clean/clear rig floor. Observe pockets on magnets -1/2 full of metal shavings. Observe total of -1 cup of debris Contained in boot baskets, crude -contaminated metallsand mixture. Page 19123 Report Printed: 1112 812 01 7 - Operations Summary (with Timelog Uepths) 1H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stall Time End Time Dur (hr) Phase Op Code An fty Code Time P -T -X Operation Start Depth (ftKB) End Depth(ftKB) 11/3/2017 11/3/2017 2.50 COMPZN RPCOMP RURD P Rig up to run 3-1/2" upper completion. 0.0 0.0 02:00 04:30 Change out handling equipment, rig up SLB spooler and sheave, mobilize cannon clamps to floor, and rig up GBR power tongs. M/U XO to TIW for well control. Note: Observe static losses at -0.5 bbl/hr while rigging up. 11/3/2017 11/3/2017 0.25 COMPZN RPCOMP SFTY P PJSM for running upper completion 0.0 0.0 04:30 04:45 11/3/2017 11/32017 1.25 COMPZN RPCOMP PUTB P Make up Baker trailblazer wellbore 0.0 367.0 04:45 06:00 prep tool with muleshoe and WIV, followed by 1 x 4' spaceout pup, 7 x joints 3-1/2" 9.3# L-80 EUE-m tubing, 2 x water injection mandrels, 1 x . nipple, 1 x gauge, 1 x Baker feed-thru packer, and 2 x 10'spaceout pups. Use JetLube Run -N -Seal dope and torque to 2240 ft -lbs. 11/3/2017 11/3/2017 2.25 COMPZN RPCOMP PUTB P Terminate wire into DHG #1 and 367.0 367.0 06:00 08:15 Baker feed-thru packer #1. SLB pressure test DHG connection to 5000 psi 15 min. Baker test ports on feed- thru packer to 7500 psi / 15 min each. 11/3/2017 11/3/2017 0.50 COMPZN RPCOMP PUTB P Run in hole with 2 x water injection 367.0 454.0 08:15 08:45 mandrels, 1 x gauge, and 1 x Baker feed-thru packer from 367'to 454' MD, installing cannon clamps per SLB, monitoring displacement via trip tank. Use JetLube Run -N -Seal dope and torque to 2240 ft -lbs. 11/3/2017 11/32017 2.75 COMPZN RPCOMP PUTB P Terminate wire into DHG #2 and 454.0 454.0 08:45 11:30 Baker feed-thru packer #2. SLB pressure test DHG connections to 5000 psi / 5 min each. Baker test ports on feed-thru packer to 7500 psi / 15 min each. 11/32017 11/3/2017 0.50 COMPZN RPCOMP PUTB P Run in hole with 2 x joints 3-1/2" 9.3# 454.0 618.0 11:30 12:00 L-80 EUE-m tubing, 2 x water injection mandrels, 1 x nipple, 1 x gauge, and 1 x Baker feed-thru packer from 454' to 618' MD, installing cannon clamps per . SLB.. Use JetLube Run -N -Seal dope and torque to 2240 ft -lbs. Monitor displacement via trip tank. 11/3/2017 11/3/2017 3.25 COMPZN RPCOMP PUTB P Terminate wire into DHG #3 and 618.0 618.0 12:00 15:15 Baker feed-thru packer #3. SLB pressure test DHG connections to 5000 psi 15 min each. Baker lest ports on feed4hru packer to 7500 psi / 15 min each. Page 20123 Report Printed: 11128/2017 Operations Summary (with Timelog Depths) 1H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan oepth Start Time End Time Dur (hr) Phase Op Code Aciviry Code Time P -T -X Operation (flKB) End Depth (ftKB) 11/3/2017 11/4/2017 8.75 COMPZN RPCOMP PUTS P Run in hole with 3-1/2"9.3# L-80 EUE 618.0 7,000.0 1515 00:00 -m tubing from 618'to 7000' MD, installing cannon clamps per SLB on every collar and installing 1 x GLM with 2500 psi casing -tubing SOV. Use JetLube Run -N -Seal dope and torque to 2240 fl -lbs. Monitor displacement via trip tank. OA pressure at midnight = 180 psi Downhole formation losses over past 24 hours = 18 bbls 11/4/2017 11/4/2017 1.50 COMPZN RPCOMP PUTB P Run in hole with 3-1/2" 9.3# L-80 EUE 7,000.0 7,890.0 00:00 01:30 -m tubing from 7000'to bottom, installing cannon clamps per SLB on every collar. Use JetLube Run -N -Seal dope and torque to 2240 ft -lbs. Monitor displacement via trip tank. Tag bottom at 7890.22' MD with 6k weight (6.28' in on jt# 240), 2.22' deep. PUW 100k, SOW 66k. 11/4/2017 11/4/2017 1.00 COMPZN RPCOMP CRIH P Lay down joint #240, Make up head 7,890.0 7,882.0 01:30 02:30 pin and cement hose, and pump 82 bbls corrosion inhibited brine at 128 gpm, 226 psi, chase with 10 bbls brine to dear surface lines to rig floor. 11/4/2017 11/4/2017 0.25 COMPZN RPCOMP HOSO P Pull OOH laying down joint # 239 & 7,882.0 7,815.0 02:30 02:45 238. Stroke jt #237 up and then run back in hole placing string in compression, SOW 66k. Set slips with 3.5' stickup (btm at 7815.43' MD). 11/4/2017 11/4/2017 3.25 COMPZN RPCOMP ELOG P Rig up E -line to perform depth 7,815.0 7,815.0 02:45 06:00 correlation log. Make up XO, pump -in sub, and packoff to allow ability to pump down if unable to run to bottom. 11/4/2017 11/4/2017 1.50 COMPZN RPCOMP ELOG P RIH with E -line tools to 7300' MD. 7,815.0 -7,815.0 06:00 07:30 Monitor well via trip tank. Note: Able to run to bottom without pumping but had to run in fast to get down. 11/4/2017 11/4/2017 1.00 COMPZN RPCOMP ELOG P Pull OOH w/ E -line performing depth 7,815.0 7,815.0 07:30 08:30 correlation log from upper pup joint above packer to lower PIP tag. Monitor well via trip tank. E -line find PIP tag @ 7015.5' MD E -line find Marker pup @ 7197.0' MD (by tally it was at 7197.35' MD) Desired depth of marker pup @ 7204.92'. Confirm spaceout with town. 11/4/2017 11/4/2017 1.00 COMPZN RPCOMP ELOG P Lay out tools and rig down E -line. 7,815.0 7,815.0 08:30 0930 Page 21123 ReportPrinted: 11 /2 812 01 7 Operations Summary (with Timelog Depths) 1H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our hr ( ) Phew Op Cotla Admly Coae Time P-T-X Operation epffi Start B) (WB) e) EM OaPm (fll(6) 11/4/2017 11/4/2017 1.25 COMPZN RPCOMP HOSO P Pull OOH and lay down A#237,236, 7,815.0 7,790.0 09:30 10:45 and 235. Make up spaceout pups (10.41', 6.19', and 2.43'), XO, 1 xjt 4- 1/2" 12.6# L-80 Hydril 563 tubing, and 4-1/2" tubing hanger with false bowl. Total of 235 x 3-1/2" Cannon Clamps installed Total of 2 x 4-1/2" Cannon Clamps installed Total of 12 x Half Cannon clamps installed (on jewlery) Total of 1 x 4-1/2" x 3-12" XO Cannon clamp installed 11/4/2017 11/4/2017 0.50 COMPZN RPCOMP THGR P Terminate Tec wire at tubing hanger 7,790.0 7,790.0 10:45 11:15 per SLB. 11/412017 11/4/2017 1.75 COMPZN RPCOMP THGR P Make up landing joint, RIH and land 7,790.0 7,822.7 11:15 13:00 off tubing hanger. Run in lockdown screws. Pressure test hanger seals to 5000 psi / 15 min, witnessed by CPAI. Calculated displacement for trip = 23 bbls, Actual fill = 3.8 Wis. SIMOPS - R/U lines to pump Cl brine and perform pressure testing. UD SLB Tec wire equipment and GBR equipment from rig floor. 11/4/2017 11/4/2017 1.25 COMPZN RPCOMP PACK P Pump 150 bbls 9.0ppg Corrosion- 7,822.7 7,822.7 13:00 14:15 inhibited brine down tubing at 190 gpm, 578 psi, 12% F/O. Drop 1.25" OD ball and pump down with corrosion-inhibited brine at 127 gpm, 257 psi, 12% F/O for 510 strokes, slow rate to 85 gpm, 111 psi, 11 % FIC, and seat ball at 605 strokes. Pressure up to 4200 psi and set packers - total 2107 strokes pumped. 11/4/2017 11/42017 1.00 COMPZN RPCOMP PRTS P Bleed tubing to 0 psi and changeout 7,822.7 7,822.7 14:15 15:15 sensator. Pressure test tubing to 4000 psi for 30 minutes, charted - good test. 1.2 We pumped. 11/4/2017 11/4/2017 1.00 COMPZN RPCOMP PRTS P Bleed tubing to 2000 psi. Line up and 7,822.7 7,822.7 15:15 16:15 pressure test IA to 3500 psi / 30 minutes, charted - good test. 3 bbis to pressure up. Bleed tubing pressure to 0 psi and observe SOV shear once at 2550 psi differential rasing-to-tubing. 11/4/2017 11/4/2017 0.50 COMPZN RPCOMP OWFF P Monitor well for flow -well static. 7,822.7 0.0 16:15 16:45 SIMOPS - Lay down landing joint, rig down and blow down circulating lines used for pressure testing. 11/4/2017 11/4/2017 1.25 COMPZN WHDBOP MPSP P Install HP-type BPV per Vetco. 0.0 0.0 16:45 18:00 Pressure up on IA and test BPV from below to 250 psi / 5 min and 2500 psi / 10 min, charted - good test. Rig down and blow down lines to cellar. SIMOPS - Lay down mousehole. Page 22123 ReportPrinted: 1112812017 Operations Summary (with Timelog Uepths) 1 H-111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Torre fiM Torre Our r Phase Op Cale Acbvity Code Time P -T -X Operation Siert Depth 0tl(a) Entl Depth (tU(6) 11/4/2017 11/4/2017 2.00 COMPZN WHDBOP NUND P Nipple down BOPE. Remove riser, 0.0 0.0 18:00 20:00 choke and kill hoses. Remove spacer spool and rack back BOPE stack in mezzanine. 11/4/2017 11/4/2017 2.50 COMPZN WHDBOP NUND P Convert HP-BPV to two-way check, 0.0 0.0 20:00 22:30 clean off top of hanger, feed Tec wire through and nipple up Vetco tree. SLB terminale Tec wire at tree. 11/4/2017 11/5/2017 1.50 COMPZN WHDBOP PRTS P Pressure test tree connection to 5000 0.0 0.0 22:30 00:00 psi 115 min per Vetco, witnessed by CPAI - good test. Fill tree with diesel and pressure test 250/5000 psi 15 minutes - no leaks observed. SLB perform electrical test of Tec wire - no issues. Downhole losses over past 24 hours = 11 bbls OA pressure at midnight = 150 psi 11/5/2017 11/5/2017 1.00 COMPZN WHDBOP MPSP P Confirm no pressure under HP BPV 0.0 0.0 00:00 01:00 then pull HP BPV w/ test dart with dry rod. 11/5/2017 11/5/2017 2.00 COMPZN WHDBOP FRZP P Rig up LRS to pump Isotherm down IA 0.0 0.0 01:00 03:00 and pressure test lines to 2000 PSI. LRS pump 48 bbls of Isotherm followed by 10 bbls of diesel down IA @ 1 bpm= 500 psi. Line LRS up to 3- 112" tubing and pump 15 bbls of diesel down tubing @ 1 bpm=200 psi. Rig down LRS. SIMOPS, C/O saver sub to 4-1/2" IF. Isotherm @ 1820' MD on IA. Diesel @ 1820' MD on tubing. 11/5/2017 11/5/2017 1.50 COMPZN WHDBOP MPSP P Rig up lubricator as per GE rep and 0.0 0.0 03:00 04:30 test to 1000 psi. Install H BPV as per GE rep, RID lubricator. 11/5/2017 11/5/2017 1.50 DEMOB MOVE RURD P Install gauges on tree, wipe down tree 0.0 0.0 04:30 06:00 and clean cellar. OA pressure = 75 psi IA pressure = 60 psi Tubing pressure = 60 psi 11/5/2017 2.00 DEMOB MOVE RURD P Clean out cellar box, blow down lines 0.0 0.0 1111512017 06:00 08:00 1 and prep to move rig to 1 H-114. Rig released @ 08:00 hours. Page 23/23 ReportPrinted: 11/28/2017 NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H-111 1H-111 ConocoPhillips Definitive Survey Report 03 November, 2017 tt �t� ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 11-1-111 Project: Kuparuk River Unit TVD Reference: 1 H-111 actual @ 92.72usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: IH -111 actual @ 92.72usft (Doyon 142) Well: 1H-111 North Reference: True Wellbore: 1H-111 Survey Calculation Method: Minimum Curvature Design: 1 H-111 Database: OAKEDMP2 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 I Well IH -111 Audit Notes: To Well Position +N/ -S 0.00 usft Northing: 5,980,872.05 usft Latitude: 70° 21'30B91 N 38.62 +E/ -W 0.00 usft Easting: 549,562.21 usft Longitude: 149° 35'50.828 W Position Uncertainty (usft) 0.00 usft Wellhead Elevation: usft Ground Level: 54.10 usft Welfbors Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°I r) W) BGGM2017 11/15/2017 1740 80.94 57,485 Design 1H-111 Date Audit Notes: To Map Map Version: 1.0 Phase: ACTUAL Tie On Depth: 38.62 Vertical Section: Depth From (TVD) +NI -S +E/ -W Direction 1,053.75 (usft) (usft) (usft) r) 1,847.78 38.62 0.00 0.00 105.91 Survey Program Date Fran To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 135.09 1,013+131H-111 Srvy1- SLB _GWD70(1H-111) GYD-GC-SS Gyrodata gyro single shots 10/21/201710:1 1,053.75 1,761.121H-111 Srvy 2- SLB_MWD _GMAG(I H-1 MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 10/22/201710:1 1,847.78 1,847+781H-111 Srvy3-SLB_ MWD-Inc-Filler(1H MWD-INC_ONLY MWD -INC -ONLY -FILLER 10/252017 9:1£ 1,942.03 8,000.801H-111SDy4-SLB+MWD+GMAG(1H- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 10/252017 9:2: Survey HAW017 11:2730AM Page 2 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (-/100') (ft) Survey Tool Name 3862 0.00 0.00 3862 -54.10 0.00 0.00 5,980,872.05 549,562.21 0.00 0.00 UNDEFINED 135.09 0.48 185.35 13509 42.37 -0.40 -0.04 5,980,871.65 549,562.17 0.50 0.07 GYD-GC-S$(1) 16700 0.25 218.58 167.00 74.28 -0.59 -0.09 5,980,871.46 549,562.12 0.95 0.07 NOT an Actual Survey 20" x 42" 182.39 0.22 253.80 182.39 89.67 -0.62 -0.14 5,980,871.42 549,562.07 0.95 0.03 GYD-GC-SS(1) 231.00 0.36 242.56 231.00 138.28 -0.72 -0.37 5,980,871.33 549,561.85 0.31 -0,16 GYD-GC-SS(1) 312.78 0.00 21669 312.78 220.06 -0.84 -0.60 5,980,871.21 549,561.62 0.44 -0.34 GYD-GC-SS(1) 356.80 0.22 34502 35680 264.08 -0.76 -0.62 5,980,871.29 549,561.60 0.50 -0.39 GYO-GCSS(1) 44001 1.05 68.69 449.00 356.28 -0.28 0.12 5,99,871.77 549,562.33 1.14 0.20 GYD-GCSS(1) 542.81 1.73 85.49 542.77 450.05 0.14 2.34 5,980,87221 549,564.54 0.84 2.21 GYD-GC-SS(1) 636.12 4.40 103.48 635.94 54322 -0.58 722 5,980,871,52 549,569.43 3.01 7.10 GYD-GC-SS(1) HAW017 11:2730AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-111 Project: Kuparuk River Unit TVD Reference: 1H-111 actual @ 92.72us%(Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-111 actual @ 92.72usa (Doyon 142) Well: 1H-111 North Reference: True Wellbore: 1H-111 Survey Calculation Method: Minimum Curvature Design: 1 H-111 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +FJ -W Northing Eluding DLS Section (usft) (*) (9 (usf) (usN) (usm Wait) (11) IR) C/1001 (R) Survey Tool Name 727.97 7.08 105.83 727.32 634.60 -2.95 16.09 5,980,86921 549578.32 2.93 16.29 GYD-GC-SS (1) 822.76 9.42 110.81 821.13 728.41 -7.30 28.97 5,980,864.95 549,591.22 2.58 29.86 GYD-GCS6(1) 918.24 13.43 112.18 914.70 821.98 -1426 46.55 5,980,858.10 549,608.85 4.21 48.67 GYD-GC-SS(1) 1,013.13 15.22 108.59 1,006.64 913.92 -22.39 68.56 5,980,850.11 549,630.91 2.11 72.07 GYD-GC-SS(1) 1053.75 15.47 107.89 1,045.81 953.09 -25.76 78.77 5,98,846.82 549,641.14 0.77 8261 MWD+IFR-AK-CAZ-SC(2) 1,148.68 16.41 106.03 1,13209 1,044.37 -33.35 103.70 5,950,839.39 549,666.12 1.13 108.87 MWD+iFR-AK-CAZ-SC (2) 1,243.42 19.32 105.82 1,227.25 1,134.53 4182 131.65 5,980,831.61 549,694.12 3.07 137.93 MWD+1FR-AK-CAZ-SC(2) 1,337.62 2178 105.66 1,31545 1,222.73 -50.28 163.48 5,983,822.85 549,726.00 2.61 171.00 MWD+IFR-AK-CAZ-SC(2) 1432.85 25.63 105.11 1,40263 1,309.91 50.43 200.39 5,950,812% 549,762.97 4.05 20927 MWD+IFR-AK-CAZ-SC(2) 1,527.33 2750 105.16 1,487.13 1,394.41 -71.46 241.17 5,980,802.20 549.80382 1.98 251.52 MWD+IFR-AK-CA -SC(2) 1,622.67 27.87 105.05 1,571.55 1,478.83 53.00 283.94 5,980,790.94 549,84666 0.39 29581 MWD+IFR-AK-CAZ-SC(2) 1,716.98 27.49 105.51 1,655.07 1,562.35 -94.55 32620 5,980,77967 549,888.99 046 339.62 MWD+1FR-AK-CAZ-SC(2) 1,761.12 29.73 105.06 1,693.82 1,601.10 -100.11 346.59 5,980,77424 549,909.42 5,10 360.75 MWD+IFR-AK-CAZ-SC(2) 1,847.78 32.77 104.94 1,767.90 1,675.18 -111.75 390.01 5,980,762.90 549,952.91 3.51 405.70 MWD -INC _ONLY (3) 1,856.00 33.00 104.93 1,774.80 1,682.08 -112.90 394.32 5,980,761.78 549,95723 2.84 410.16 NOT an Actual Survey 10 3/4" x 13412" 1,942.03 35.45 104.83 1,845.92 1,753.20 -125.32 441.08 5,980,749.66 550,004.07 2.84 458.54 MWD+IFR-AK-CAZSC(4) 2,036.72 40.41 100.55 1,920.60 1,827.88 -137.98 497.84 5,980,73238 550,060.91 5.92 51660 MWD+IFR-AK-CAZSC(4) 2,083.68 42.78 9721 1,955.72 1,863.00 -142.78 52864 5,980,732.79 550,091.73 892 547.53 MWD+IFR-AK-CAZ-SC(4) 2,131.92 44.58 94.53 1,990.61 1,897.89 -M.17 561.77 5,980,729.61 550,124.88 5.35 580.32 MWD+IFR-AK-CAZ-SC(4) 2,226.09 47.97 9160 2,055.70 1,962.98 -149.76 629.71 5,980,726.48 550,192.83 424 646.64 MWDAFR-AK-CAZ-SC(4) 2,320.66 51.46 91.16 2,116.84 2,024.12 -151.49 701.82 5,950,725.22 550,264.94 3.71 716.46 MWD+IFR-AK-CAZ-SC(4) 2,415.93 55.05 88.97 2,173.83 2,081.11 -151.54 778.14 5,950,725.68 550,341.26 4.19 789.87 MWD+IFR-AK-CAZ-SC(4) 2,51066 58.97 87.90 2,225.07 2,132.35 -149.37 857.04 5,950,728.37 550,420.14 4.27 865.16 MWD+IFR-AK-CAZ-SC(4) 2,604.98 62.26 88.02 2,271.64 2,178.92 -146.43 939.69 5,950,731.86 550,502.75 3.47 94383 MWD+IFR-AK-CAZ-SC(4) 2,700.24 6529 88.32 2,313.73 2,221.01 -143.70 1,025.09 5,98,735.15 550,58842 3.19 1,025.21 MWD+11FR-AKCAZSC(4) 2,794.05 69.97 88.07 2,349.43 2,256.71 -140.97 1,111.77 5,980,738.46 550,674.78 4.99 1,107.82 MWD+IFR-AK-CAZSC(4) 2,888.86 72.48 87.48 2,379.94 2,287.22 -137.48 1,201.46 5,980,742.54 550,764.44 2.71 1,193.12 MWDAFR-AK-CAZ-SC(4) 2,983.92 72.63 8868 2,408.44 2,315.72 -133.96 1,292.08 5,980,746.65 550,855.02 062 1,279.31 MWD+IFR-AK-CAZ-SC(4) 3,079.34 72.65 88.58 2,43691 2,344.19 -131.31 1,383.11 6,980,749.91 550,946.03 0.50 1,366.12 MWD+IFR-AK-CAZ-SC(4) 3,173.72 72.59 88.05 2.465.10 2,372.38 -128.66 1,473.14 5,950,753.15 551,036.03 0.54 1,451.98 MWD+IFR-AK-CAZ-SC(4) 3,268.70 72.55 88.43 2,493.55 2,400.83 -125.88 1,563.72 5,980,756.53 551,126.58 0.38 1,538.32 MWD+IFR-AKCAZSC(4) 3,363.10 73.00 8704 2,521.51 2,42819 -122.31 1,653.81 5.98O.7W 69 551,21864 1.48 1,623.99 MWD+IFR-AK-CAZSC(4) 3,457.24 72.55 88.56 2,549.38 2,456.66 -118.86 1,74366 5,980,764.74 551,306.45 1.61 1,709.45 MWD+IFR-AK-CAZ-SC(4) 3,551.19 72.62 8777 2,577.50 2,484.78 -115.99 1,833.26 5,950,76820 551,396.02 0.81 1,794.83 MWD+IFR-AK-CA7-SC(4) 3,646.78 72.62 87.29 2,606.05 2,513.34 -112.06 1,924.40 5,983,772.74 551,487.12 0.48 1,881.40 MWD+IFR-AK-CAZ-SC(4) 3,74113 72.68 8655 2,634.37 2,541.65 -107.19 2,014.90 5,980,778.20 551,577.58 0.75 1,967.09 MWD+IFR-AKCAZSC(4) 3,836.29 72.68 84.79 2,662.53 2,569.81 -100.37 2,104.91 5,980,78561 551.657.53 1.78 2,05179 MWD+IFR-AK-CAZSC(4) 3,930.34 72.53 83.26 2,69064 2,597.92 -91.03 2,194.17 5,950,79555 551,756.72 1.56 2,135.07 MWD+IFR-AK-CAZ-SC(4) 4,026.01 7265 83.40 2,719.26 2,626.54 -50.43 2,284.84 5,990,806.75 551,847.31 0.19 2,219.36 MWD+IFR-AK-CAZ-SC(4) 4,120.51 72.62 84.16 2.747.46 2,654.74 -70.66 2,374.50 5,980,817.11 551,936.90 0.77 2,302.91 MWD+IFR-AKCAZ-SC(4) 11/3/2017 11:27 30AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-111 Project. Kuparuk River Unit TVD Reference: 1 H-111 actual @ 92.72usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-111 actual @ 92.72usft (Doyon 142) Well: 1H-111 North Reference: True Walibore: 11-1-1111 Survey Calculation Method: Minimum Curvature Design: 11-1-111 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Easting DLS Section (usft) V) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Nam 4,214.82 72.60 86.35 2,775.65 2,682.93 53.21 2,464.19 5,980,825.15 552026.52 2.22 2,387.12 MWD+IFR-AK-CAZ-SC(4) 4,309.96 72.28 87.23 2,804.35 2,711.63 58.13 2,554.75 5,980,830.83 552,11704 0.94 2,472.82 MWD+IFR-AK-CAZ-SC(4) 4,403.96 72.20 87.11 2,833.03 2,740.31 -53.71 2,644.16 5,980,835.84 552,20641 0.15 2,557.59 MWD+IFR-AK-CAZSC(4) 4,497.93 72.32 87.08 2,861.66 2,768.94 49.18 2,733.55 5,980,840.97 55229576 0.13 2,692.31 MWD+IFR-AK-CAZ-SC(4) 4,593.57 72.24 85.88 2,890.77 2,798.05 -03.58 2,82447 5,980,847.16 552,386.64 1.20 2,728.22 MWD+IFR-AK-CAZ-SC(4) 4,688.43 72.13 84.83 2,919.79 2,827.07 -36.27 2,914.49 5,980,855.07 552,476.59 1.06 2,812.78 MWD+IFR-AK-CAZ-SC (4) 4,782.82 72.30 84.77 2,948.62 2,855.90 -28.12 3,004.00 5,980,863.80 552,566.03 0.19 2,89663 MWD+IFR-AK-CAZ-SC(4) 4,876.80 72.22 84.41 2,977.26 2,884.54 -1969 3,093.11 5,950,872.83 552,65508 0.37 2,98002 MWD+IFR-AK-CAZ-SC(4) 4,971.62 72.55 84.23 3,005.95 2,913.23 -10.74 3,183.04 5,980,882.37 552,744.94 0.39 3,064.05 MWD+IFR-AK-CAZ-SC(4) 5,066.97 72.38 85.04 3,030.68 2,941.96 -2.24 3,273.56 5,980,89147 552,835.39 0.83 3,148.77 MWD+IFR-AK-CAZ-SC(4) 5,160.74 72.29 WAS 3,063.14 2,970.42 4.62 3,362.64 5,980,898.92 552,924.42 1.13 3,232.56 MND+IFR-AK-CAZ-SC(4) 5,255.28 72.29 87.31 3,091.90 2,999.18 9.76 3,452.55 5,980,904.65 553,014.29 1.17 3,317.82 MWD+IFR-AK-CAZ-SC(4) 5,350.60 7229 8203 3,120.89 3,028.17 14.24 3,543.24 5,950,9D9,73 553,104.94 0.28 3,403.61 MWD+IFR-AK-CAZ-SC(4) 5,445.08 72.29 86.27 3,149.63 3,056.91 19.50 3,633.09 5,980,915.59 553,194.74 0.77 3,488.57 MWD+IFR-AK-CAZSC(4) 5,540.34 72.25 85.59 3,178.64 3,085.92 25.94 3,723.60 5,980,92263 553,285.20 0.68 3,57385 MWD+IFR-AK-CAZSC(4) 5,634.51 72.32 WAS 3,20728 3,114.56 32.93 3,813.04 5,980,930.20 553,374.57 0.13 3,657.94 MND+IFR-AK-CAZ-SC(4) 5,728.87 7151 86.14 3,235.79 3,143.07 39.50 3,902.75 5,980,937.37 553,464.23 0.70 3,742.41 MWD+IFR-AK-CAZ-SC(4) 5,824.40 72.47 87.05 3,264.53 3,171.81 44.91 3,993.69 5,950,943.38 553,555.12 0.91 3,828.39 MND+IFR-AK-CAZ-SC(4) 5,919.14 72.31 87.62 3,293.20 3,200.48 49.11 4,083.89 5,980,948.17 553,64529 0.60 3,913.98 MWD+IFR-AK-CAZ-SC(4) 6,012.99 72.33 86.90 3,321.70 3,228.98 53.38 4,173.20 5,980,95300 553,734.56 0.73 3,998.70 MWD+IFR-AK-CAZ-SC(4) 6,109.14 72.16 87.33 3,35102 3,258.30 57.99 4,264.66 5,980,95825 553,825.98 0.46 4,085.39 MWD+IFR-AK-CAZSC(4) 6,202.82 71.24 87.47 3,380.43 3,287.71 62.03 4,353.51 5,980,962.87 553,91479 0.99 4,169.73 MWD+IFR-AK-CAZ-SC(4) 6,297.38 72.10 90.23 3,410.18 3,317.46 63.82 4,443.24 5,980,96526 554,004.50 2.92 4,255.53 MWD+IFR-AK-CAZ-SC(4) 6,392.16 72.41 88.79 3,439.06 3,346.34 64.59 4,533.50 5,98,966.63 554,094.75 1.48 4,342.13 MWD+IFR-AK-CAZ-SC(4) 6,487.50 72.67 86.82 3,467.67 3,374.95 68.06 4,624.38 5,950,970.72 554,18559 1.99 4,428.57 MWD+IFR-AK-CAZ-SC(4) 6,582.78 72.31 85.09 3,496.34 3,40362 74.49 4,715.01 5,980,977.72 554,276.17 1.77 4,513.97 MWD+IFR-AK-CAZ-SC(4) 6,676.79 72.35 85.18 3,524.88 3,432.16 82.08 4,80427 5,980,98591 554,365.36 0.10 4,597.72 MWD+IFR-AK-CAZSC(4) 6,771.61 72.39 84.68 3,553.60 3,460.88 90.07 4,894.28 5,980,994.49 554,455.31 0.50 4,682.10 MND+IFR-AK-CAZ-SC (4) 6,866.28 72.34 80.26 3,582.28 3,489.56 98.76 4,984.08 5,981,00318 554,545.00 0.43 4,766.08 MND+IFR-AK-CAZ-SC (4) 6,960.93 69.19 8278 3,613.46 3,520.74 108.80 5,072.86 5,981,014.44 554,633.75 364 4,84870 MWDAFR-AK-CAZ-SG(4) 6,999.14 67.57 82.39 3,627.53 3,534.81 113.42 5,108.09 5,981,01925 554,668.94 4.34 4,881.31 MWD+IFR-AK-CAZSC(4) 7,054.92 65.07 81,69 3,649.93 3,557.21 120.49 5,158.67 5,981,026.66 554,719.47 4.63 4,928.03 MND+IFR-AK-CAZ-SC (4) 7,149.94 61.18 81.60 3,692.88 3,600.16 132.80 5,242.51 5,981,039.52 554,803.22 4.09 5,005.28 MND+IFR-AK-CAZ-SC(4) 7,184.27 59.52 82.27 3,709.86 3,617.14 136.99 5,272.05 5,981,043.91 554,832.73 5.12 5,032.54 MWD+IFR-AK-CAZ-SC(4) 7,243.75 57.44 8357 3,740.96 3,648.24 143.25 5,322.37 5,981,050.49 554,882.99 3.96 5,079.21 MWD+IFR-AK-CAZSC(4) 7,337.53 55.99 85.04 3,792.43 3,699.71 151.03 5,400.37 5,981,058.80 554,960.94 2.03 5,152.09 MND+IFR-AK-CAZ-SC(4) 7,432.70 54.31 84.32 3,846.81 3,754.09 158.27 5,478.13 5,981,066.55 555,038.64 1,87 5,224.89 MND+IFR-AK-CAZ-SC (4) 7,527.57 54.53 84.02 3,902.01 3,809.29 166.11 5,554.89 5,981,07489 555,115.34 0.35 5,296.56 MWD+IFR-AK-CAZ-SC(4) 7,622.06 54.56 85.06 3,956.82 3,864.10 173.42 5,631.51 5,981,082.71 555,191.90 0.91 5,368.24 MWD+IFR-AK-CAZSC(4) 7,71700 54.51 8581 4,011.90 3,919.18 17956 5,708.59 5,981,089.36 555,268.93 0.63 5,440.68 MND+IFR-AK-CAZSC(4) 11/32017 11:27:30AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-111 Project: Kuparuk River Unit TVD Reference: 1 H-111 actual @ 92.72usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1 H-111 actual @ 92.72usft (Doyon 142) Well: 1H-111 North Reference: True Wellbore: 1 H-111 Survey Calculation Method: Minimum Curvature Design: 1H.111 Database: OAKEDMP2 Survey MD Inc Axl TVD TVDSS (usR) (°) (1) luau) (ustt) 7,811.44 53.94 86.17 4,067.11 3,974.39 7,906.46 54.14 85.48 4,12291 4,030.19 8,000.80 54.21 85.29 4,178.13 4,085.41 8,056.00 54.21 8529 4,210.41 4,117.69 7" x 8-914" 8,066.00 54.21 85.29 4,216.26 4,123.54 201.01 5,990.68 5,981,11268 Map Map +N1S +EI -W Northing (usft) Wait) (it) 184.92 5,785.02 5,981,095.22 190.52 5,861.73 5,981,101.33 196.67 5,937.97 5,981,107.99 200.35 5,982.60 5,981,111.96 201.01 5,990.68 5,981,11268 Map Vertical Eastlng DLS Section (ft) ("/100) (ft) Survey Tool Name 555,345.32 0.68 5,51272 MWD+IFR-AK-CAZ-SC(4) 555,421.98 0.62 5,584.95 MWD+IFR-AK-CAZ-SC(4) 555,498.17 0.18 5,656.59 MM*IFR-AK-CAZ-SC (4) 555,542.77 0.00 5,69849 NOT an Actual Survey 555,550.85 0.00 5,706.09 PROJECTEDWTD Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. P] Yes ❑ No ! have checked to the best of my ability that the following data is correct: O Surface Coordinates 0 Declination & Convergence Q GRS Survey Corrections p Survey Tool Codes Brandon Tempnle Digitally signed by Brandon Temple SLB DE: M Date: 2017.11.03 11:35:49 -0000' Ie�.uA" Dgitelysigned bysen Tolman Client Representative: �6'd Date W17.1 10507;1157-000' Date. 1113117 11/3/2017 11:27:30AM Page 5 COMPASS 5000.14 Build 85 Loepp, Victoria T (DOA) From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Tuesday, January 02, 2018 10:09 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]KRU 1H-111(PTD 217-133) 10-407 Surface casing cement sx Attachments: 1H-111 Revised Surface Cement Detail Report.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, You are correct, the reported sacks were incorrectly reported. The correct volumes are 948 sacks of Lead (322.5 bbls) and 296 sacks of Tail (61 bbls) cement pumped. Please see revised Surface Cement Detail Report with the corrected sacks. Sorry for the incorrect information; it is always our honest effort and diligence to ensure proper and accurate reporting. Please let me know if you have any further questions. Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(o)1(307) 231-3550(m) From: Tolman, Ben V Sent: Tuesday, January 2, 2018 9:42 AM To:'Loepp, Victoria T (DOA)' <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 1H-111(PTD 217-133) 10-407 Surface casing cement sx Victoria, Good morning. Let me verify the paperwork and I'll get back with you this morning. Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(o)1(307) 231-3550(m) From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.eov] Sent: Tuesday, January 2, 2018 9:22 AM To: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Subject: [EXTERNAL]KRU 1H-111(PTD 217-133) 10-407 Surface casing cement sx Ben, On the 10-407 cementing record for the surface casing, the lead cement sx(168 sx) and tail cement sx(53 sx) do not seem to be correct. Please check this and send me revised numbers. Also revise the Cement Detail Report and resubmit. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(cDa laska.00V CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipfent(s(. It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoric.Loepp@alaska.gov - Cement Detail Report String: Conductor Job: DRILLING ORIGINAL, 10/20/2017 16:00 Cement Details Description Conductor Cementing StartDate 11/2/2016 1800 Cementing Entl Date 111212016 19:00 Wellbore Name 1 H-111 Comment Cement Stages Stage # t Description Conductor Cement Objective Top Depth (ftKB) 39.0 Bottom Depth (ftKB) 118.0 Full Return? No Vol Cement... I Top Plug? Btm Plug? No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Methotl Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid TypeFluid Conductor Cement Description Estimated Top (ftKB) 39.0 Est Btm (ftKB) 118.0 Amount (sacks) 6 Class Volume Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa-s) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 121412017 Cement Detail Report 1H-111 String: Surface Casing Cement Job: DRILLING ORIGINAL, 10/20/201716:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 10/23/2017 13:15 10/23/2017 16:30 11-1-111 Comment Cementers on line with 5 BBLS CW 100, PT and chart all surface lines to 4K PSI. Pump remaining 35 BBL of CW 100 @ 5 BPM 180 PSI 14% F/O, f/40.1 BBLS total. Chase with 76 BBLS of 10.5# using MP #2 @ 4 BPM 200 PSI. 13% F/O. Drop bottom plug chase with 322.5 BBLS 11# Lead cement @ 6 BPM, FCP = 130 PSI, 17% F/O, land casing with cement at shoe. UP WT = 122K, OWN WT = 114K. Pump 61 BBLS 15.8# Tail cement @ 5.8 BPM 210 PSI with 21 % F/O. Drop top plug with 10 BBLS water, swap to rig pump and displace cement at 6.7 BPM. for 1500 STKS. FCP = 560 PSI with 20% F/O. reduce to 3 BPM FCP = 400 PSI, 13% F/O. Bump plug at 1,592 STKS, increase pressure to 930 PSI and hold for 5 min. Bleed Pressure and check floats (GOOD). Cement in place at 16:16. 97 BBLS cement returned to surface. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Depth (flK8) Full Re b in? Vol Cement.. Top Plug? Bun Plug? Surface Casing Cement 1,865.1 No 97.0 Yes Yes O Pump Init (bourn... O Pump Final (bbl/... O Pump Avg (bull... P Pump Final (psiBump (psi) Reclp7 Stroke (ft) Rotated? Pipe RPM (rpm) 8 3 6 56950.0 #D.p1tt0hffPI Yes 0.00 No Tagged Depth (flK8) Tag Method ug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cementers on line with 5 BBLS CW 100, PT and chart all surface lines to 4K PSI. Pump remaining 35 BBL of CW 100 @ 5 BPM 180 PSI 14% F/O, f/40.1 BBLS total. Chase with 76 BBLS of 10.5# using MP #2 @ 4 BPM 200 PSI. 13% F/O. Drop bottom plug chase with 322.5 BBLS 11# LEad cement @ 6 BPM, FCP = 130 PSI, 17% F/O, land casing with cement at shoe. UP WT = 122K, DW N WT = 114K. Pmp 61 BBLS 15.8# Tail cement @ 5.8 BPM 210 PSI with 21 % F/O. Drop top plug with 10 BBLS water, swap to rig pump and displace cement at 6.7 BPM. for 1500 STKS. FCP = 560 PSI with 20% F/O. reduce to 3 BPM FCP = 400 PSI, 13% F/O. Bump plug at 1,592 STKS, increase pressure to 930 PSI and hold for 5 min. Bleed Pressure and check floats (GOOD). Cement in place at 16:16. 97 BBLS cement returned to surface. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bun (ftKB) Amount (sacks) Class Volume Pumped (bbl) Pre Flush 40 CW-100 Yield (W1s3ck) Mix H2O Ratio (gal/sa... Free Water 1%) Density (Ib/gal)Plastic Viscosity (Pars) Thickening Time (hr) CmprStr 1 (psi) 8.34 Additives Additive Type Concentration Con; Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Ban IRKS) Amount (sacks)Class Volume Pumped (bbl) Pre Flush 76 MudPushll Yield (WIsack) Mix H2O Ratio (gallsa... Free Water (Y.) Density (Ib/gal)Plastic Viscosity (Pars) Thickening Time (hr) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluitl Descnption Estimated Top (111(13) Est Btrn (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 40.0 1,285.0 948 ALC 322.5 Yield mft /sa;k) Mix H2O Rano (gal/sa... Free Water (%) Density(Ib/gal) Plastic Viscosity (Pars) Thickening Time (hr) CmprStr t (psi) 1.91 6.63 11.00 47.0 5.12 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.02 gal/sx Additive Type Concentration Conc Unit label Dispersant D230 0.7 gal/sx Fluid Fluid Type Fluid Description Estimated Top (ftKB)Est Bbn (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,285.0 1,285.0 296 G 61.0 Yield (WIsack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal)Plastic Viscosity (Pars) Thickening Time (hr) CmprStr t (psi) 1.16 5.12 15.80 130.0 5.07 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.05 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D255 0.35 %BWOC Page 1/1 Report Printed: 1/2/2018 Cement Detail Report 1H-111 String: Surface Casing Cement Job: DRILLING ORIGINAL, 10/20/2017 16:00 Description--'7nw,y �w,.7 ......,•�••e-••--^•- .._..__._.._..._ Surface Casing Cement 10/23/2017 13:15 10/23/2017 16:30 1H-111 Comment Cementers on line with 5 BBLS CW 100, PT and chart all surface lines to 4K PSI. Pump remaining 35 BBL of CW 100,0 5 BPM 180 PSI 14% F/O, f/40.1 BBLS total. Chase with 76 BELS of 10.5# using MP #2 @ 4 BPM 200 PSI. 13% F/O. Drop bottom plug chase with 322.5 BBLS 11# Lead cement @ 6 BPM, FCP = 130 PSI, 17% F/O, land casing with cement at shoe. UP WT = 122K, DWN Wi = 114K. Pump 61 BBLS 15.8# Tai /cement @ 5.8 BPM 210 PSI with 21% F/0. Drop top plug with 10 BELS water, swap to rig pump and displace cement at 6.7 BPM. for 1500 STKS. FCP = 5 PSI with 20% F/O. reduce to 3 BPM FCP = 400 PSI, 13% F/O. Bump plug at 1,592 STKS, increase pressure to 930 PSI and hold for 5 min. Bleed Pressu and check floats (GOOD). Cement in place at 16:16. 97 BBLS cement returned to surface. Cement Cementers on line with 5 BBLS CW 100, PT and ch4q all surface lines to 4K PSI. total. Chase with 76 BBLS of 10.5# using MP #2@ 4 M 200 PSI. 13% F/O. L 130 PSI, 17% F/O, land casing with cement at shoe. UP = 122K, DW \1 WT = Drop top plug with 10 BBLS water, swap to dg pump and dl lace cement at 6.7 E 400 PSI, 13% F/O. Bump plug at 1,592 STKS, increase pres re to 930 PSI and 16:16. 97 BBLS cement returned to surface. Flush I Pre Flush 1 Lead Cement 1.91 D046 1,865.11 No 1 97.0 Yes Yes Recip? Stroke (ft) Rotated Pipe RPM (rp I Yes 0.00 No 1p remaining 35 BBL of CW 100 @ 5 BPM 180 PSI 14% F/O, f/40.1 BBLS )ottom plug chase with 322.5 BBLS 11# LEad cement @ 6 BPM, FCP = C. Pmp 61 BBLS 15.8# Tail cement @ 5.8 BPM 210 PSI with 21 % F/O. for 1500 STKS. FCP = 560 PSI with 20% F/O. reduce to 3 BPM FCP = for 5 min. Bleed Pressure and check floats (GOOD). Cement in place at 11 Ell 5. Tail Cement 1.2i5.01 1,285.01 531 G 61.0 1 5.12 Antifoam D047 u.vo yevan Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unn label Fluid Loss Control D255 0.35 %BWOC Cement Detail Report 1H-111 String: Production Casing Cement Job: DRILLING ORIGINAL, 10120/201716:00 Cement Details Description Cementing Start Date End Cementing EnDate Wellbore Name Production Casing Cement 10/30/2017 04:00 10/30/2017 06:45 1H- 111 Comment Pump cement job as follows: SLB pump 5 bbls freshwater and pressure test lines to 600 / 4500 psi - good test. Pump 30 bbls 12.5ppg Mudpush at 3 bpm, ICP 260 psi, FCP 153 psi. Drop Davis Lynch anti -rotational bottom plug. Balch mix cement, cement wet at 04:48 his. SLB pump total of 140 bbls 15.8ppg Class G cement at 5.5 bpm, ICP 273 psi, FCP 146 psi. Drop Davis Lynch anti -rotational top plug. SLB pump 10 bbls freshwater at 6 bpm, 150 psi. Reciprocate pipe -13 ft, PUW 185k, SOW 82k. Displace cement using SLB pump truck with 9.Oppg NaCl brine w/ 3% KCI at 6 bpm, ICP 100 psi, FCP 1247 psi for 275 bbis. Drop rate to 4 bpm, ICP 1015 psi, FCP 1100 psi for 10 bbls. Drop rate to 2 bpm, ICP 890 psi, FCP 1034 psi. Did not observe plugs bumping. Pumped total of 296.9 bbls of brine (displacement plus 1/2 of shoetrack volume). Hold pressure for 6 minutes. Bleed off and check floats - floats holding. Cement in place c@ 06:35 hrs. Note: No downhole losses observed throughout cement job Cement Stages stags # 7 Description objective Top Depot (RKB) Bottom Depth (ftK8) Full ReWrn? Vol Cement... Top Plug? Btm Plug? Production Casing Cement production 4,324.0 8,056.3 Yes 0.0 Yes Yes Cement casing Q Pump InK (bbltm... Q Pump Final (bbl/... Q Pump Avg (bbil... P Pump Final (psi) P Plug Bump (psi)Rs Stroke (ft) Rotated? Pipe RPM (rpm) 6 2 6 1,034.0 I 0.0 Yes 13.00 No Tagged Depth (RKB) Tag Matron Depot Plug Drilled Out To (RKB) Drill out Diameter (in) 7,822.0 Drill Bit 7,888.0 61/8 Comment Pump cement job as follows: SLB pump 5 bbls freshwater and pressure test lines to 600 / 4500 psi - good test. Pump 30 bbls 12.5ppg Mudpush at 3 bpm, ICP 260 psi, FCP 153 psi. Drop Davis Lynch anti -rotational bottom plug. Batch mix cement, cement wet at 04:48 hrs. SLB pump total of 140 bbls 15.8ppg Class G cement at 5.5 bpm, ICP 273 psi, FCP 146 psi. Drop Davis Lynch anti -rotational top plug. SLB pump 10 bbls freshwater at 6 bpm, 150 psi. Reciprocate pipe -13 ft, PUW 185k, SOW 82k. Displace cement using SLB pump truck with 9.Oppg NaCl brine w/ 3% KCI at 6 bpm, ICP 100 psi, FCP 1247 psi for 275 bbls. Drop rate to 4 bpm, ICP 1015 psi, FCP 1100 psi for 10 bbls. Drop rate to 2 bpm, ICP 890 psi, FCP 1034 psi. Did not observe plugs bumping. Pumped total of 296.9 bbls of brine (displacement plus 1/2 of shoetrack volume). Hold pressure for 5 minutes. Bleed off and check floats - floats holding. Cement in place Q 06:35 hrs. Note: No downhole losses observed throughout cement job Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (RKB) Est Btm (ftK8) Amount (sacks) Class Volume Pumped (bbl) 1 Mud Push 3,525.0 4,324.0 30.0 Yield (ft'tsack) Mix H2O Ratio (gausa... Free water (%) Density (lblgal) Plastic Viscosity (Pa -s) Thickening Time (hr) I Cmprstr 1 (psi) 12.50 Additives Type Concentration Con; Unit label Additive Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est etm (ftK8) Amount (sacks) Class Volume Pumped (bbl) Cement 4,324.0 8,056.0 678 G 140.0 Yield (ft fsa;k) Mix H2O Ratio (gallsa... Free water (Ye) Density (lblgal)Plastic Viscosity (Pa•s) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.12 15.80 4.25 Additives Additive Type Concentration Conc Unit label D047 Antifoam 0.05 gaUsk Additive Type Concentmtion Conc Unit label D065 Dispersant 0.2 %BWOC Additive Type Concentration Cone Unit label D255 Fluid Loss 0.5 %BWOC Page 1/1 ReportPrinted: 12/4/2017 Acquisition System Maxwell 2017 SP3 Application Patch rsion 17.3.92069.3100 reline_Hotfix-RTDLIS-2017SP3_7.3.92363 Run Name Pass Objective Direction Top Bottom Start Stop DSC Mode Depth Shift Include USIT CBL Log[10]:Up Up LOG All depths are referenced to toolstring zero 2578.88 f Parallel Data 7875.08 f 31 -Oct -2017 01 -Nov -2017 OFF -8.00 ft No 10:37:48 PM 1:34:43 AM • • Company:ConocoPhillips Alaska, Inc. Well: 1H-111 Description:CBL VDL Format: Log ( Sonic CBL with VDL) 01 -Nov -2017 02:53:45 Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: �-BIEP -Bond Index Event Pips DSLT-BB TIME -1900 - Time Marked every 60.00 (s) CBL Amplitude (CBL) DSLT-BB 0 mV 100 Stuck Tool Indicator, Total (STIT) CBL Amplitude (CBL) DSLT-BB 0 mV 10 Gamma Ray (ECGR_EDTC) EDTC-B 0 ft 50 Good Bond (GOBO) 0 gAPI 150 Cable 0 mV 10 Transit Time for CBL (TT) DSLT-BB Tension (TENS) 400 us 200 0 Ibf 5000 Casing Collar Locator Amplitude (CCL) CAL-YA ....::........:... ....GoodBond from CBL to .. * " * .......... CBL Amplitude (Fluid Compensated) (CBLF) DSLT-B8 -19 1 Cable, Drag 0 mV 100 Min Amplitude Max Transit Time (Sliding Gate) (TTSL) DSLT-BB — — 400 us 200 Tool_Tot. Dreg CBL Amplitude (Sliding Gate) (CBSL) DSLT-BB 0 mV 100 Variable Density Log (VDL) DSLT-BB 200 us 1200 2520 2530 1 2540 2550 2560 2570 2590 2590 �Ililfiilill'� !�I i E I 10 E I c 04 4 `�3 150 lnalcacor, 0 mV 100 0 9API Total (STIT) Transit Time for CBL (TT) DSLT-BB 0 ry 50 CBL Amplitude (CBL) DSLT-BB Cable 0 u200 0 mV 10 40s Casing Collar Locator Amplitude (CCL) CAL-YA Tension_ _ Good Bond (GOBO) 1g 1 (TENS) 0 mV 10 Transit Time (Sliding Gate) (TTSL) DSLT-BB 0 Ib..f 5000 • • ' ' ' ' ' ' ' CBL to GOBO' •� •� •� •� •� 200::;.. ,GoodBond from : 400 us Cable Drag CBL Amplitude (Fluid Compensated) (CBLF) DSLT-BB ------------ TooL Tot. n mV 10C CBL mV DSLT-BB Variable Density Log (VDL) DSLT-BB us 12UI TIME -1900 - Time Marked every 60.00 (s) �- BIEP - Bond Index Event Pips DSLT-BB Description: CBL VDL Format: Log ( Sonic CBL with VDL) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: USIT CBL LOG: Parameters Flag nent Type Type Caliper M. in mV luau uai rum slowness rns casing uuter uiamerer luau's uc� Iu_urr USIT CBL LOG: Parameters Unit us RECEIVED Originated: API # 50-029.23136-00 50-029-23211-61 50-029-23581.00 50-103-20286-00 50.029-23223-61 50-029.23306-00 50-029-23278-00 50.029-23305-00 50-029.23505-00 511-029-23311-00 50-029-23251-00 Schlumberger Nov 17 2017 PTS- PRINTCENTER Perf Perf Tubing LDL (PROF (PROF (PROF IPROF PPROF-FSI IPROF (PROF 6411A Street AOGCC Anchorage, AK 99518 1 1 1 1 1 1 1 1 1 1 1 (907)273-1700 main (907)273-4760fax Delivered to: ;/ MakanaK Bender � I Natural Resources Technician 11 r Alaska 0:1 r, rj;7g Cnnsarvahon Cor,?r*'u ssicy; 1 21 7 133 28 798 TRANSMITiALDATE 7 TRANSMITTAL# DATA LOGGED lV /22/2072 K BENDER WELL NAME 1C-190 1EH12L2 1H-111 21--321 1E-1141-2 1J-127 1J-164 1J-184 2E-04 1J-156 1E-117 API # 50-029.23136-00 50-029-23211-61 50-029-23581.00 50-103-20286-00 50.029-23223-61 50-029.23306-00 50-029-23278-00 50.029-23305-00 50-029.23505-00 511-029-23311-00 50-029-23251-00 SERVICE # ORDER DUJJ-00007 DUJJ-00008 DSOS-00074 DSOS-00075 DUJJ-00009 DM87-00141 DM87-00142 DM87-00143 DUJJ-00010 DM87-00144 DM87-00145 FIELD NAME DESCRIPTION KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL DELIVERABLE WL WL WL WL WL WL WL WL WL WL Perf Perf Tubing LDL (PROF (PROF (PROF IPROF PPROF-FSI IPROF (PROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 2 -Nov -17 3 -Nov -17 4 -Nov -17 5 -Nov -17 7 -Nov -17 8 -Nov -17 9 -Nov -17 11 -Nov -17 11 -Nov -17 12 -Nov -17 13 -Nov -17 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 11 11 Transmittal Receipt A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the Xy �_ package have been verified to match the media noted above. Print Name Signature Date specific content of the CDs and/or hardcopy prints may or may Please send signed transmittal to CPAI via email or post. not have been verified for correctness or quality level at this Tom Osterkamp a co ocophillus com point. Tom Osterkamp, Conoco Phillips Alaska Inc. SLB Auditor 7(j r RECEIVED mnerger AOGCC Transmittal #: 08NOV17-SP01 Drilling & Measurements h DATA LOGGED Product Delivery ,t i,5/2011 K BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well Name: 1H-111 Date Dispatched: 8 -Nov -17 Service Order #: 17AKA0007 Dispatched By: Stephanie Pacillo Product Description Hardcopy Digital Copy Logging Date Color Log Prints: 4 Contents on CD 28 -Oct -17 VISION Service 2" MD x x 2" TVD x x 5" MD x x 5" TVD x x Digital Data N/A Contents on CD LAS/DLIS Data x Surveys 2 Contents on CD Directional Survey Nad27 x x Directional Survey Nad83 x x CD 1 Contents on CD Data: DLIS/ LAS x Graphics: PDF x Surveys: PDF/TXT x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkampto')conocophillips.com AlaskaPTSPrintCentercDslb.com Attn: Tom Osterkamp Attn: Stephanie Pacillo Received By: ta_a� 21 71 33 28779 RECEIVED NOV 0 9 2017 FINAL AOGCC NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H-111 1H-111 ConocoPhillips Definitive Survey 03 November, 2017 21 7133 28 779 'V'V'/ ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-111 Project: Kuparuk River Unit TVD Reference: 1 H-111 actual @ 92.72usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-111 actual @ 92.72usft (Doyon 142) Well: 1H-111 North Reference: True Wellbore: 1 H-111 Survey Calculation Method: Minimum Curvature Design: 1H-111 Database: OAKEDMP2 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 1H-111 Well Position +N/ -S 0.00 usft Northing: 5,980,872.05 usft Latitude: 70'21'30.691 N Version: 1.0 +EI -W 0.00 usft Easting: 549,562.21 usft Longitude: 149° 35' 50.828 W Position Uncertainty Depth From (TVD) 0.00 usft Wellhead Elevation: usft Ground Level: 54.10 usft Wellbore 1H-111 Magnetics Model Name Sample Data Declination Dip Angle Field Strength (°1 P) (nT) BGGM2017 11/15/2017 17.40 80.94 57,485 Design 1H-111 Date Audit Notes: From To Map Version: 1.0 Phase: ACTUAL Tie On Depth: 38.62 Vertical Section: Depth From (TVD) +N/ -S +EI -W Direction 1,013.13 1 H-111 Srvy 1 - SLB_GWD70 (1H-111) (usft) (usft) (usft) (1) 1,053.75 38.62 0.00 0.00 105.91 Survey Program Date From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 135.09 1,013.13 1 H-111 Srvy 1 - SLB_GWD70 (1H-111) GYD-GC-SS Gyrodata gyro single shots 10/21/2017 10:1 1,053.75 1,761A21H-111 Srvy 2 -SLB MWD_GMAG(1 H-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/22/2017101 1,847.78 1,847.781H-111 Srvy 3 -SLB MWD-Inc-Flller(1H MWD -INC -ONLY MWD -INC _ONLY -FILLER 10/25/2017 9:1< 1,942.03 8,000.801H-111 Srvy 4-SLB+MWD+GMAG(111- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 10/25/2017 9:2' Survey 11/3/2017 11:27:30AM Page 2 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 38.62 0.00 0.00 38.62 -54.10 0.00 0.00 5,980,872.05 549,562.21 0.00 0.00 UNDEFINED 135.09 0.48 185.35 135.09 42.37 -0.40 -0.04 5,980,871.65 549,562.17 0.50 0.07 GYD-GC-SS(1) 167.0 0.25 218.58 167.00 7428 -0.59 -0.09 5,980,871A6 549,562.12 0.95 0.07 NOT an Actual Survey 20" x 42" 182.39 0.22 253.80 182.39 89.67 -0.62 -0.14 5.960,871.42 549,562.07 0.95 0.03 GYD-GC-SS(1) 231.00 0.36 242.56 231.00 138.28 -0.72 -0.37 5,980,871.33 549,561.85 0.31 -0.16 GYD-GC-SS(1) 31238 0.00 216.69 312.78 220.06 -0.84 -0.60 5,980,87121 549,561.62 0.44 -0.34 GYD-GC-SS(1) 356.60 0.22 $45.02 356.80 264A8 -0.76 -0.62 5.98,871.29 549,561.60 0.50 -0.39 GYD-GC-SS(1) 449.01 1.05 6889 449.00 356.28 -0.28 0.12 5,980,871.77 549,562.33 1.14 0.20 GYD.GC.SS(1) 542.81 1.73 8549 542.77 450.05 0.14 2.34 5,980,872.21 549,564.54 0.84 2.21 GYD-GC-SS(1) 6WA2 4.40 103.48 635.94 543.22 -D.58 7.22 5,980,871.52 549,56943 3.01 7.10 GYD-GC-SS(1) 11/3/2017 11:27:30AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well iH-111 Project: Kuparuk River Unit TVD Reference: IH -111 actual @ 92.72usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-111 actual @ 92.72usft (Doyon 142) Well: 1H-111 North Reference: True Wellbore: 1 H-111 Survey Calculation Method: Minimum Curvature Design: 1 H-111 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS -NI-S +E1 -W Northing Easting DLS Section (usft) (I (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 727.97 7.08 105.83 727.32 634.60 -2.95 16.09 5,980,869.21 549,578.32 2.93 16.29 GYD-GC-SS(1) 822.76 9.42 110.81 821.13 72841 -7.30 28.97 5,980,864.95 549,591.22 2.58 29.86 GYD-GC-SS(1) 918.24 13.43 112.18 914.70 821.98 -1426 46.55 5,980,858.10 549,608.85 4.21 4867 GYD-GC-SS(1) 1,013.13 15.22 108.59 1,006.64 913.92 -22.39 68.56 5,980,850.11 549,630.91 2.11 72.07 GYD-GC-SS(1) 1,053.75 1547 107.89 1,045.81 953.09 -25.76 7877 5,980,846.82 549,641.14 0.77 82.81 MWD+IFR-AK-CAZ-SC(2) 1,148.68 16.41 106.03 1,137.09 1,044.37 -33.35 103,70 5,980,839.39 549,666.12 1.13 108.87 MWD+IFR-AK-CAZ-SC(2) 1,243.42 19.32 105.82 1,227.25 1,134.53 -41.32 131.65 5,98(3,83161 549,694.12 3.07 137.93 MM+IFR-AK-CAZ-SC(2) 1,337.62 21.78 105.66 1,315.45 1,22233 -50.28 163.48 5,980,82285 549,726.00 2.61 171.00 MWD+IFR-AK-CAZ-SC(2) 1,432.85 25.M 105.11 1,402.63 1,309.91 -6043 200.39 5,980,812.96 549,762.97 4.05 209.27 MM+IFR-AK-CAZ-SC(2) 1,527.33 27.50 105.16 1,487.13 1,394.41 -71.46 241.17 5,980,802.20 549803.82 1.98 251.52 MWD+IFR-AK-CAZ-SC(2) 1,622.67 27.87 105.05 1,571.55 1478.83 -83.00 283.94 5,980,790.94 549,846.% 0.39 295.81 MWD+IFR-AK-CAZ-SC(2) 1]16.98 2]49 105.51 1,655.07 1,562.35 -94.55 32620 5,980,779.67 549,888.99 046 339.62 MWD+IFR-AK-CAZ-SC(2) 1,761.12 29.73 105.06 1,693.82 1,601.10 -100.11 346.59 5,980,77424 549,909.42 5.10 360.75 MWD+IFR-AK-CAZ-SC(2) 1,847.76 32.77 104.94 1,767.90 1,675.18 -111.75 39001 5,980,762.90 549,952.91 3.51 405.70 MWD -INC -ONLY (3) 1,85600 33.00 104.93 1,774.80 1,682.08 -112.90 394.32 5,980,761.78 549,957.23 2.84 410.16 �T7R Actual $UIYl�r 10 314" X 13412" 1,942.03 35.45 104.83 1,845.92 1,753.20 -125.32 441.08 5,980,74966 550,004.07 2.84 458.54 MWD+IFR-AK-CAZ-SC(4) 2,036.72 4041 100.56 1,920.60 1,827.88 -13].98 497.84 5,980,73238 550,060.91 5.92 516.60 MWD+IFR-AK-CAZ-SC(4) 2,083.68 42.78 97.21 1,955.72 1,863,00 -142.78 52864 5,980,732.79 550,09113 6.92 547.53 MWD+IFR-AK-CAZ-SC(4) 2,131.92 44.58 94.53 1,99061 1,897.89 -146.17 561.77 5,980,72961 550,124.88 5.35 580.32 MWD+IFR-AK-CAZ-SC(4) 2,22609 47.97 91.60 2,055.70 1,962.98 -149.76 629.71 5,980,72646 550,192.83 4.24 646.54 MWD+IFR-AK-CAZ-SC(4) 2,320.66 5146 91.16 2,116.84 2,024.12 -151.49 701.82 5,980,72522 550,264.94 3.71 716.46 MWD+IFR-AK-CAZ-SC(4) 2,415.93 55.05 88.97 2,173.83 2,081.11 -151.54 778.14 5,980,725.68 550,341.26 4.19 789.87 MWD+lFR-AK-CAZ-SC (4) 2,510.06 58.97 87.90 2,225.07 2,132.35 -149.37 857.04 5.980,728.37 550,420.14 427 865.16 MWD+IFR-AK-CAZ-SC(4) 2,604.98 62.26 88.02 2,271.64 2,178.92 -146.43 939.69 5,980,731.86 550,502.75 347 943.83 MWD+IFR-AK-CAZ-SC(4) 2,700.24 6529 88.32 2,313.73 2,221.01 -143.70 1,D25.09 5,980,735.15 550,586.12 3.19 1025.21 MWD+IFR-AK-CAZ-SC(4) 2,794.05 69.97 88.07 2,34943 2,256.71 -140.97 1.111.77 5,980,73846 550,674.78 4.99 1,107.82 MWD+IFR-AK-CAZ-SC(4) 2,888.86 7248 8748 2,379.94 2,28722 -13748 1,20146 5,980,742.54 550,76444 2,71 1,193.12 MWD+IFR-AK-CAZ-SC(4) 2,983.92 72.63 88.08 2,408.44 2,315.72 -133.96 1,292.08 5,980,74665 550,855.02 062 1,279.31 MWD+IFR-AK-CAZ-SC(4) 3,079.34 7265 88.58 2.436.91 2,344.19 -131.31 1,383.11 5,980,749.91 550,946.03 0.50 1,366.12 MWD+1FR-AK-CAZ-SC(4) 3,17372 72.59 88.05 2,465.10 2,372.38 -128.66 1,473.14 5,980,753.15 551,036.03 0.54 1451.98 MWD+IFR-AK-CAZ-SC(4) 3,268.70 72.55 88.43 2,493.55 2,40083 -125.88 1,563.72 5,980,756.53 551,128.58 0.38 1,538.32 MWD+IFR-AK-CAZ-SC(4) 3,363.10 73.00 87.04 2,521.51 2,428.79 -122.31 1,653,61 5,980,760.69 551,216.64 1.48 1,623.99 MWD+IFR-AK-CAZ-SC (4) 3.45724 72.55 88,56 2.549.38 2,45686 -118.86 1,743.66 5,980,764.74 551,306.45 1.61 1,709.45 MWD+IFR-AK-CAZ-SC(4) 3,551.19 72.62 87.77 2,577.50 2,48438 -115.99 1,833.26 5,980,768.20 551396.02 0.81 1,794.83 MWD+IFR-AK-CAZ-SC 14) 3,646.78 72.62 87.29 2,606.06 2,513.34 -112.06 1,924.40 5,980,772.74 551,487.12 0.48 1,88140 MWD+IFR-AK-CAZ-SC(4) 3,741.73 7268 86.55 2,634.37 2,541.65 -107.19 2,01490 5,960.778.20 551,5]].58 0.75 1,967.09 MWD+IFR-AK-CAZ-SC(4) 3,836.29 72.68 84.79 2,662.53 2,569.81 -100.37 2,104.91 5,980.785.61 551,667.53 1 78 2,051.79 MWD+IFR-AK-CAZ-SC (4) 3,930.34 72.53 83.26 2,690.64 2,597.92 -91.03 2,194.17 5,980,795.55 551,75672 1.56 2,135.07 MWD+IFR-AK-CAZ-SC(4) 4,026.01 7266 83.40 2,71926 2,626.54 -80.43 2,284.84 5,980,806.75 551,847.31 0.19 2,219.35 MWD+IFR-AK-CAZ-SC(4) 4,120.51 72.62 84.18 2,747.46 2,654.74 -70.66 2,374.50 5,980,817.11 551,936.90 0.77 2,302.91 MWD+IFR-AK-CAZ-SC (4) 11/32017 11 27'30AM Page 3 COMPASS 5000. 14 Budd 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-111 Project: Kuparuk River Unit TVD Reference: 1 H-111 actual @ 92.72usfl (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-111 actual @ 92.72usfl (Doyon 142) Well: 1H-111 North Reference: True Wellbore: 1 H-111 Survey Calculation Method: Minimum Curvature Design: 1 H-111 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) 1°I 0 (usft) (usft) just) (usft) (t) (ft) (°1100') (ft) Survey Tool Name 4,214,82 7260 86.35 2,775.65 2,682.93 -63.21 2,464.19 5,980825.15 552.026.52 2.22 2,387.12 MWD+1FR-AK-CAZ-SC(4) 4,30996 72.28 87.23 2,804.35 2,711.63 -58.13 2,554.75 5,980,830.83 552,117.04 0.94 2,472.82 MWD+IFR-AK-CAZ-SC(4) 4,403.96 72.20 87.11 2,833.03 2,740.31 -53.71 2,644.16 5,980,835.84 552,20641 0.15 2,557.59 MWD+IFR-AK-CAZ-SC(4) 4,497.93 72.32 8708 2,861.65 2,768.94 -49.16 2.733.55 5,980,840.97 552,295.76 0.13 2,642.31 MW0+IFR-AK-CAZ-SC(4) 4,593.57 72.24 85.88 2,89037 2,798.05 -4358 2,824.47 5,980,847.16 552,38864 1.20 2,728.22 MWD+IFR-AK-CAZ-SC(4) 4,688.43 72.13 84.83 2,919.79 2.827.07 -36.27 2,91449 5,980,855.07 552,476.59 1.06 2,81278 MWD+IFR-AK-CAZ-SC(4) 4,782.82 72.30 84.77 2,94B 62 2,855.90 -28.12 3,004.00 5,980,863.80 552,566.03 0.19 2,89663 MWD+IFR-AK-CAZ-SC(4) 4,876.80 72.22 8441 2,977.26 2,884.54 -1969 3,093.11 5,9W,872 83 552,655.08 0.37 2,980.02 MWD+IFR-AK-CAZ-SC(4) 4,971.62 72.55 64.23 3,005.95 2,913.23 -10]4 3,183.04 5,980,882.37 552,74494 0.39 3,064.05 MWD+IFR-AK-CAZ-SC(4) 5,06697 72.38 85.04 3,034.68 2,941.96 -2.24 3,273.56 5,980,89147 552,835.39 0.83 3.148.77 MWD+1FR-AK-CAZ-SC(4) 5,160.74 72.29 86.15 3,063.14 2,970.42 4.62 3,362.64 5,980,898.92 552,92442 1.13 3,232.56 MWD+IFR-AK-CAZ-SC(4) 5,255.28 72.29 87.31 3,091.90 2,999.18 9,76 3.452.55 5,980,90465 553,01429 1.17 3,317.62 MWD+1FR-AK-CAZ-SC(4) 5,35060 72.29 87.03 3,12089 3,D28.17 14.24 3,543.24 5,980,909.73 553,104.94 0.28 3,403.61 MM+IFR-AK-CAZ-SC(4) 5.445.08 72.29 86.27 3,149.63 3.056.91 19.50 3,833.09 5,980,915.59 553,194.74 0.77 3,488.57 MWD+IFR-AK-CAZ-SC(4) 5,540.34 72.26 85.59 3,17864 3,085.92 25.94 3,723.60 5,980,922.63 553,28520 068 3,573.85 MWD+IFR-AK-CAZ-SC(4) 5.634.51 72.32 85.48 3,207.28 3,114.58 32.93 3,81304 5,980,93020 553,374.57 0.13 3,657.94 MWD+IFR-AK-CAZ-SC(4) 5,728.87 72.51 86.14 3,235.79 3,143,07 39.50 3,90275 5,980,937.37 553,464.23 0.70 3,742.41 MWD+1FR-AK-CAZ-SC(4) 5,824.40 72.47 87.05 3,264.53 3,171.81 44.91 3993.69 5,980,943.38 553,555.12 0.91 3,828.39 MWD+IFR-AK-CAZ-SC(4) 5,919.14 72.31 87.62 3,293.20 3,200.48 49.11 4,083.89 5,980948.17 553,845.29 0.60 3,913.98 MWD+IFR-AK-CAZ-SC (4) 6,012.99 72.33 86.90 3,321.70 3,228.98 53.38 4,173.20 5,980,95304 553,734.56 073 3,998.70 MWD+IFR-AK-CAZ.SC(4) 6,109.14 72.16 87.33 3,351.02 3,258.30 57.99 4,264.66 5,980,958.25 553,825.98 0.46 4,085.39 MWD+IFR-AK-CAZ-SC(4) 6,202.82 71.24 87.47 3,380.43 3,287.71 6203 4,353.51 5,980.962.87 553,914.79 0.99 4,169.73 MWD+IFR-AK-CAZ-SC(4) 6.29738 72.10 90.23 3,410.18 3,31746 63.82 4,443.24 5,980,965.26 554,004.50 2.92 4,255.53 MWD+IFR-AK-CAZ-SC(4) 6,392.16 72.41 88.79 3,439.06 3,346.34 64.59 4,533.50 5,980,966.63 554094.75 148 4,342.13 MWD+IFR-AK-CAZ-SC (4) 6,487.50 72.67 86.82 3,467.67 3.374.95 68.08 4624.38 5,98097072 554,185.59 1.99 4,428.57 MW1)+IFR-AK-CAZ-5C(4) 6,582.78 72.31 8509 3,496.34 3,40362 7449 4,715.01 5.980,977]2 554,276.17 177 4,513.97 MWD+IFR-AK-CAZ-SC(4) 6,676.79 72.35 85.18 3,524.88 3,432.16 82.08 4,804.27 5,980,98591 554,365.36 0.10 4,597.72 MWD+IFR-AK-CAZ-SC(4) 6,771.61 7239 8468 3,55360 3,450.88 9007 4,894.28 5,980,994.49 554,455.31 0.50 4,682.10 MW0+IFR-AK-CAZ-SC(4) 6,866.28 72.34 84.26 3,582.28 3489.56 9876 4,984.08 5,981.003.78 554,545.04 0,43 4,766.08 MWDHFR-AK-CAZ-SC(4) 6,96093 69.19 8278 3,613.46 3,520.74 108.84 5,072.86 5,981,014.44 554,633.75 3.64 4,848.70 MWD+IFR-AK-CAZ-SC(4) 6,999.14 67.57 82.39 3,627.53 3,534.81 11342 5,10809 5,981019.25 554,668.94 4.34 4,881.31 MWD+IFR-AK-CAZ-SC(4) 7,054.92 65.07 81.69 3,649.93 3,557.21 12049 5,15867 5,981,026.66 554,719.47 463 4,928.03 MWD+IFR-AK-CAZ-SC(4) 7,149.94 61.16 81.60 3,692.88 3,600.16 132.80 5,242.51 5,981,039.52 554,803.22 4.09 5,00528 MWD+IFR-AK-CAZ-SC(4) 7,184.27 59.52 82.27 3,709.86 3,617.14 136.99 5,272.05 5,981,043.91 554,832.73 5.12 5,032.54 MWD+IFR-AK-CAZ-SC (4) 7.243.75 57.44 83.57 3,740.96 3,648.24 143.25 5,322.37 5,981,050.49 554,882.99 3.96 5,079.21 MWD+IFR-AK-CAZ-SC (4) 7,337.53 55.99 85.04 3,79243 3,699.71 151.03 5,400.37 5,981,058.80 554,960.94 2.03 5,152.09 MWD+IFR-AK-CAZ-SC(4) 7,432.70 54.31 84.32 3,846.81 3,754.09 15827 5,478.13 5,981,066.55 555,03864 1.87 5,224.89 MWD+IFR-AK-CAZ-SC(4) 7,527.57 54.53 84.02 3,902.01 3,809.29 166.11 5,554.89 5,981,074.89 555,115.34 0.35 5,256.56 MWD+IFR-AK-CAZ-SC(4) 7,622.06 54.56 85.08 3,956.82 3,864.10 17342 5,631.51 5,981,082.71 555,191.90 0.91 5,36824 MWD+IFR-AK-CAZ-SC(4) 7,717.00 54.51 85.81 4,011.90 3,919.18 179.56 5,708.59 5,981,089.36 555,268.93 0.63 5,44068 MWD+IFR-AK-CAZ-SC(4) 1143/2017 11:27:30AM Page 4 COMPASS 5000.14 Build 85 I Conocolphillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-111 Project: Kupamk River Unit TVD Reference: 1 H-111 actual @ 92.72usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-111 actual @ 92.72usft (Doyon 142) Well: 1H-111 North Reference: True Wellbore: 1 H-111 Survey Calculation Method: Minimum Curvature Design: 1HA11 Database: OAKEDMP2 Survey MD Inc AN TVD TVDSS (usft) (*) 11 (usft) (usft) 7811.44 53.94 86.17 4,067.11 3,974.39 7,906.46 54.14 85.48 4,122.91 4,030.19 8,000.80 54.21 8529 4,178.13 4,085.41 8,055.00 54.21 85.29 4,21041 4,117.69 7" x 8-314" 8,066.00 54.21 85.29 4,216.26 4,123.54 Map +N/ -S +EI -W Northing (usft) (usft) (ft) 184.92 5.785.02 5,981,095.22 190.52 5,861.73 5,981,10133 196.67 5,937.97 5,981,107.99 200.35 5,98260 5,981,11196 201.01 5,990.68 5,981,112.68 Map Vertical Easting DLS Section (ft) r1loo') (ft) Survey Tool Name 555,345.32 0.68 5,512.72 MWD+IFR-AK-CAZ-SC (4) 555,421.98 062 5,584.95 MWD+IFR-AK-CAZ-SC(4) 555,498.17 0.18 5,656.59 MWD+IFR-AK-CAZSC(4) 555,542.77 0.00 5,69849 NOT anAl:Wal$Yrvy 555,550.85 0.00 5,706.09 PROJECTED to TO 111312017 11:27:30AM Page 5 COMPASS 5000.14 Build 65 Final Definitive Survey Verified and Signed -off All targets andlor 14'ell position objectives have been achieved. rd Yes ❑ No I have checked to the best of my ability that the following data is correct: O Surface Coordinates p Declination & Convergence O GRS Survey Corrections p-1 Survey Tool Codes Digitally signed Brandon Temple Brandon Temple SLB DE: 1 Date: 2017.11.03 11:35:49 -08'00' Client Representative: %.,.AN Dg Bally198edby Ban Tolman b Data 7017.1,O5o7"s7°a°°' Date. 1113117 111312017 11:27:30AM Page 5 COMPASS 5000.14 Build 65 RECEIVED NOV 0 9 2017 FINAL AOGCC ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad IH -111 1H-111 NAD 83 ConocoPhillips Definitive Survey Report 03 November, 2017 21 7133 28 779 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: 1H-111 Wellbore: 1 H-111 Design: 1H-111 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: Norm Reference: Survey Calculation Method; Database: Well 11-1-111 1H-111 actual @ 92.72usft (Doyon 142) 11-1-111 actual @ 92.72usft (Doyon 142) True Minimum Curvature OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 1H-111 Audit Notes: Well Position +N/ -S 0.00 usft Northing: 5,980,623.86 usft Latitude: 70" 21'29.645 N ACTUAL +E/ -W 0.00 usft Easting: 1,689,593.83 usft Longitude: 149° 36'2o44 W Position Uncertainty Direction 0.00 usft Wellhead Elevation: usft Ground Level: 54.10 usft Wellbore iH-111 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1°) (9 OT) BGGM2017 11/15/2017 17.39 80.94 57,485 Design 1H-111 Date 11/3/2017 Audit Notes: To Map Map Version: 1.0 Phase: ACTUAL Tie On Depth: 38.62 Vertical Section: Depth From (TVD) +N/ -S +EI -W Direction 1,053.75 (usft) (usft) (usft) PI 1,847.78 38.62 0.00 0.00 105.91 Survey Program Date 11/3/2017 From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 135.09 1.013.131H-111 Sivy1-SLB GWD70(111-111) GYD-GC-SS Gyrodata gyro single shots 10/21/201710:1 1,053.75 1,761.121H-111 Srvy 2- SLB_MWD_GMAG(1 H-1 MWD-IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC 10/22/201710:1• 1,847.78 1,847.781H-111 Srvy 3 -SLB MWD-InoFiller(1H MWD -INC -ONLY MWD -INC -ONLY -FILLER 10/25/2017 9:1f 1,942.03 8,000.801H-111 Srvy4-SLB+MWD+GMAG(1H- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/25/2017 9:2i Survey 11/3/2017 10: 12:59AM Page 2 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +EI -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3862 0.00 0.00 3862 -54.10 0.00 0.00 5.980,623 85 1,689,593.83 0.00 000 UNDEFINED 135.09 0.48 185.35 135.09 42.37 -0.40 -004 5,98,62346 1,689,59360 0.50 0.07 GYD-GC-SS(1) 167.00 0.25 218.58 16].00 74.28 -0.59 -009 5,98082327 1,689,593.74 0.95 007 NOT an Actual Survey 20" X 42" 182.39 0.22 253.80 182.39 89.67 -062 4)14 5,980,623.24 1,669,59369 0.95 0.03 GYD-GC-SS(1) 231.00 0.36 242.56 231.00 13828 -0.72 -0.37 5,980,623.14 1,689,593.47 0.31 -0.16 GYD-GC-SS(1) 312.78 0.00 216.69 31278 220.06 -0.84 -0.60 5,980,623.02 1,689,593.24 0.44 -0.34 GYD-GC-55(1) 356.80 0.22 345.02 356.80 264.08 -0.76 -0.62 5,980,623.10 1,689,59322 0.50 4139 GYD-GC-SS(1) 449.01 1.05 68.69 449.00 356.28 -0.28 0.12 5,980,623.58 1.689,593.96 1.14 0.20 GYD-GC-55(1) 542.81 1.73 85.49 54277 450.05 0.14 2.34 5,980,624.02 1,689.596.17 084 2.21 GYD-GC-SS(1) 636.12 4.40 103.48 635.94 543.22 458 7.22 5,980,623.33 1,689,601.06 3.01 7.10 GYD-GC-S$(1) 11/3/2017 10: 12:59AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupi Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1 H Pad MD Reference: Well: 1 H-111 North Reference: Wellbore: 1 H-111 Survey Calculation Method: Design: 1H-111 Database: Well 1H-111 1 H-111 actual @ 92.72usft (Doyon 142) 1 H-111 actual @ 92.72usft (Doyon 142) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc AN TVD TVDSS -NI-S +E/ -W Northing Easting DLS Section (usft) (1 (') (usft) (usft) (usi (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 727.97 7.08 105.83 727.32 634,60 -2.95 16.09 5,980.621.02 1,689,60995 2.93 16.29 GYD-GC-SS(1) 82276 9.42 110.81 821.13 72841 -780 28.97 5,980,616.76 1689,622.85 2.58 29.86 GYD-GC-SS(1) 918.24 13.43 112.18 914.70 821.98 -1426 46.55 5,980,609.91 1,689,640.47 4.21 48.67 GYD-GC-SS(1) 1.013.13 1522 108.59 100664 91392 -22.39 68.56 5.980.601.92 1,689,662.53 2.11 7207.GYD-GC-SS(1) 1,053.75 1547 10T89 1,045.81 953.09 -25.76 7837 5,980,598.63 1689,67276 0.77 82.81 MWD+IFR-AK-CAZ-SC(2) 1.14868 16.41 106.03 113709 1,044.37 -33.35 103,70 5,980,59120 1,6B9,69774 1.13 108.87 MWD+IFR-AK-CAZ-SC(2) 1,243.42 1932 105.82 1,227.25 1.134.53 -41.32 131.65 5,980,58341 1.689,725 74 3.07 137.93 MWD+IFR-AK-CAZ-SC(2) 1,33762 2178 105.66 1,31545 1,222.73 -5028 163.48 5,980,57466 1,689,757.62 2.61 171.00 MWD+IFR-AK-CAZ-SC(2) 1,43285 25.63 105.11 1,402.63 1,309.91 -60.43 200.39 5,980,56416 168979459 4.05 209.27 MWD+IFR-AK-CAZ-SC(2) 1,52733 27.07 105.16 148713 1,394.41 -7146 241.17 5,980,55399 1,689,835.44 1.98 251.52 MWD+IFR-AK-CAZ-SC(2) 1,62267 27.87 105.05 1,571.55 1478.83 -83.00 283.94 5,980,542.73 1,689,878.28 0.39 29581 MWD+IFR-AK-CAZ-SC(2) 171898 27.49 105.51 1,655.07 1,562.35 -94.55 326.20 5,980,53147 1,689,92061 046 33962 MWD+IFR-AK-CAZ-SC(2) 1,761.12 2973 10506 1,693.82 1601.10 -100.11 346.59 5,980,526.03 1,689,941.03 5.10 36075 MWD+IFR-AK-CAZ-SC(2) 1.84778 3277 104.94 176790 1,675.18 -11175 390.01 5,980,51469 1,689,98453 3.51 405.70 MWD-INC_ONLY(3) 1,856.00 33.00 104.93 1,774.80 1 682cil -112.90 394.32 5,980,513.57 1,689,986.B5 2.84 410.15 NOT an Actual Survey 10 314" x 13-112" 1942.03 3545 104.83 1,845.92 1,753.20 -12532 441.08 5.980,501.45 1,690,035.69 284 45B.54 MWD+IFR-AK-CAZ-SC(4) 2,03672 40.41 100.56 1,920.60 1,827.88 -137.98 49784 5.98,489.16 1,690,09252 5.92 516.60 MWD+IFR-AK-CAZ-SC(4) 2,083.68 42.78 9721 1,95572 1,863.00 -14278 528.64 5,96048457 1,60,123.34 6.92 547.53 MWD+IFR-AK-CAZ-SC(4) 2,131.92 44.58 94.53 1,990.61 1,897.89 -146.17 561.77 5,9B0,48140 1,690,156.50 5.35 580.32 MWD+IFR-AK-CAZ-SC(4) 2226.09 47.97 91.60 2,055.70 1,962.98 -149.76 629.71 5,980,47825 1,69,22445 424 646.64 MWD+IFR-AK-CAZ-SC(4) 2,320.66 51,46 91.16 2,116.64 2,024.12 -151.49 701.82 5,980,477.00 1,690,296.56 371 716.46 MWD+IFR-AK-CAZ-SC(4) 2,415.93 55.05 88.97 2,17383 2,081.11 -151.54 778.14 5,980,477.45 1,690,372.87 4.19 789.87 MWD+IFR-AK-CAZ-SC(4) 2,510.06 58.97 87.90 2,225.07 2,132.35 -149.37 857.04 5,980,480.14 1,690.45175 4.27 865.16 MWD+IFR-AK-CAZ-SG(4) 2,604.98 62.26 88.02 2,271.64 2,178.92 -146.43 939.69 5,980.483.62 1,690,534.37 3.47 943.83 MWD+IFR-AK-CAZ-SC (4) 2,700.24 65.29 88.32 2,313.73 2,221.01 -143.70 1,02509 5,980,486.91 1,690,619.74 3.19 1.02521 MWD+IFR-AK-CAZ-SC(4) 2,79405 69.97 88.07 2,349.43 2.256.71 -140.97 1,11177 5,980,490.21 1,690,70640 4.99 1,107.82 MWD+IFR-AK-CAZ-SC(4) 2,888.86 72.48 87.48 2,379.94 2,287.22 -13748 1,201.46 5,980,494.29 1,690,796.05 271 1,193.12 MWD+IFR-AK-CAZ-SC (4) 2,983.92 72.63 88.08 2,408.44 2.31572 -133.96 1292.08 5,980,49840 1,60,886.64 0.62 1,279.31 MWD+IFR-AK-CAZ-SC(4) 3,079.34 72.65 88.58 2,436.91 2,344.19 -13131 1,383.11 5,980,50165 1,60,977.64 0.50 1,366.12 MWD+IFR-AK-CAZ-SC(4) 3,173.72 72.59 8805 2,465.10 2,372.38 .128.66 1,473.14 5,980,504.89 1,691067.65 0.54 1,45198 MWD+IFR-AK-CAZ-SC(4) 3,268.70 72.55 88.43 2,493.55 2,400.83 -12588 1,56372 5,980,50826 1,691,158.19 038 1,538.32 MWD+IFR-AK-CAZ-SG(4) 3.363.10 73.00 87.04 2,521.51 2,428.79 -122.31 1,653.81 5,980,51242 1691,248.25 1.48 1,623.99 MWD+IFR-AK-CAZ-SC(4) 3,457.24 72.55 88.56 2549.38 2,456.66 -118.86 1,74366 5,980,51846 1,691,33807 161 1,709.45 MWD+IFR-AK-CAZ-SC(4) 3,551.19 72.62 87.77 2,577.50 248478 -11599 1,833.26 5,980.519.92 1,691,427.63 0.81 1,794.83 MWD+IFR-AK-CAZ-SC(4) 3,646.78 72.62 87.29 2,606.06 2,513.34 -112.06 1,924.40 5,980,524.45 1,691,51874 0,48 1,881.40 MWD+IFR-AK-CAZ-SC(4) 3,741.73 72.6B 86.55 2.634.37 2,541.65 -107.19 2,014.90 5,980,529.91 1,691,609.19 0.75 1,967.09 MWD+IFR-AK-CAZ-SC (4) 3,836.29 72.68 8479 2,662.53 2,569.81 -100.37 2,104.91 5,980,537.32 1,691,699.15 178 2,051.79 MWD+IFR-AK-CAZ-SC(4) 3,930.34 72.53 83.26 2.690.64 2,597.92 -9103 2,194.17 5,980,547.24 1,691,788.33 1.56 2,135.07 MWD+IFR-AK-CAZ-SC(4) 4,026.01 72.66 8340 2,719.26 2,626.54 -80.43 2,284.84 5,980,55844 1,691,878.93 0.19 2,219.36 MWD+IFR-AK-CAZ-SC(4) 4.120.51 7262 84.16 2,74746 2,654.74 -70.66 2,374.50 5,980,56880 1,691,968.52 0.77 2,302.91 MWD+IFR-AK-CAZ-SC(4) 111312017 10.12.59AM Page 3 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: 1H-111 Wellbore: 1 H-111 Design: 1H-111 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 11-1-111 1H-111 actual @ 92.72usft (Doyon 142) 1H-111 actual @ 92.72usft (Doyon 142) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section Wall (I C) (usft) (usft) (usft) (usft) (ft) (ft) (-/100-) (ft) Survey Tool Name 4,21482 7260 86.35 2,775.65 2,68293 -63.21 2,464.19 5,980,576.83 1,692,058.14 2.22 2,387.12 MWD+IFR-AK-CAZ-SC(4) 4,309.96 72.28 87.23 2,804.35 2,71163 -58.13 2,554.75 5.980582.51 1.692,148.66 0.94 2,472,82 MWD+IFR-AK-CAZ-SC(4) 403.96 72.20 87.11 2,833.03 2,740.31 -53.71 2,644.16 5.960,58751 1,692,238.03 0.15 2,557.59 MWD+IFR-AK-CAZ-SC(4) 4,49793 72.32 87.08 2,86166 2,768.94 49.18 2,733.55 5,980,592.64 1.692 327,38 0.13 2,642.31 MWD+IFR-AK-CAZ-SC(4) 4,593.57 72.24 8588 2,890.77 2.798.05 43.58 2,824.47 5,980,598.83 1,692,418.26 120 2,728.22 MWD+IFR-AK-CAZ-SC(4) 4,688.43 72.13 84.83 2,919.79 2,827.07 -3627 2,914.49 5.980.60673 1,692,508.21 1.06 2,81278 MWD+IFR-AK-CAZ-SC(4) 4,782.82 72.30 84.77 2,948.62 2,855.90 -28.12 3,004.00 5,980.61546 1,692,59766 0.19 2,896.63 MWD+IFR-AK-CAZ-SC(4) 4,876.80 72.22 8441 2,977.26 2,884.54 -1969 3,093.11 5,980,624.48 1,692,686.70 0.37 2,980.02 MWD+1FR-AK-CAZ-SC(4) 4,97162 72.55 84.23 3,005.95 2,913.23 -10.74 3,183.04 5,980,63402 1,692,776.56 039 3,064.05 MWD+IFR-AK-CAZ-SC(4) 5,066.97 72.38 85.04 3,034.68 2,941.96 -2.24 3,273.56 5,980,643.11 1,692,86702 0.83 3,148.77 MWD+IFR-AK-CAZ-SC(4) 5,16074 72.29 86.15 3,063.14 2.970.42 462 3,362.64 5,980,650.56 1,692,956.05 1.13 3,232.56 MWD+IFR-AK-CAZ-SC(4) 5,255.28 72.29 87.31 3,091.90 2,999.18 9]6 3,452.55 5,980,656.29 1,693,045.91 1.17 3317.62 MWD+IFR-AK-CAZ-SC(4) 5,350.60 72.29 8703 3,120.89 3,028.17 14.24 3,543.24 5,980,661.36 1,693,136.56 0.28 3.403.61 MWD+IFR-AK-CAZ-SC(4) 5,445.08 72.29 86.27 3,149.63 3,055.91 19.50 3,633.09 5,980,657.21 1,693,22637 0.77 3,488.57 MWD+IFR-AK-C4Z-SC(4) 5,540.34 72.26 85.59 3,178.64 3,085.92 25.94 3,723.60 5,980.674.25 1,693,316.82 068 3,573.85 MWD+IFR-AK-CAZ-SC(4) 5,634.51 72.32 85.48 3,207.28 3,114.56 3293 3,813.04 5,980,681.82 1,69340620 0.13 3,65794 MWD+IFR-AK-CAZ-SC(4) 5,72887 72.51 86.14 3,235.79 3,143.07 39.50 3,902.75 5,980,688.98 1,693.495.86 070 3,742.41 MWD+IFR-AK-CAZ-SC(4) 5,824.40 7247 87.05 3,264.53 3,171.81 44.91 3,993.69 5,98,694.98 1,693,58635 0.91 3,82839 MWD+IFR-AK-CAZ-SC(4) 5.919.14 72.31 87.62 3,293.20 3.200.48 49.11 4,083.89 5,980,699.77 1,693,676.91 0.60 3,913.98 AM+IFR-AK-CAZ-SC(4) 6,012.99 7233 86.90 3,32170 3,228.98 53.38 4,173.20 5,980,704.63 1,693,766.19 073 3,998.70 MWD+IFR-AK-CAZ-SC(4) 6,109.14 72.16 87.33 3,351.02 3,258.30 57.99 4,264.66 5,960,70884 1,693,857.60 0.46 4,085.39 MWD+IFR-AK-CAZ-SC (4) 6,202.82 ]1.24 8747 3,380.43 3,287.71 6203. 4,35351 5,980,71446 1,693,946.42 0.99 4,169.73 MWD+IFR-AK-CAZ-SC(4) 6,297.38 72.10 90.23 3,410.18 3,317.46 6382 4,443.24 5980,716.85 1,694,036.13 2.92 4,255.53 MWD+IFR-AK-CAZ-SC(4) 6,392.16 7241 88.79 3,439.06 3,346.34 64.59 4,533.50 5,980,71821 1,694126.37 1.48 4,342.13 MWD+IFR-AK-CAZ-SC(4) 6,487.50 72.67 66.82 3,46767 3,374.95 68.08 4,624.38 5,980722.29 1,694.21722 1.99 4,428.57 MWD+IFR-AK-CAZ-SC(4) 6,582.78 72.31 8509 3,496.34 3,40362 74.49 471501 5,980729.29 1.694,307.80 1 7 4,513.97 MWD+IFR-AK-CAZ-SC(4) 6,676.79 7235 85.18 3,524.88 3,432.16 8208 4,804.27 5,980,737.48 1694,396.99 0.10 4,597.72 MWD+IFR-AK-CAZ-SC(4) 6,771.61 72.39 8468 3,553.60 3,46088 90.07 4,894.28 5,980,74605 1694,486.94 0.50 4,682.10 MWD+IFR-AK-CAZ-SC(4) 6,866.28 7234 84.26 3,582.28 3,489.56 9876 4,98408 5,980,75533 1,894,57667 043 4,766.08 MWD+IFR-AK-CAZ-SC (4) 6,960.93 69.19 82.78 3,613.46 3,520.74 10864 5,072.86 5,980,76599 1,694,66538 3.64 4,648.70 MWD+IFR-AK-CAZ-SC(4) 6,999.14 87.57 82.39 3,627.53 3,53481 113.42 5,10809 5,980,770.80 1694,700.57 4.34 4,881.31 MWD+IFR-AK-CAZ-SC(4) 7,054.92 65.07 81.69 3,649.93 3,55721 12049 5,15867 5,980,778.21 1,694,751.10 4.63 4.92803 MWD+IFR-AK-CAZ-SC(4) 7,149.94 61.18 81.60 3,692.88 3,600.16 132.80 5,242.51 5,980,791.07 1,694,83485 4.09 5,005.28 MWD+IFR-AK-CAZ-SC(4) 7,18427 59.52 82.27 3,709.86 3,617.14 IM99 5,272.05 5,980795.45 1,694,864.36 5.12 5.032.54 MWD+IFR-AK-CAZ-SC(4) 7,243.75 57.44 83.57 3)40.96 3,648.24 143.25 5,322.37 5,980,602.03 1,694,914.63 3% 5,079.21 MWD+IFR-AK-CAZ-SC 14) 7,337.53 55.99 85.04 3,792.43 3,699.71 151.03 5,400.37 5,980,810.33 1,694,992.57 203 5,152.09 MWD+IFR-AK-CAZ-SC 141 7,43270 54.31 8432 3,846.81 3,754.09 15827 5,478.13 5,980.81808 1,695,070.27 1.07 5,224.89 MWD+IFR-AK-CAZ-SC(4) 7,527.57 54.53 84.02 3,902.01 3,809.29 166.11 5,554.89 5,980,826.42 1,695,146.97 0.35 5,296.55 MWD+IFR-AK-CAZ-SC (4) 7,622.06 54.56 8508 3,956.82 3,864.10 17342 5,631.51 5,980,834.23 1,695,22353 091 5,36824 MWD+IFR-AK-CAZ-SC(4) 7,717.00 54.51 8581 4,011.90 3,919.18 179.56 5,708.59 5,980,840.88 1,695,300.56 0.83 5,440.68 MWD+IFR-AK-CAZ-SC(4) 11/3/2017 10:12,59AM Page 4 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: 1H-111 Wellbore: 1H-111 Design: 1H-111 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1H-111 1H-111 actual @ 92.72usft (Doyon 142) 1H-111 actual @ 92.72usft (Doyon 142) True Minimum Curvature OAKEDMP2 Vertical Section (ft) Survey Tool Name 5,512.72 MWD+IFR-AK-CAZ-SC Eli 5.584.95 MW1D+IFR-AK-CAZ-SC(4) 5,656.59 MW -IFR-AK-CAZ-SC(4) Final Definitive Survey Verified and Signed -off All targets andlor Weis position objectives have been achieved. (] Yes No 5,698.49 NOT an Actual Survey 5,706.09 PROJECTED to TD I have checked to the best of my ability that the following data is correct f7 Surface Coordinates p Declination & Convergence E] GRS Survey Corrections E] Survey Tool Codes SLB DE. Brandon Temple Date: 017,1 ed 11:35Brandon-OV001 le Date: 2017.11.03 11:35:49 -08'00' �elMAM DiKJK*s9nedby Ban Tdman Client Representative: 4aDMe Ml7.I lM07:1157419W Date: 1113/17 11!./2017 10:12, 59AM Page 5 COMPASS 5000.14 Build 65 Map Map MD Inc Azi TVD TVDSS +NlS +E/ -W Northing Basting DLS tysft) (") (1 (usft) (usft) just) lust) (ft) (ft) (-1100•) 7,811.44 53.94 86.17 4,067.11 3,974.39 184.92 5.785.02 5,980,846.74 1,695,376.95 0.68 7,906.46 54.14 85.48 4,122.91 4,030.19 190.52 5,861.73 5,980,85284 1,695,453.61 0.62 8,000.80 54.21 85.29 4,178.13 4,065.41 196.67 5.937.97 5,9W,859 49 1,695,529.81 0.18 8,056.00 54.21 65.29 4,210.41 4,117.69 200.35 5,98260 5,980,88346 1,695,574.40 0.00 7" x 8-314" 8,066.00 54.21 85.29 4,21626 4,123.54 201.01 5,990.68 5,980,864.16 1,695,582.48 0.00 Vertical Section (ft) Survey Tool Name 5,512.72 MWD+IFR-AK-CAZ-SC Eli 5.584.95 MW1D+IFR-AK-CAZ-SC(4) 5,656.59 MW -IFR-AK-CAZ-SC(4) Final Definitive Survey Verified and Signed -off All targets andlor Weis position objectives have been achieved. (] Yes No 5,698.49 NOT an Actual Survey 5,706.09 PROJECTED to TD I have checked to the best of my ability that the following data is correct f7 Surface Coordinates p Declination & Convergence E] GRS Survey Corrections E] Survey Tool Codes SLB DE. Brandon Temple Date: 017,1 ed 11:35Brandon-OV001 le Date: 2017.11.03 11:35:49 -08'00' �elMAM DiKJK*s9nedby Ban Tdman Client Representative: 4aDMe Ml7.I lM07:1157419W Date: 1113/17 11!./2017 10:12, 59AM Page 5 COMPASS 5000.14 Build 65 RECEIVED Originated: Schlumberger Nov o z eon PTS-StreetH ENTER A OGCC 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: MakanaK Bender . - Natural Resources Technician 11 Alaska Oil & Gas Conservation Commission %V 7'= Ave. Suite 10O Anchorage. AK 99501 21 7133 TRANSMITTAL DATE I TRANSMITTAL DATA LOGGED N l 41201-7 M.K.BENDEF WELL NAME 2K -21A API # 50-103-20123-01 ORDERSERVICE # DM87.00139 FIELD NAME KUPARUK RIVER DESCRIPTION WL DELIVERABLE DESCRIPTION SqueezeGun DATA FINAL FIELD DATELOGGED 21 -Oct -17 Prints 1 CD's 1 2K -21A 50-103-20123.01 DM87-00139 KUPARUK RIVER WL CBL-SCMT FINAL FIELD 21 -Oct -17 1 1 2K -21A 50-103-20123.01 DSOS-00070 KUPARUK RIVER WL SqueezeGun FINAL FIELD 26 -Oct -17 1 1 2G-15 50-029.21162-00 DSOS-00072 KUPARUK RIVER WL Whipstock FINAL FIELD 29 -Oct -17 1 1 1N-111 50-029.23581-00 DSOS-00073 KUPARUK RIVER WL CBL FINAL FIELD 30 -Oct -17 1 1 5 5 Transmittal Receipt A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X✓""""'�� /...GK package have been verified to match the media noted above. The Print Name Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy to Schlumberger. point. pT-D a/-7-/33 Loepp, Victoria T (DOA) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Wednesday, November 01, 2017 5:56 AM To: Loepp, Victoria T (DOA) Subject: Fwd: 1Fi-111 Production Casing CBL and Cement Attachments: 1FI-111 CBL_11-1-2017.pdf,, 1H-111 7in Production Casing Cement Review.pdf Follow Up Flag: Follow up Flag Status: Completed Victoria, Let me know if you need anything else for your approval for us to proceed with us perfing 1H-111. Thanks. Adam Klem From: Tolman, Ben V <ben.v.tolman@conocophillips.com> Sent: Wednesday, November 1, 2017 05:03 Subject: 1H-111 Production Casing CBL and Cement To: Klem, Adam <adam.klem@conocophillips.com> Adam, Please see information attached for submittal to the state. Included is a wellbore schematic, cement job recap w/ chart, the cement report that gets submitted with 10-407 paper work, and the CBL. Overall I thoughts on the CBL is we have competent cement and good coverage throughout the reservoir section (and above). Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907) 265-6828 (o) 1 (307) 231-3550 (m) Summary PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD5-22 Rig: Doyon 19 Date: 1 J112812017 1 Volume Input Drilling Supervisor: Rick Bjorhus ! W. Earhart Pump used: #z Mud Pump • . strokes IV Type Of Test: Casing Shoe Test LOT/FII Pumping down annulus and DP. 1w Casing Volume/Stroke Pump Rate: 0.1007 Bbis/Strk 'W 5.00 S1rk/min Test Pressure Integrity 1w Hole Size: USE PICK LIST w Casing Shoe Dee Hole De th Pumping Shut-in Pumping Shut-in RKB-CHF: 36.5 Ft 10708.0 Ft-MD 7472.0 Ft-TV 10718.0 Ft-MD 7473.0 Ft-TVD Casing Size and DeSCrigtlon. 10-3/4"45.5#/Ft L-80 BTC -w Strka si Min Si Strks psi Min psi 5 250 0 3575 1 0.00 710 CasinoT t PressureInt il ri Test 10 550 1 3575 2 0.25 710 Mud Weight: 10.7 ppg Mud 10 min Gel: 23.0 Lb/100 Ft2 Test Pressure: 3500.0 psi Rotating Weight: # Lbs Slocks/Top Drive Weigh 60000.0 Lbs Estimates for Test: 12.9 bbls j Mud Weight: 10.7 ppg Mud 10 min Gel: 20.0 Lb/100 Ft2 Rotating Weight: �# Lbs Blocks/Top Drive Weight: 60000.0 Lbs Desired PIT EMW: 12.5 ppg Estimates for Test: 699 psi 2.6 bbls 15 875 2 3575 3 0.50 705 20 1100 3 3575 4 240 1.00 700 25 1350 4 3575 5 290 1.50 690 30 1650 5 3575 6 350 2.00 685 35 1950 6 3575 7 405 2.50 68^ 40 2250 7 3575 8 460 3.00 45 2600 8 3575 9 511 3.50 u .. EMW = Leak-off Pressure + Mud Weight = 715 + 10.7 0.052 x TVD 0.052 x 7472 EMW at 70708 Ft-MD 7472 Ft-TVD = 12.5 ppg PIT 15 Second Shut-in Pressure, psi 50 2925 9 3575 1' 4.00 660 55 3275 10 3575 1 4.50 650 710 60 3600 15 3575 11 5.00 650 400020 Lost 0 psi during test, 3500 3000 W 2500 N 2000 Lu IL 1500 1000 500 0 0 1 2 3 45 8 7 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes � CASING TEST --N-LEAK-OFF-LEAK-OFF TEST 0 PIT Pant 3575 5.50 640 25 3575 6.00 640 30 3575 6.50 630 7.00 625 7.50 620 8.00 610 8.50 610 9.00 600 9.50 10.00 11 2 3 Si5 4 575 Volume Pump ed o u c Bled Bac olume Pumped --Volume Bled Back 8 4. S S S Comments: 10.7 ppg LSND Intermediate Casino - TesIT. I Summary Free Ringing Pipe Amplitude Shift at Top of Cement Free Ringing Pipe Amplitude Shift at Top of Cement Insulated Conductor: 20" Casing Wellhead/Tubing Hanger/Tree, 1H-111 NEWS 13-3/8" x 4-'/V IBTM, SM Injector (Post Drilling & Pre -Completions) Crossover below TH : 4-12" x 3-12" Tubing 3-12", 9.2 #, L-80, EUE-AB 10-3/4" 45.5#, L-80 HYD563 @ 1856 It MD Surface Casing 3-12" MMG with SOV Feed Through Pecker #3 (Baker): 7193'MD Gauge Mandrel: 7198'MD — 2.812" Cameo DS Nipple: 7209MD Upper MMGW: 7213'MD Lower MMGW 7243'MD Feed Through Packer #2 (Baker): 7373'MD Gauge Mandrel: 73831MD Upper MMGW: 738VMD Lower MMGW: 7418'MD Feed Through Packer #1 (Baker): 7482'MD Gauge Mandrel: 7487MD - 2.813" Cameo XNipple: 749TMD - Upper MMGW: 7502'MD Lower MMGW: 75321MD RA/PIP Tags @ 3009,'& 7,013' MD "D" Sand Perforations: 7276'-7356'MD Baker WIV:7843'MD k ► Scraper/Magnet Assy: 7845'MD Dumb iron muleshoe:7875MD — "B" Sand Perforations: 7408'-7467'MD 1 A4 perfs:7497'-7524'MD A3 parts: 7619'-7636 MD A2 parts: 7690'-7769'MD 7" 26#, L-80, HYD563/rXP — (6.276" ID, 6.151" DRIFT) X@ 8056 MD TD @ 8,066' MD /4,216' TVD ConocoPhillips Formation Tops Base of Permafrost: 1,699' MD / 1639' TVD Ugnu Top: 5,233' MD 13,048' TVD N Sands: 6,798' MD / 3,564' TVD West Sak D: 7,275' MD / 3,761' TVD West Sak B: 7,407' MD / 3,835' TVD West Sak A: 7,473' MD / 3,774' TVD ConocoPhillips ® Cement Slurry: 678 sks 15.8 ppg tail Job Comments: 6 Maintained proper cement mixing density a Good returns throughout job Reciprocated pipe Saw good lift pressure Did not bump plug but floats held Made clean-out run wJ bit Found plug @ 7,888' MD 77' (3 bbls) above float collar * TOC identified at 3,350' MD/2,517' TVD • 3448' MD above pool top • 1044' TVD above pool top Pressure tested casing to 3,500 psi Test was performed after clean-out run Good lift pressure on cement job 2 November 1, 2017 1H-111 Pump Chart Time Pressure Density - — gate az:as:m a3:os:m 03:35:m a3:es:m ae:as:m � ae:os:m ! :6s M::m aszs:m J ar.=s;m a6:a3;m a6:zs: O6:M i nn:mma a.m BY,I I6m mm zzm ama ea 8D 1a.a lz.x lsa LSa a.m zL no 6a Ea La.a N Cement Detail Report 1H-111 String: lnh• ORII I INC I rags vT Report Pentad: 10/31120171 deoripHon cemaNn9loll dto denoWn, EM -IMM ae Nemo Plodudion Casing Cement 10r30201] 06;00 10/301201708:45 1H-tii oamen mre Pump cement lob as follows: SLB pump 5 bola freshwater ant pressure lost fines to 600 / 4500 psi - good test Pump W bible 12.5ppg Mudpush at 3 bpm, ICP 280 be, FCP 153 psi. Drop Davis Lynch aft-fse dMal bottom plug. Belch mix cament, Cament wet at 04:48 his. SLB Pump total of 140 bible 15.9ppg Class G cement at 5.5 bpm, ICP 273 pal, FCP IM psi. pop Davis Lynch aNd Madonsl tap plug. SLB pump 10 bols ireshander at 6 bpm, 150 psi. Reciprocete pipe -13 R, PUW /85k, SOW 82K Displace cement using SLB pump truck with 9.OPp9 NaCl brine wit 3% KG at 6 bpm, ICP 100 pal, FCP 1247 psi for 275 We. Drop rate to 4 bpm, ICP 1015 psi, FCP 1100 psi for 10 bbls. pap rale to 2 bpm, ICP 890 psi, FCP I O34 pet. Did not observe plugs bumping. Pumped total of 296.9 blas W brine (displacement plus 112 of shoetnrk volume). Hold pressure for 5 minutes. Bleed Wf and check floats -floats holding. Cement M pace a 06:35 hrs. Note: No downhole lasses observed throughout cement join Cemem Stages Stage x t decrlpdon Production Casing Obpgive Tap d (XNBI Cement Product. 4,324.0 Bglgn Depth (XKB)FYII Relvni VW CamrR... Top p1Ypi Brm Poua} Cement casing 6,056.3 Yes 0.0 Yes Yes C Pump Mh (EbNn... O Pump Flntl lbbll... O ump Ava Ib ... P Pump FIMI Iry 1 plop Bum"Iota) dpi SXake 1X1 Ro 17 P pe RPM Imml 6 2 6 1,031.0 0.0 Yea 13.00 No agpetl dpi IX 1 TF9 ph ug ON b OW To MKBI Cm Diameter lin) 7,822.0 Cog Bit 7,888.0 B 118 Cmmsm Pump cement job as follows: SLB pump 5 bible freshwater and pressure test lines to 600/4500 Psi - good test. Pump 30 bola 12.5ppg Mudpush at 3 bpm, ICP 260 psi, FCP 153 psi. Drop Devic Lynd1 anti+otaeonal bottom pug. Batch mix cement, Camem we at 04:48 his. SLB pump total W 140 bible 15.8ppg Gass G cement at 5.5 bpm, tCP 273 psi, FCP 146 0. Drop Davis Lynch antl-rota0onal top plug. SLB pump 10 bels freshwater at 6 both, 150 psi. Reciprocate pipe -13 8, PUW 185k, SOW 52k. Displace cement using SLB pump trudt with g.Oppg Nact bene w/ 3% KG M 6 bpm, ICP 100 psi, FCP 1247 pG for 275 bible. Drop We to 4 bpm, ICP 1015 psi, FCP 1100 psi for 10 ties. Drop We to 2 bpm, ICP 8W psi, FCP 1034 psi. Did not observe plugs bumping. Pumped total W 296.9 bible W brinier (dsplacament pus 12 W shoetri volume). Hold pressure for 5 minutes. Gleed off and chedt floats - noels holding. Cement in pace Q 06'35 firs. Note: No downhole losses observed throughout cement job Cement Fluids A Additives Fluid Fluid Type Flultl dacdpdan Esamfted Top(rtKB) Eatatmmism) Amoum(ii Chu Valame petl jUb Mod Push 3,525.0 4,324.0 30.0 Weld (IPlaac) Mix Hie RMip lgM+va... Free Water l%) dnehy961ge1 Push. Vleo"Ityll"i Thickening TTheeIMI Omuta, 1 ('.1) 12.50 ddmvaa AdtlkWa Type Cm on"I' l"n COM Un aloe plot Fluitl Type FlYm dacepHon leen ebtl Top tZB2) Ea Ben (NN 1 AmMm (axkel Cleve Volume Pumped m6l CemMa 4,324.0 8.056.0 678 G 140.0 YNid IM•aeol slum Rafo 1pWFa... Frq ort%1 XY Iw/wll Poasd<WecoeHyl.67 Tbicke amme(m) Can ,testi 1.18 5.12 15.80 4.25 tldltives ditiw Type eM[emretlan on[ UnX label 0047 Antifoem 0.05 geVBk ddkM TYW Cornenintlon CMC UnX IebN 0665 Dispersant 0.2 %BWOC A ve TYPv ConoemraaM Car[ nit law 0255 Fluid Loas 0.5 %SWOC I rags vT Report Pentad: 10/31120171 THE STATE OfALASKA GOVERNOR BILL WALKER Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, West Sak Oil Pool, KRU IH -111 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-133 Surface Location: 169' FSL, 778' FEL, SEC. 28, T12N, R10E, UM Bottomhole Location: 355' FSL, 115' FEL, SEC. 27, T12N, R10E, UM Dear Mr. Alvord: 333 West seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aogccalaska. gov Enclosed is the approved application for permit to drill the above referenced service well. Per Statute AS 31.05.030cdxx13 2 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 R day of October, 2017. STATE OF ALASKA ALA, A OIL AND GAS CONSERVATION COMMI� JN PERMIT TO DRILL 20 AAC 25.005 Kt: ;tivt:ul SEP 19 2011 Ih AOGCC 1 a. Type of Work: Drill E. Lateral ❑ Reddll ❑ Reentry ❑ 11b. Proposed Well Class: Exploratory - Gas ❑ Stratigraphic Test ElDevelopment - Oil [I Exploratory - Oil ❑ Development - Gas ❑ Service - WAG ✓ • Service - Disp�- t Service - Winj ❑ Single Zone R Service - Supply ❑ Multiple Zone Ll 1c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket Single Well ❑11. Bond No. 59-52-180 yry Well Name and Number: KRU 1H-111 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 8,050' TVD: 4,272' 12. Field/Pool(s): Kuparak River Field West Salk Oil Pool. 4a. Location of Well (Governmental Section): Surface: 169' FSL & 778' FEL, Sec 28, T12N, RIDE, UM Top of Productive Horizon: 318' FSL & 660' FEL, Sec 27, T12N, R10E, UM Total Depth: 355' FSL & 115' FEL, Sec 27, T12N, R1 DE, UM - 7. Property Designation: ADL025639 8. DNR Approval Number: 80-261 13. Approximate Spud Date: 10/19/2017 9. Acres in Property: 2560 acres - 14. Distance to Nearest Property: 115' to ADL025638 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 549562.21 y- 5980872.05 Zone- 4 . 10. KB Elevation above MSL (ft): 93.0' GL/ BF Elevation above MSL (ft): 54'.0 , 15. Distance to Nearest Well Open to Same Pool: 3,983'to 1C-174 16. Deviated wells: Kickoff depth: 420 feet • Maximum Hole Angle: 71.87 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 1,790 psi , Surface: 1,391 psi 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) 42" 20" 94# H-40 Welded 80' Surf Surf 119' 119' Existing, cement to surface 13-1/2" 10-3/4" 45.5# L-80 HYD563 1746' Surf Surf 1785' 1714' 640 sx 11.0 ppg, 275 sx 15.8 ppg 8-3/4" 7" 26# L-80 HYD563lT 8011' Surf Surf 8050' 4272' 380 sx 15.8 ppg Class G 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): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑✓ 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch ✓ B Drilling Program Seabed Report ✓ Time v. Depth Plot e Drilling Fluid Program B Shallow Hazard Analysis 20 AAC 25.050 requirementsB 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: Ben Tolman 91. Authorized Name: Chip Alvord Contact Email: begm.tolmanlcDcolp.com Authorized Title: Alaska Drilling Manager ( Contact Phone: 907-265-6828 Authorized Signature: . c-.. (�(..{� Date: �I(612-C( Commission Use Only Permit to Drill 1 Number: - 3 API Number: 50-00 - - �] - pp - O� Permit Approval Date: p I See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained m shales: Other: i5PJ p 2-CSf }0 9 5D C P 5-/ 5Samples req'd: Yes ❑ No(yyJ Mud log req'd: Yes r❑] Nog �✓Ihv/q /PrG v�h firr--ft5to Z5 -170P g/gqHzS measures: Yes No[ -Directional svy req'd: Yes Z' No❑ Spacingkxception req'd: Yes ❑ No LI Inclination -only svy req'd: Yes ❑ No Post initial injection MIT mq'd: Yes Dj"No ❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 9� A I 6[�l13�� vN A� /a Submit Form and rm 10.4 1 Rev' a 2017 p r I f 2 months fro e d to of approval per 20 AAC 25.005(g) Attachments in Duplicate o'� f ISS a- Application for Permit to Drill, Well 1 H-111 Saved: 18 -Sep -17 Sept 18, 2017 Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Well 1H-111, a West Sak Sand Injector V Dear Commissioner: RECEIVED SEP 19 2017 AOGCC ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots injector well from the 1 H pad. The expected spud date for this well is Oct 19h, 2017. It is planned to use rig Doyon 142. / IH -111 is planned to be a slant thru the West Sak sands. The surface section will be drilled with 13-1/2" bit and run 10- 3/4" casing to ±1,785' MD / 1,714' TVD. The production section will be drilled with 8-3/4" bit and run 7" casing to +/- ±8,050'MD / 4,272' TVD. The upper completion will be run with 3-1/2" tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Ben Tolman at 265-6828 (ben.v.tolman@cop.com) or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well 1H-111 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 1H-111 Drilling �- BWells CanocoV hilfiPs Location Summary Requirements of 20 AAC 25,005(c)(21 An application for a Permit to Drill must be accompanied by each of the following items. except for an item already on file wish the commission and identified in the application: (2) a plat identifying the property and the property's miners and showing (A)Ihe coordinates of the proposed location of the well at the sinface, at the top ofeach objective formation. and at total depth. referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the suface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration: (C) the proposed depth of the well at the top of each objeclive formation and at total depth: Location at Surface 169' FSL, 778' FEL, Sec 28, T12N, R010E, UM NGS Coordinates Northings: 5,980,872.05' Eastings: 549,562.21' RKBElevatton 93' AMSL Pad Elevation 54'AMSL Location at Top of 318' FSL, 660 Productive Interval Northings: 5,981,059.08' Eastings: 554,948.18' 27, T12N, R010E, UM 7.217' Location at Total Depth 355' FSL, 115' FEL, Sec 27, T12N, R010E, UM NGS Coordinates Northings: 5,981,100.26' Eastings: 555,502.68' I Measured Depth, RKB: 8,050' Total Vertical Depth, RKB. 4,272' Total Vertical Depth, SS: 4,179' and (D) other information required by 10 AAC 25.050(b): Requirements of 20 AAC 25.050(b) Ifa well is to be intentionally deviated. the applicationfar a Permit to Drill (Form 10-401) nuhst (1) include a plat. drawn to a suitable scale. showing the path of the proposed wellbore, including all adjacent wellbores within 100 feet of arty portion of the proposed well: Please see Attachment: Directional Plan And (2) forall it ells within 200 feei of the pr eposed a el/bore (A) list the names of the operators of those yells, to the extent that those names are known or discoverable in public records, and shmr that each named operator has been furnished a copy of the application by certified mail: ar (B) state that the applicant is the only affected miner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except jor an iteu already on file with the commission and identified in the application: (3) a diagram and description ofthe blowout prevention equipment (HOPE) as required by 20 AAC 25.035. 20 AAC 25.036. or 20 AAC 15.037, as applicable: Please reference BOP schematics on file for Doyon 142 and attachment. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application jar a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards. including (A) the rnaximmn downhole pressure that may be encountered. criteria used to determine it, and nraranum potential surface pressure based on a methane gradient: The maximum potential surface pressure (MPSP) while drilling 1H-1 I 1 is calculated using an estimated maximum reservoir pressure of 1,590 psi (based on IH -105 MDT pressure of 1749 psi, 8.6 ppg / equivalent, and corrected to depth), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak A2 sand at 3,995' TVD: A Sand Estimated. BHP = 1,790 psi A Sand estimated depth = 3,995' TVD Gas Gradient — 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 399 psi (3,995' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 1,391 psi (1,790 psi — 399 psi) (B) data on potential gas zones: The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as abnorumll3 geo-pressured strata, lost circulation zones, and zones that have a propensity for differential slicking: See attached 1H-111 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items. except far an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting -jet oration imegray tests. as required under 20 AAC 25.030(f): A procedure is on file with the commission for performing LOT'S. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items. except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030. and a description of any slotted linec pre -perforated liner, or screen to be installed Casing and Cement Program Casio and Cementin Pro ram Csg/Tbg OD Hole Sime Weight Grade Conn. Length Top NIDfTVD Ban MD/TVD Cement Program (in) nb ft) 0 f) U) 20 42 94 H40 Welded 80 Surf 119/119 Existing Cement to Surface with 10-3/4 13-1/2 45.5 L-80 HYD563 1,746 Surf 1,785 / 1,714 640 sx LaeCRETE Lead 11.0 ppg, 275 sx UmSLURRY Tail 15.8 ppg 7 8-3/4 26 L-80 1YD563 / g Ol I Surf 8,050 / 4,272 380 sx Class G at 15.8ppg TXP w/ TOC at 6,065' MD 10-3/4" Surface casing run to 1,740' MD / 1,707' TVD Cement from 1,785' MD to 1,285'(500' of tail) with 15.8 ppg UniSLURRY, and from 1,285' to surface with 11 ppg LiteCRETE. Assume 150% excess annular volume for lead and 50% excess for tail, and 0% excess in 20" conductor. Lead slurry from 1,285' MD to surface with Arctic LiteCRETE @ 11 ppg Conductor (119' — 0') x 1.339 ft /ft x 1.0 (00% excess) = 159 ft' Bottom of Lead to Conductor (1,285' — 119') x 0.3638 ft3/ft x 2.5 (150% excess) = 1,060 ft' Total Volume = 159 + 1,060 = 1,220 ft'=> 640 sx of 1I ppg LiteCRETE @ 1.91 ft' /sk Tail slurry from 1,785' MD to 1,285' MD with 15.8 ppg UniSLURRY Shoe to Top of Tail (1,785'— 1,285') x 0.3638 I13/ft x 1.50 (50% excess) = 273 ft Shoe Joint (80') x 0.5400 ft /ft x 1.0 (0% excess) =43 ft' Total Volume = 273 + 43 = 316 113 => 275 sx of 15.8 ppg UniSLURRY @ 1.16 Whisk 7" Production casing, run to 8.050' MD / 4.272' TVD Single stage slurry is designed to be placed from TD to 6,065' MD, which is 250' TVD above top of West Salk Pool (base of Ugnu); 40% excess annular volume. Slurry from 8,050' MD to 6,065' MD with 15.8ppg Class G + additives Shoe to Top of Cement (8,050'— 6,065') X 0.1503 Will X 1.40 (40% excess) = 418 ft Shoe Joint (80') X 0.3171 ft3/11 X 1.0 (0% excess) = 21 113 Total Volume = 418 + 21 = 439 fit's => 380 sx of 15.8 ppg Class G @ 1.16 ft3/sk Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to D, ill must be accompanied by each of the following items. except for an item already on file with the commission and identified in the application: (7) a diagram and description of the divener system as required by 20 AAC 25.035, unless this requoentem is waived by the commission amder 20 AAC 25.035(h)(2): Please reference diverter schematic on file for Doyon 142. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(81 An application for a Pennit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a drilling fluid progrmn, including a diagram and description of the drilling fluid system. as required by 20 AAC 25.033; Mud Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis _Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding _Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program R_ eguirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill musi be accompanied by each of the follownig items, except for an item already on file with the commission and identified in the application: Surface 13-1/2" Hole 10-3/4" Casing Production 8-3/4" Hole 7" Casing Mud System Spud WBM LSND WBM Density 8.8-9.5 9.0-10.0 PV ALAP ALAP YP 30-80 20-30 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD N/A Initial Gel 30-50 9 - 11 10 minute Gel 30-50 < 20 API Filtrate NC <6 HTHP Fluid Loss at 160° F N/A <10 H 10.8-11.2 9.5-10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis _Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding _Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program R_ eguirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill musi be accompanied by each of the follownig items, except for an item already on file with the commission and identified in the application: The proposed drilling program is included below. Please refer to attachment for proposed well schematic. 1. Move in / rig up Doyon Rig 142. Install Annular with 16" diverter line and function test. Notify AOGCC 24 hrs before test. 2. Spud and directionally drill 13.5" hole to casing point at +/- 1,785' MD / 1,714' TVD as per directional plan. Run MWD tools and required for directional monitoring (gamma ray, resistivity). ✓ 3. Run and cement 10.75", 45.5#, L80, HYD563 casing to surface. Displace cement with mud and check floats upon bumping plug. Perforin top job if required. 4. Remove diverter system. Install and test 13-5/8" x 5,000 psi BOP's to 250 psi low and 3,500 psi high (annular preventer to 3,500 psi). Notify AOGCC 24 hrs before test. 5. PU 8.75" bit and 6.75" drilling assembly, with MWD/LWD (gamma ray, resistivity, sonic, neutron -density). RIH, clean out cement to top of float equipment and test casing to 3,000 psi for 30 min. 6. Drill out cement and between 20' - 50' of new hole. Perform leak off test to a minimum of 11.5ppg EMW LOT/FIT, recording results. 7. Displace to LSND water based drilling fluid. 8. Directionally drill to 7" casing point at 8,050' MD / 4,272' TVD. 9. Circulate hole clean. POOH. 10. Run 7, 269, L80, HYD563/TXP casing to surface. (Top of cement to be 6,065' MD / 3,366' TVD which corresponds to 250' TVD above top of the West Sak Pool.) 11. Install wellhead x 7" packoff and test to 3,500 psi. 12. Flush 10.75" x 7" annulus with water, followed by isotherm. 13. Pressure test production casing to 3,500 psi for 30 min. 14. Run CBL on wireline. /1/Ot�iiy 106ee 07' GQL t'r,s✓lt5 ct.-,o( Ct�rn% Job rls�l� 15. RIH with TCPs and perforate zones. 16. Close annular and reverse circulate perforations (circulate out gas from perf guns any potential hydrocarbons). 17. Make clean out run if needed. 18. Run 3.5" upper completions with packers and gauges. 19. Land hanger, run in lock screws, and test seals to 5,000 psi. 20. Set BPV. 21. Nipple down BOPE, nipple up tree and test. Pull BPV. 22. Freeze protect 3.5" x 7" annulus (if the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 23. Set BPV and move off rig. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music he accompanted by each of the follmring items, eccepl for an item already on file p ith the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of ithelher the operator intends to request authon--ation under 20 AW 25.080 fm' an annular disposal operation in the well.: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class I1 disposal well (DS 1B CRI) or Prudhoe DS-VAll cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. I Attachments: Attachment 1 AOR Attachment 2 Directional Plan Attachment 3 Drilline Hazards Summary Attachment 4 Well Schematic Attachment 5 Diverter Layout Diaeram Attachment 6 BOP Confieuration Attachment 1 AOR An Area of Review plot is shown below of the 1H-11 I planned wellpath and offset wells. The included table identifies any of the offset wellbores within the'/4-mile review. tl pDlf 1H-111wp22 TOC Quarter Mile View Cement Operations Name 1H-11B1H 118vp24 1 tyt�}p 103L4Ny21 06 Ne 'tl 120w '1 266 Reservoir Status Zonal Isolation /"On4wg 2 II (MD/TVD) TVD) By 1H^14wy21 I I Column of cement to be 250' 1 H -I I I 1H 11" /' 7,217' / 3,765' 6,0651/ CBL Not Yet Drilled above pool top @ 6,065 MD/ <r �.•..- Injector 3,366' __1H 117. ^� . I . 3,366' TVD I -' 860 IH -113 Proposed 9,124' / 3,788' Closest Approach @ D top of I H -I 11: 1. Well does not exist et y Injector 475' TVD & 181' (X,Y) above pool top. 1940' separation between D tops Laterals will be open hole. 1H-102 Proposed Not Yet Drilled Intermediate casing cement to --- ---- ------ iH111wP22 Producer be 250' above pool top. -} T I Proposed Not Yet Drilled Intermediate casing cement to Well does not exist yet Producer he 250' above pool top. I I I _`�----µl-00AP 1.m -'9i4-142"B21 --4H-i08wB..1 1 2660 _ -am 0 am 17m 2550 3400 4250 51m 050 6800 ]650 vastFY�l�) Im � ) Well Top of West TOC TOC Cement Operations Name Status Sak D Sand (MD / Determined Reservoir Status Zonal Isolation Summary (MD/TVD) TVD) By Column of cement to be 250' 1 H -I I I Proposed 7,217' / 3,765' 6,0651/ CBL Not Yet Drilled above pool top @ 6,065 MD/ Well does not exist yet Injector 3,366' 3,366' TVD Not Yet Drilled. IH -113 Proposed 9,124' / 3,788' Closest Approach @ D top of I H -I 11: Column of cement to be 250' Well does not exist et y Injector 475' TVD & 181' (X,Y) above pool top. 1940' separation between D tops Laterals will be open hole. 1H-102 Proposed Not Yet Drilled Intermediate casing cement to Well does not exist yet Producer be 250' above pool top. Laterals will be open hole. IH -103 Proposed Not Yet Drilled Intermediate casing cement to Well does not exist yet Producer he 250' above pool top. 9:18, August IY 201] 1 H-111 wp22 Permit Pack W S B _ T-3 e �f g PFROST Na] / 0 UG CUCUG_A IV1WS_BASE 0 0 1875 3750 5625 7500 ` V x 42' 10 3/4' x 13-1/ Measured Depth 7" x 8-1/2 X000 i I Plan: 54.1+39 @ 93.10usft (Doyon 142) j'ZOe. o- i u : � 1-41 r ^N I I eo r �0 850 X1,700 2550 3400 4250 5100 x 4e2 10 3/4" x 13-1/ Horizontal Denarmre 7 eAV MV TY'. 60 ca i. DO v 40 y l r li o m i I 20 Equivalent Magnetic Distance 0 1250 2500 3750 5000 6250 7500 Depth From Depth To elrvaylFlan Tool East / X: 1689593.83 3900 500.00 1H911wp22 (flan: 1H-111) G9D'GDS$ 59000 150000 1H9tf wp22 (Flare 1H-111) Mw0 Patl Elevation: 54.10 1500.0017MW 114111wp22(Man: 1H-111) Mw". AK-CAZ-SC TVD MO A 1764.533261.53 11+111wp22(Man: 1H-111) MWD 118.10 118.10 2P 1784.53 WMA9 1Hd11wp221%an: 1H-111) MWD.IFR-AK CAZ-$C 1714.00 1784.53 10314'% 4272.37 8050.49 T' x Plan Summ 00 \^h 00 �O 1 39 211 330I�I" 0 0 fiW so0 - 790 I1 IIIIC 790 - 970 +E/ -W 970 1150 TFace VSect Target 1150 1340 300 y 60 1340 - 1520 1 1520 1700 0.00 1700 IWO 1 :3 1950 2230 0.00 2230 24M 0.00 0.00 2490 - 2750 27W 3010 90 3010 3270 420.10 3270 - 3540 0.00 3540 - 3600 0.00 3600 43M 240 120 4330 46fi0 KOP: Start 1.51100' DLS, 110 -TIF, for 180.07' 4660 5390 5390 5920 600.17 5920 - 64fi0 211 150 6460 6990 1 ` 6990 7520 180 7520 - 6050 Magnetic Model & Date: BGGM2017 15 -Nov -17 Magnetic North is 17.391 East of True North (Magnetic Declination) Magnetic Dip & Field Strength: 80.94° 57484.61 nT 4PFROST Lithology Column Sec MD Inc AA TVD +N/ -S +E/ -W Dleg TFace VSect Target Annotation uy Bui An 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 420.10 0.00 0.00 420.10 0.00 0.00 0.00 0.00 0.00 KOP: Start 1.51100' DLS, 110 -TIF, for 180.07' 3 600.17 2.70 110.00 600.10 -1.45 3.99 1.50 110.00 3.88 Start 2.51100' DLS, S°TF for 611.73' 4PFROST 41211.90 17.99 107.44 1200.10 -34.89 108.28 2.50 .3.00 105.58 Scan 31100•DLS,-5°TF for 398.67' 5 1610.56 29.92 105.36 1563.77 79.85 263.47 3.00 -5.00 257.25 Hold for 115.38' 4 6 1725.94 29.92 105.36 16 63.77 95.10 31896 000 0.00 311.55 Start 41100' DLS,-26.73°TF, for 58.59' T-3 7 1784.53 32.03 103.38 1714.00 -102.57 348.18 4.00 -26.73 340.17 Hdtl for 20' 4 8 1804.53 3203. 103.38 4730.96 -105.02 358.50 0.00 0.00 350.30 Start 4°/100 DLS,-25.03°TF, for 1045.78' 9 2850.31 71.87 86.11 2365.36 -136.87 1160.02 400 -25.03 1147.65 Hold for 4010.34' 10 6860.65 71.87 86.11 3613.15 121.91 4962.51 0.00 0.00 4958.93 Start 41100' DLS,-17987°TF, for 496.8' 11 7357.46 52.00 86.05 3845.70 151.72 5397.68 4.00 .179.W 5395.12 1H-111 b20Feb15 BW Hold for 243.04' 12 7600.49 52.00 86.05 3995.33 164.91 5588.75 0.00 0.00 5586.64 Adjust F to 0°, for 450 13 8050.49 52.00 86.05 4272.38 18934 5942.51 0.00 0.00 5941.24 TD: 8050.49 MD, 4272.38' TVD K-15 31112 UG C ass G_B N4 UG A . Nagyga 5-A3 S_A2 00 9-4ASE Challengin By signing this I acknowledge that I have been informed of all risks, checked that the �!� data is correct, ensured it's completeness, and all surrounding wells are assigned to Z Orientation the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.( approve it as the basis for the final well plan and wellsite drawings. I also acknowledae that unless notified otherwise all targets have a 100 feet lateral repared by UhCt&M0IIlJY ccepted by Approved by: S. DeLapp uy Bui An Erik Sterk B. Tolman 1 H-111 wp22 39.00 To 8050.49 I Spider Easting (2000 usfYin) MAUgMI02M7 1 H-111 wp22 Plan View 2400 While drilling horizont 1600 al, stay within 100 feet 600 laterally S 1H-111 b 20Feb15 BW 1H 111wp22 of plan, N unless o J notified d o o otherwis Z o 0 o e or as -800 20"'x 42" �" x 8/3/4" dictated 10 3/4" x 13-1/2 by drilling, anti - _1600 collision or geologic 2400 al needs. 0 800 1600 2400 3200 4000 4800 5600 6400 West( -)/East(+) (800 usft/in) %W,August 10 W17 1 H-111wp22 Section View 0- --------20" x 42" --------- 20" 0° 650 5° 10° 15° 10 3/4" x 13-1/2 2.4° 1300 zy° 0° PFROST y o T-3 950 ........... ° ........ k t go hx-15 0 0 m U X600 d H N ....... ----- UGC 3250 - ...... ----- UG_B ----- UG _A ° by W 7" x 8-3/4" 3900-_...... ........ 1H-111 b 20Feb15WB---_--- - _-_Sa 3 WS A2 .� ,. ... ----- WS' Al ---.-- VPS N o. -BASE '-------- 3 0 650 1300 1950 2600 3250 3900 4550 5200 5850 6500 = Vertical Section at 86.000 (650 ustl/in) ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-111 (formerly 109, 32D) 50103xxxxx00 Plan: 1H-111 Plan: 1 H-111wp22 Standard Proposal Report 10 August, 2017 ConocoPhillips ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-111 (formerly 109,32D) Wellbore: Plan: 1H-111 Design: 1H-111wp22 Local Co-ordinate Reference: TV0 Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: iH-111 (formerly 109, 32D) Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93, 10usft (Doyon 142) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 1 H Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0 " Grid Convergence: 0.37 ° Well Plan: 1H-111 (formerly 109, 32D) Well Position +N/ -S 900.93 usft Northing: Latitude; Version: +E/ -W 370.96 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: 54.10 usft Wellbore Plan: 1H-111 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) BGGM2017 814/2017 17.56 80.95 57,493.79 Design 1H-111wp22 Date 8/4/2017 Audit Notes: Depth To Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 1H-111 wp22(Plan: 1 H-111) (usft) (usft) (usft) (°) 39.00 0.00 0.00 86.00 Plan Survey Tool Program Date 8/4/2017 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.00 500.00 1H-111 wp22(Plan: 1 H-111) GYD-GC-SS Gyrodata gyro single shots 2 500.00 1,500.00 1H-11lwp22(Plan:11-1-111) MWD MWD - Standard 3 1,500.00 1,784.53 1H-111wp22(Plan: 1H-111) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 1,784.53 3,284.53 1H-11lwp22(Plan: 1H-111) MWD MWD - Standard 5 1,784.53 8,050.49 1H-111wp22(Plan: 1H-111) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/102017 9: 43:05AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Turn Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit (°7100usft) Site: Kuparuk 1H Pad 0.00 Well; Plan: 1H-111 (formerly 109, 32D) Wellbore: Plan: 1H-111 2.50 Design: 1H-111wp22 3.00 2.99 Plan Sections 0.00 0.00 0.00 Measured 3.60 -3.39 Vertical Depth Inclination Azimuth Depth (usft) (°) (°) (usft) 39.00 0.00 0.00 39.00 420.10 0.00 0.00 420.10 600.17 2.70 110.00 600.10 1,211.90 17.99 107.44 1,200.10 1,610.56 29.92 105.36 1,563.77 1,725.94 29.92 105.36 1,663.77 1,784.53 32.03 103.38 1,714.00 1,804.53 32.03 103.38 1,730.96 2,850.31 71.87 86.11 2,365.36 6,860.65 71.87 86.11 3,613.15 7,357.46 52.00 86.05 3,645.70 7,600.49 52.00 86.05 3,995.33 8,050.49 52.00 86.05 4,272.38 +N/ -S (usft) 0.00 0.00 -1.45 -34.89 -79.85 -95.10 -102.57 -105.02 -136.87 121.91 151.72 164.91 189.34 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: +E/ -W (usft) 0.00 6.00 3.99 108.28 263.47 318.96 348.18 358.50 1,160.02 4,962.51 5,397.68 5,588.75 5,942.51 ConocoPhillips Standard Proposal Report Well Plan: 11-1-111 (formerly 109, 32D) Plan: 54.1+39 @j 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Dogleg Build Turn Rate Rate Rate (°1100usft) (°7100usft) (°1100usft) 0.00 0.00 0.00 0.00 0.00 0.00 1.50 1.50 0.00 2.50 2.50 -0.42 3.00 2.99 -0.52 0.00 0.00 0.00 4.00 3.60 -3.39 0.00 0.00 0.00 4.00 3.81 -1.65 0.00 0.00 0.00 4.00 -4.00 -0.01 0.00 0.00 0.00 0.00 0.00 0.00 TFO (°) Target 0.00 0.00 110.00 -3.00 -5.00 0.00 -26.73 0.00 -25.03 0.00 -179.87 1H-111 b 20Feb15 BV 0.00 0.00 8/102017 9:43.05AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan: 1 H-111 (formedy 109, 32D) Company: ConocoPhillips (Alaska) Inc. -Kupi TVD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan: 1H-111 (formerly 109, 32D) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-111 Design: 1H-111wp22 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) V) (usft) (usft) (usft) (usft) (°/100usft) (°1100usft) (°1100usft) 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 118.10 0.00 0.00 118.10 0.00 0.00 0.00 0.00 0.00 0.00 20" x 42" 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 420.10 0.00 0.00 420.10 0.00 0.00 0.00 0.00 0.00 0.00 500.00 1.20 110.00 499.99 -0.29 0.79 0.76 1.50 1.50 0.00 600.00 2.70 110.00 599.93 -1.45 3.98 3.87 1.50 1.50 0.00 600.17 2.70 110.00 600.10 -1.45 3.99 3.88 1.50 1.50 0.00 700.00 5.20 108.56 699.69 -3.69 10.48 10.20 2.50 2.50 -1.44 800.00 7.69 108.05 799.05 -7.21 21.14 20.59 2.50 2.50 -0.51 900.00 10.19 107.79 897.82 -11.99 35.94 35.01 2.50 2.50 -0.26 1,000.00 12.69 107.63 995.83 -18.02 54.84 53.45 2.50 2.50 -0.16 1,100.00 15.19 107.52 1,092.67 -25.30 77.81 75.85 2.50 2.50 -0.11 1,200.00 17.69 107.45 1,188.78 -33.80 104.80 102.19 2.50 2.50 -0.08 1,211.90 17.99 107.44 1,200.10 -34.89 108.28 105.58 2.50 2.50 -0.07 1,300.00 20.63 106.78 1,283.24 -43.45 136.12 132.76 3.00 2.99 -0.74 1,400.00 23.62 106.21 1,375.87 -54.13 172.23 168.03 3.00 2.99 -0.57 1,500.00 26.61 105.76 1,466.41 -65.81 213.03 207.92 3.00 2.99 -0.45 1,600.00 29.61 105.40 1,554.60 -78.46 258.41 252.31 3.00 3.00 -0.36 1,610.56 29.92 105.36 1,563.77 -79.85 263.47 257.25 3.00 3.00 -0.33 1,700.00 29.92 105.36 1,641.29 -91.67 306.49 299.34 0.00 0.00 0.00 1,725.94 29.92 105.36 1,663.77 -95.10 318.96 311.55 0.00 0.00 0.00 1,784.53 32.03 103.38 1,714.00 -102.57 348.18 340.17 4.00 3.60 -3.39 10 3/4" x 13-1/2 1,800.00 32.03 103.38 1,727.11 -104.46 356.16 348.00 0.00 0.00 0.00 1,804.53 32.03 103.38 1,730.96 -105.02 358.50 350.30 0.00 0.00 0.00 1,900.00 35.52 100.60 1,810.30 -115.98 410.41 401.32 4.00 3.66 -2.91 2,000.00 39.24 98.16 1,889.75 -125.82 470.30 460.38 4.00 3.72 -2.44 2,100.00 43.00 96.08 1,965.07 -133.92 535.54 524.90 4.00 3.76 -2.08 2,200.00 46.79 94.27 2,035.90 -140.25 605.82 594.57 4.00 3.79 -1.80 2,300.00 50.61 92.68 2,101.89 -144.77 680.80 669.04 4.00 3.82 -1.59 2,400.00 54.45 91.25 2,162.72 -147.47 760.10 747.96 4.00 3.84 -1.43 2,500.00 58.30 89.96 2,218.09 -148.33 843.34 830.94 4.00 3.85 -1.30 2,600.00 62.16 88.77 2,267.73 -147.35 930.12 917.58 4.00 3.86 -1.19 2,700.00 66.04 87.66 2,311.40 -144.53 1,020.01 1,007.45 4.00 3.87 -1.11 2,800.00 69.92 86.61 2,348.90 -139.89 1,112.58 1,100.11 4.00 3.88 -1.04 2,850.31 71.67 86.11 2,365.36 -136.87 1,160.02 1,147.65 4.00 3.89 -1.01 2,900.00 71.87 86.11 2,380.82 -133.66 1,207.13 1,194.87 0.00 0.00 0.00 3,000.00 71.87 86.11 2,411.94 -127.21 1,301.95 1,289.91 0.00 0.00 0.00 3,100.00 71.87 86.11 2,443.05 -120.76 1,396.77 1,384.94 0.00 0.00 0.00 3,200.00 71.87 86.11 2,474.17 -114.30 1,491.59 1,479.98 0.00 0.00 0.00 3,300.00 71.87 86.11 2,505.28 -107.85 1,586.40 1,575.01 0.00 0.00 0.00 3,400.00 71.87 86.11 2,536.39 -101.40 1,681.22 1,670.05 0.00 0.00 0.00 3,500.00 71.87 86.11 2,567.51 -94.95 1,776.04 1,765.09 0.00 0.00 0.00 3,600.00 71.87 86.11 2,598.62 -88.49 1,870.85 1,860.12 0.00 0.00 0.00 3,700.00 71.87 86.11 2,629.74 -82.04 1,965.67 1,955.16 0.00 0.00 0.00 3,800.00 71.87 86.11 2,660.85 -75.59 2,060.49 2,050.20 0.00 0.00 0.00 3,900.00 71.87 86.11 2,691.97 -69.13 2,155.30 2,145.23 0.00 0.00 0.00 4,000.00 71.87 86.11 2,723.08 -62.68 2,250.12 2,240.27 0.00 0.00 0.00 4,100.00 71.87 86.11 2,754.19 -56.23 2,344.94 2,335.30 0.00 0.00 0.00 8/102017 9: 43:05AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kupamk River Unit Site: Kupamk 1H Pad Well: Plan: 111-111 (formerly 109,32D) Wellbore: Plan: iH-111 Design: 1H-111wp22 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: 1H-111 (formerly 109, 32D) Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100usft) (°/100usfl) (°1100usft) 4,300.00 71.87 86.11 2,816.42 -43.32 2,534.57 2,525.38 0.00 0.00 0.00 4,400.00 71.87 86.11 2,847.54 -36.87 2,629.39 2,620.41 0.00 0.00 0.00 4,500.00 71.87 86.11 2,878.65 -30.42 2,724.21 2,715.45 0.00 0.00 0.00 4,600.00 71.87 86.11 2,909.76 -23.97 2,819.02 2,810.49 0,00 0.00 0.00 4,700.00 71.87 86.11 2,940.88 -17.51 2,913.84 2,905.52 0.00 0.00 0.00 4,800.00 71.87 86.11 2,971.99 -11.06 3,008.66 3,000.56 0.00 0.00 0.00 4,900.00 71.87 86.11 3,003.11 -4.61 3,103.48 3,095.59 0.00 0.00 0.00 5,000.00 71.87 86.11 3,034.22 1.85 3,198.29 3,190.63 0.00 0.00 0.00 5,100.00 71.87 86.11 3,065.33 8.30 3,293.11 3,285.67 0.00 0.00 0.00 5,200.00 71.87 86.11 3,096.45 14.75 3,387.93 3,380.70 0.00 0.00 0.00 5,300.00 71.87 86.11 3,127.56 21.20 3,482.74 3,475.74 0.00 0.00 0.00 5,400.00 71.87 86.11 3,158.68 27.66 3,577.56 3,570.78 0.00 0.00 0.00 5,500.00 71.87 86.11 3,189.79 34.11 3,672.38 3,665.81 0.00 0.00 0.00 5,600.00 71.87 86.11 3,220.90 40.56 3,767.19 3,760.85 0.00 0.00 0.00 5,700.00 71.87 86.11 3,252.02 47.01 3,862.01 3,855.88 0.00 0.00 0.00 5,800.00 71.87 86.11 3,283.13 53.47 3,956.83 3,950.92 0.00 0.00 0.00 5,900.00 71.87 86.11 3,314.25 59.92 4,051.65 4,045.96 0.00 0.00 0.00 6,000.00 71.87 86.11 3,345.36 66.37 4,146.46 4,140.99 0.00 0.00 ool) 6,100.00 71.87 86.11 3,376.48 72.83 4,241.28 4,236.03 0.00 0.00 0.00 6,200.00 71.87 86.11 3,407.59 79.28 4,336.10 4,331.06 0.00 0.00 0.00 6,300.00 71.87 86.11 3,438.70 85.73 4,430.91 4,426.10 0.00 0.00 0.00 6,400.00 71.87 86.11 3,469.82 92.18 4,525.73 4,521.14 0.00 0.00 0.00 6,500.00 71.87 86.11 3,500.93 98.64 4,620.55 4,616.17 0.00 0.00 0.00 6,600.00 71.87 86.11 3,532.05 105.09 4,715.37 4,711.21 0.00 0.00 0.00 6,700.00 71.87 86.11 3,563.16 111.54 4,810.18 4,806.25 0.00 0.00 0.00 6,800.00 71.87 86.11 3,594.27 117.99 4,905.00 4,901.28 0.00 0.00 0.00 6,860.65 71.87 86.11 3,613.15 121.91 4,962.51 4,958.93 0.00 0.00 0.00 6,900.00 70.30 86.10 3,625.90 124.44 4,999.64 4,996.15 4.00 -4.00 -0.01 7,000.00 66.30 86.09 3,662.87 130.76 5,092.32 5,089.04 4.00 -4.00 -0.01 7,100.00 62.30 86.08 3,706.23 136.90 5,182.20 5,179.13 4.00 -4.00 -0.01 7,200.00 58.30 86.07 3,755.77 142.85 5,268.84 5,265.97 4.00 -4.00 -0.01 7,300.00 54.30 86.06 3,811.24 148.56 5,351.82 5,349.15 4.00 -4.00 -0.01 7,357.46 52.00 86.05 3,845.70 151.72 5,397.68 5,395.12 4.00 -4.00 -0.01 7,400.00 52.00 86.05 3,871.89 154.03 5,431.13 5,428.65 0.00 0.00 0.00 7,500.00 52.00 86.05 3,933.46 159.46 5,509.74 5,507.45 0.00 0.00 0.00 7,600.00 52.00 86.05 3,995.03 164.89 5,588.36 5,586.25 0.00 0.00 0.00 7,600.49 52.00 86.05 3,995.33 164.91 5,588.75 5,586.64 0.00 0.00 0.00 7,700.00 52.00 86.05 4,056.59 170.31 5,666.97 5,665.05 0.00 0.00 0.00 7,800.00 52.00 86.05 4,118.16 175.74 5,745.59 5,743.85 0.00 0.00 0.00 7,900.00 52.00 86.05 4,179.72 181.17 5,824.20 5,822.65 0.00 0.00 0.00 8,000.00 52.00 86.05 4,241.29 186.60 5,902.81 5,901.45 0.00 0.00 0.00 8,050.49 52.00 86.05 4,272.38 189.34 5,942.51 5,941.24 0.00 0.00 0.00 7" x 8314" 81102017 9,43:05AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kupawk River Unit Site: Kuparuk 1 Pad Well: Plan: iH-111 (formerly 109, 32D) Wellbore: Plan: IH -111 Design: 1H-111wp22 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: 11-1-111 (formerly 109, 32D) Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Design Targets Vertical Diameter Depth Depth Target Name (usft) Name 118.10 118.10 20"x42" - hitlmiss target Dip Angle Dip Dir. TVD +NIS +E/ -W Northing Easting -Shape (") (1 (usft) (usft) (waft) (usft) (usft) Latitude Longitude 1 H-111 D 080217 RP WI 0.00 0.00 3,805.39 -1,602.92 6,758.83 5,979,065.50 1,696,362.36 70° 21' 13.850 N 149° 32'44.477 W - plan misses target center by 2024.02usft at 8050.49usft MD (4272.37 TVD, 189.34 N, 5942.51 E) 7,306.30 - Circle (radius 100.00) WS_C 7,340.52 3,835.35 WS_B 7,398.71 1 H-111 b 20Febl5 BW 0.00 0.00 3,845.70 151.72 5,397.68 5,980,811.00 1,694,989.88 70° 21'31.118 N 149° 33'24.227 W - plan hits target center WS—A2 7,765.81 4,097.11 WS At 7,900.77 - Circle (radius 100.00) WS—BASE Casing Points Formations Measured Vertical Diameter Depth Depth (usft) (usft) Name 118.10 118.10 20"x42" 1,784.53 1,714.00 10 3/4" x 13-1/2 8,050.49 4,272.38 7" x 8-3/4" Measured Vertical Diameter Depth Depth (usft) (usft) Name 1668.25 1613.77 PFROST 1,869.49 1,785.30 T-3 2.159.76 2,007.96 K-15 5,247.57 3,111.25 UG_C 6,036.67 3,356.77 UG_B 6,438.93 3,481.93 UG_A 6,870.50 3,616.24 Na 7,217.21 3,764.90 WS_D 7,306.30 3,814.93 WS_C 7,340.52 3,835.35 WS_B 7,398.71 3,871.10 WS—A4 7,469.92 3,914.94 WS—A3 7,600.49 3,995.33 WS—A2 7,765.81 4,097.11 WS At 7,900.77 4,180.20 WS—BASE Casing Hole Diameter Diameter 20 42 10-3/4 13-1/2 7 8-3/4 Dip Dip Direction Lithology (1) (`) 811012017 9: 43: 05AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupt Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Plan: 1H-111 (formerly 109, 32D) Wellbore: Plan: 1H-111 Design: 1H-111wp22 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: 1H-111 (formerly 109, 32D) Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 420.10 420.10 0.00 0.00 KOP: Start 1.5°/100' DLS, 110° TF, for 180.07' 600.17 600.10 -1 As 3.99 Start 2.5-/100' DLS, -3° TF, for 611.73' 1,211.90 1,200.10 -34.89 108.28 Start 3°/100' DLS, -5° TF, for 398.67' 1,610.56 1,563.77 -79.85 263.47 Hold for 115.38' 1,725.94 1,663.77 -95.10 318.96 Start 4°/100' OILS, -26.73° TF, for 58.59' 1,784.53 1,714.00 -102.57 348.18 Hold for 20' 1,804.53 1,730.96 -105.02 358.50 Start 4°/100' OILS, -25.03° TF, for 1045.78' 2,850.31 2,365.36 -136.87 1,160.02 Hold for 4010.34' 6,860.65 3,613.15 121.91 4,962.51 Start 4°/100' DLS, -179.87° TF, for 496.8' 7,357.46 3,845.70 151.72 5,397.68 Hold for 243.04' 7,600.49 3,995.33 164.91 5,588.75 Adjust TF to 0*, for 450' 8,050.49 4,272.38 169.34 5,942.51 TD: 8050.49' MD, 4272.38' TVD 8/102017 9:43:054M Page 7 COMPASS 5000.14 Build 85 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-111 (formerly 109, 32D) Plan: 11-1-111 50103xxxxx00 1 H-111 wp22 ConocoPhillips Clearance Summary Anticollision Report 10 August, 2017 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad - Plan: 1H-111(formerly 109, 32D) -Plan: 1H-111-1H-111wp22 Well Coordinates: Datum Height: Plan: 54.1+39 @ 93.10usft (Doyon 142) Scan Range: 0.00 to 8,050.49 uaR Measured Depth. Scan Radius is 1,001.15 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips ConocoPhillips Anticollision Report for Plan: 1H-111 (formerly 109, 32D) - 1H-111wp22 Tmv. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kupamk 1H Pad - Plan: 1H-111(formerly 109, 32D) -Plan: 1H-111-1H-111wp22 Scan Range: 0.00 to 8,050.49 usft Measured Depth. Scan Radius is 1,001.16 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit 10 August, 2017 - 9:47 Page 2 of 6 COMPASS Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Kuparuk 1H Pad 1H -05 -1H -05-1H-05 2,128.58 210.83 2,128.58 156.97 2,275.00 3.914 Clearance Factor Pass - Major Risk 1H-05-1H-05-iH-05 2,146.40 210.49 2,146.40 157.20 2,300.00 3.950 Centre Distance Pass - Major Risk 1H-05-1H-105-iH-105 2,126.95 210.90 2,126.95 156.98 2,275.00 3.912 Clearance Factor Pass - Major Risk 1 H-05 - 1 H-105 - 1 H-105 2,144.77 210.50 2,144.77 157.15 2,300.00 3.946 Centre Distance Pass - Major Risk 1H-401(UGNU)-IH-401-1H-401 1,444.62 137.67 1,444.82 99.58 1,625.00 3.614 Clearance Factor Pass - Major Risk Plan: I H-1 02 (formerly 31) -Plan: I H-1 02 - 1 H-1 02wp2 300.10 210.07 300.10 204.73 300.00 39.310 Centre Distance Pass - Major Risk Plan: I H-1 02 (formerly 31) -Plan: I H-1 02 - 1 H-1 02wp2 375.10 210.63 375.10 204.08 375.00 32.149 Clearance Factor Pass - Major Risk Pian: 1H-102 (formerly 31) - Plan: 1H-1021-1 - 1H -102L 300.10 210.07 300.10 204.73 300.00 39.310 Centre Distance Pass- Major Risk Plan: 1 H-1 02 (formerly 31) -Plan: 1H -10211 -1H -102L 375.10 210.63 375.10 204.08 375.00 32.149 Clearance Factor Pass - Major Risk Plan: 1 H-102 (formerly 31) -Plan: 1H -1021 -2 -1H -102L 300.10 210.07 300.10 204.73 300.00 39.310 Centre Distance Pass - Major Risk Plan: 1H-102(formerly 31) -Plan: 1H -1021 -2 -1H -102L 375.10 210.63 375.10 204.08 375.00 32.149 Clearance Factor Pass - Major Risk Plan: 1H-102(formerly 31) -Plan: 1H -1021 -3 -1H -102L 300.10 210.07 300.10 204.73 300.00 39.310 Centre Distance Pass - Major Risk Plan :1H-102(formerly 31) -Plan: 1H -10213 -1H -102L 375.10 210.63 375.10 204.08 375.00 32.149 Clearance Factor Pass - Major Risk Plan: IH -102 (Formerly 3l) -Plan: 1H -1021 -4 -1H -102L 300.10 210.07 300.10 204.73 300.00 39.310 Centre Distance Pass - Major Risk Plan: I H-1 02 (formerly 31) -Plan: 1H-10214-iH-102L 375.10 210.63 375.10 204.08 375.00 32.149 Clearance Factor Pass - Major Risk Plan : 1H-103 (formerly 104, 33) - Plan: 1 H-103 - IH -10 300.00 149.92 300.00 144.58 300.00 28.061 Centre Distance Pass- Major Risk Plan: 1 H-103 (formerly 104, 33) - Plan: 1 H-103 - i H-10 399.99 150.83 399.99 143.87 400.00 21.673 Clearance Factor Pass - Major Risk Plan: 1H-103 (formerly 104, 33) - Plan: iH-10311 - 1 H 300.00 149.92 300.00 144.58 300.00 28.061 Centre Distance Pass - Major Risk Plan: 1H-103 (formerly 104, 33) - Plan: 1H -103L1 - 1 H 399.99 150.83 399.99 143.87 400.00 21.673 Clearance Factor Pass- Major Risk Plan :1H-103(formerly 104, 33) -Plan: 1H -10312-1H 300.00 149.92 300.00 144.58 300.00 28.061 Centre Distance Pass -Major Risk Plan: 1H-103(formerly 104, 33) -Plan: 1H -103L2 -1H 399.99 15D.83 399.99 143.87 400.00 21.673 Clearance Factor Pass - Major Risk Plan : 1 H-1 03 (formerly 104, 33) -Plan: 1H-10313-iH 300.00 149.92 300.00 144.58 300.00 28.061 Centre Distance Pass - Major Risk Plan : 1H-103 (formerly 104, 33) - Plan: 1H-10313 - 1H 399.99 150.83 399.99 143.87 400.00 21.673 Clearance Factor Pass - Major Risk Plan: 1H-103 (formerly 104, 33) - Plan: iH-1031-4 - 1 H 300.00 149.92 300.00 144.58 300.00 28.061 Centre Distance Pass- Major Risk Plan: 1H-103(formerly 104, 33) -Plan: 1H -103L4 -1H 399.99 150.83 399.99 143.87 400.00 21.673 Clearance Factor Pass - Major Risk Plan : 1 H-1 04 (formerly 101, 27) -Plan: 1H -104-1H-10 2D0.00 89.87 200.00 86.16 200.00 24.257 Centre Distance Pass - Major Risk Plan :1H-104(formerly 101,27) -Plan: 1H -1D4 -1H-10 349.97 90.87 349.97 84.70 350.00 14.748 Clearance Factor Pass - Major Risk Plan: 1H-106(formerly 108, 30E, 107) -Plan: 1H-106- 300.10 239.87 300.10 234.53 300.00 44.886 Centre Distance Pass - Major Risk 10 August, 2017 - 9:47 Page 2 of 6 COMPASS ConocoPhillips Anticollision Report for Plan: 1H-111 (formerly 109, 32D)-1H-111wp22 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 7H Pad -PIan: 1H-111 (formerly 109, 32D) -Plan: 1H-111-1H-111Wp22 Scan Range: 0.00 to 8,060.49 usft. Measured Depth. Scan Radius is 1,001.16 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit 10 August. 2017 - 9:47 Page 3 of 6 COMPASS Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Plan :1H-106(formerly 108, 30E, 107) -Plan: 1H-106- 375.10 240.52 375.10 233.98 375.00 36.777 Clearance Factor Pass - Major Risk Plan :1H-107(formerly 106, 28E, 112)-PIan: 1H-107- 250.10 180.25 250.10 175.78 250.00 40.322 Centre Distance Pass - Major Risk Plan* 1 H-107 (formerly 106, 28E, 112) - Plan: 1 H-107 - 325.10 180.90 325.10 175.25 325.00 32.032 Clearance Factor Pass - Major Risk Plan: 1H-108 (formerly 111, 30D) - Plan: 1H-108 - iH-1 577.05 119.55 577.05 109.89 575.00 12.370 Centre Distance Pass- Major Risk Plan: 11-1-108 (formerly 111, 30D) - Plan: 1 H-108- 1H-1 755.00 120.75 755.00 108.68 750.00 10.007 Clearance Factor Pass- Major Risk Plan, 1 H-1 09 (formerly 110, 30C) -Plan: 1H -109-1H-1 550.90 59.72 550.90 50.39 550.00 6.397 Centre Distance Pass - Major Risk Plan: 1H-109 (formerly 110, 30C) - Plan: 1H-109 - 1 H-1 727.21 60.74 727.21 49.08 725.00 5.210 Clearance Factor Pass- Major Risk Plan, 1H-110(formerly 111, 113, 34D) -Plan, 1H-110- 375.10 29.92 375.10 23.27 375.00 4.497 Centre Distance Pass - Major Risk Plan* 1H-110(formerly 111, 113, 34D) -Plan 1H-110- 676.13 32.40 676.13 21.50 675.00 2.971 Clearance Factor Pass - Major Risk Plan* 1H-112(formerly 107, 28D, 106)- Plan 1H-112- 400.10 30.12 400.10 23.03 400.00 4.247 Centre Distance Pass - Major Risk Plan: 1H-112(formerly 107, 28D, 106) -Plan: 1H-112- 549.64 31.08 549.64 21.60 550.00 3.278 Clearance Factor Pass - Major Risk Plan: 1H-113(formerly 112, 34B) -Plan: 1H -113-1H-1 1,244.44 53.07 1,244.44 31.63 1,250.00 2.475 Centre Distance Pass - Major Risk Plan: 1H-113(formerly 112, 34B) -Plan: 1H -113-1H-1 1,493.27 57.34 1,493.27 28.55 1,500.00 1.992 Clearance Factor Pass - Major Risk Plan* 1 H-114 (formerly 30B,116) -Plan: IH -114-1H-1 400.00 90.07 400.00 82.96 40D.00 12.704 Centre Distance Pass - Major Risk Plan : 1 H-114 (formerly 30B,116) -Plan: 1H -114-1H-1 1,016.74 94.13 1,016.74 77.84 1,025.00 5.779 Clearance Factor Pass - Major Risk Plan :1H-115(formerly 115, 34A, 114) -Plan* 1H-115- 671.73 117.90 671.73 106.97 675.00 10.780 Centre Distance Pass - Major Risk Plan: 1H-115(formerly 115, 34A, 114) -Plan: 1H-115- 943.21 120.15 943.21 104.87 950.00 7.866 Clearance Factor Pass - Major Risk Plan :1H-116(formerly 114, 32B, 115) -Plan: 1H-116- 400.00 149.96 400.00 142.87 400.00 21.151 Centre Distance Pass - Major Risk Plan: 1H-116(formerly 114, 32B, 115) -Plan: 1H-116- 670.53 151.42 670.53 140.46 675.00 13.812 Clearance Factor Pass - Major Risk Plan: IH-117(formerly 118, 28B) -Plan: 1H-117-iH-1 400.10 180.20 400.10 173.11 400.00 25.412 Centre Distance Pass - Major Risk Plan: I H-1 17 (formerly 118, 288) -Plan: 1H-117-iH-1 547.62 181.09 547.62 171.63 550.00 19.145 Clearance Factor Pass - Major Risk Plan :IH-118(formerly 30A, 119) -Plan: 1H -118 -Rig: 43.10 209.75 43.10 206.20 -50.00 59.099 Centre Distance Pass - Major Risk Plan: IH -11 8 (formerly 30A, 119) -Plan: 1H -118 -Rig: 193.10 210.37 193.10 204.40 100.00 35.273 Clearance Factor Pass - Major Risk Plan : IH -118 (formerly 30A, 119) - Plan: 1 H-118 - 1 H-1 400.10 209.75 400.10 202.66 400.00 29.579 Centre Distance Pass - Major Risk Plan : 1H-118 (formerly 30A, 119) - Plan: 1 H-118 - 1 H-1 547.24 210.63 547.24 201.18 550.00 22.276 Clearance Factor Pass - Major Risk Plan: 1 H-119 (formerly 28A, 120) - Plan: 1 H-119 - 1 H-1 399.90 240.05 399.90 232.96 400.00 33.865 Centre Distance Pass - Major Risk Plan : 1 H-119 (formerly 28A, 120) - Plan: 1 H-119 - 1 H-1 546.64 240.93 546.64 231.48 550.00 25.500 Clearance Factor Pass - Major Risk Plan* 1H -120(A7035, formerly 117) -Plan: 1H-120-iH 424.86 270.02 424.86 262.42 425.00 35.497 Centre Distance Pass - Major Risk Plan :1H -120(A7035, formerly 117) - Plan : 1H-120-iH 619.09 271.19 619.09 260.80 625.00 26.098 Clearance Factor Pass - Major Risk 10 August. 2017 - 9:47 Page 3 of 6 COMPASS ConocoPhillips Anticollision Report for Plan: 11-1-111 (formerly 109, 32D) - 1 H-111wp22 Survey tool grogram From (usR) 39.00 500.00 1,500.00 1,784.53 1,784.53 To (usft) 500.00 1H-111wp22 1,50D.00 1 H-111wp22 1,784.53 1 1-1-111wp22 3,284.53 1H-111 wp22 8,050.49 1H-111 wp22 Ellipse error terms are correlated across survey tool tieon points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. SurveylPian Survey Tool GVD-GESS MWD MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit 10 August, 2017 - 9.47 Page 4 of 6 COMPASS ConocoPhillips Anticollision Report for Plan: 1H-111 (formerly 109, 32D) - 1H-111wp22 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: 54.1+39 @ 93.1 Dusft (Doyon 142). Northing and Easting are relative to Plan: 1 H-111 (formerly 109, 32D). Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150,00°, Grid Convergence at Surface is: 0.38 ". 900- 3 O O co C O 600- 4 a) U) (D b C iU O N U Ladder Plot -4- 111-05, -t- 1H40' -dr- Plan:1 1500 3000 4500 6000 Measured Depth (1500 usitfin) 7500 $ ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit 5,1 F+105 V6 J), 1H-401, 1 H-401 VO (formery31), Plan:1 H-102,1 H-102wp23 VO (bnnerty31), Plan: 11+1021-1, 11-1-1021-1 V23 VO (bnnery31), Plan:1 H-1021-2, 11-1-102L2vp23 VO (briery31), Plan:1 H-1021-3, 11+102L3v4)23 VO (brierly31), Plan: 1 I+102L4, 1 H-102L4vp23 VO (bmlerly 104,33), Plan: 11-103, 11+103wp21 VO (bmlerly104,33), Plan: 11-1031-1, 1 H-103L1wp21 VO (bnnery104,33), Plan: 11+1031-2, 1 K103L2wp21 VO (brmeN 104,33), Plan: 11+1031-3, 11+103L3wp21 VO (banally 104,33), Plan:1 H-1031-4,1H-1031-4wp2l (nev (brierly 101, 27), Plan: 111-104,1 K104wp21 VO (brmery 1 08,30E, 107), Plan: 11+106,1 F+106np21 VO (formerly 106,28E,112), Plan: t 1-107,1 H-107vp21 VO (briery 111,30D), Plan: 11-108, 11+108vvp21 VO (briery 110,30C), PIan:I K109,1 F+109wp21 VO (briery 111, 113,34D), Plan: 11-110,11-11 DNP21 VO (bnnery107,28D, 106), Plan: t H-112,1 H-112vp21 VO (formery112,34B),Plan: 11+113, 1 K113vvp21 VO (formerly 30B,116), Plan: 11-114,1 F+114vvp22 VO (brmery 115,34A,114), Plan:1 H-115,1 K11 BW21 VO (brmerly 114,328,115), Plan: 11.116,1 K11 W21 VO (brmery 118,28B), Plan: 11+117,1 K117wp22 VO (fonnery30A,119), Plan: 11-118, 11-118wp21.1 VO 10 August, 2017 - 9:47 Page 5 of 6 COMPASS Or *"j Plar f* Plar Plar 1� _ - Plar 1500 3000 4500 6000 Measured Depth (1500 usitfin) 7500 $ ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit 5,1 F+105 V6 J), 1H-401, 1 H-401 VO (formery31), Plan:1 H-102,1 H-102wp23 VO (bnnerty31), Plan: 11+1021-1, 11-1-1021-1 V23 VO (bnnery31), Plan:1 H-1021-2, 11-1-102L2vp23 VO (briery31), Plan:1 H-1021-3, 11+102L3v4)23 VO (brierly31), Plan: 1 I+102L4, 1 H-102L4vp23 VO (bmlerly 104,33), Plan: 11-103, 11+103wp21 VO (bmlerly104,33), Plan: 11-1031-1, 1 H-103L1wp21 VO (bnnery104,33), Plan: 11+1031-2, 1 K103L2wp21 VO (brmeN 104,33), Plan: 11+1031-3, 11+103L3wp21 VO (banally 104,33), Plan:1 H-1031-4,1H-1031-4wp2l (nev (brierly 101, 27), Plan: 111-104,1 K104wp21 VO (brmery 1 08,30E, 107), Plan: 11+106,1 F+106np21 VO (formerly 106,28E,112), Plan: t 1-107,1 H-107vp21 VO (briery 111,30D), Plan: 11-108, 11+108vvp21 VO (briery 110,30C), PIan:I K109,1 F+109wp21 VO (briery 111, 113,34D), Plan: 11-110,11-11 DNP21 VO (bnnery107,28D, 106), Plan: t H-112,1 H-112vp21 VO (formery112,34B),Plan: 11+113, 1 K113vvp21 VO (formerly 30B,116), Plan: 11-114,1 F+114vvp22 VO (brmery 115,34A,114), Plan:1 H-115,1 K11 BW21 VO (brmerly 114,328,115), Plan: 11.116,1 K11 W21 VO (brmery 118,28B), Plan: 11+117,1 K117wp22 VO (fonnery30A,119), Plan: 11-118, 11-118wp21.1 VO 10 August, 2017 - 9:47 Page 5 of 6 COMPASS ConocoPhillips Anticollision Report for Plan: 1H-111 (formerly 109, 32D)-1H-111wp22 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit 1-05, 1H -05V5 1-105, 1H -105V6 GNU), 11-1-401, 11-1-401 V0 102 (formerly3l) , Plan: 1H-102, 1H-102wp23 VO 102 (formerly 31) , Plan: 1 1-1-102L1, 1H-102L1wp23 VO 102 (formerly 31) , Plan: 1H -102L2. 1H-102L2wp23 V0 102(formerly 31) , Plan: IH -102L3, 1H-102L3wp23VO 102(formerly 31) , Plan: 1H -102L4, 1H-102L4wp23V0 103 (formerly 104,33), Plan: 1H -103,1H -10W1 VO 103(formerly 104,33), Plan: 1H-10311,1 H-103L1wp21 VO 103(formerly 104,33), Plan: 11-1-1031-2,1H-103L2wp21 VO 103(formerly 104,33), Plan: iH-1031-3, 1H-103L3wp21 VO 103(formerly 104,33), Plan: 1H -103L4, 11-1-1031,4wp2l (new INC -ON 104(formerly 101, 27), Plan: 11-1-104, 11-1-104wp21 VO 106 (formerly 108, 30E,107), Plan: 1 1-1-106,1 H-100wp21 VO 107 (formerly 106,28E, 112), Plan:1H-107,1H-107wp21 VO 108(formerly 111, 30D), Plan: 11-1-1108, 1H-108wp2l VO 109 (formerly 110, 30C), Plan: 11-1-109,1 H-109wp21 VO 110(formerly 111,113, 34D), Plan: 1 H-110,1 H-110wp21 VO 112 (formerly 107,28D, 106), Plan: 1H-112,1H-112wp21 VO 113(formerly 112,348), Plan: 1H-113, 1H-113wp21 VO - 114(formerly 30B,116), Plan: 1H-114, 1H-114wp22VO 115 (formerly 115,34A, 114), Plan: 1H-115,1 H-115wp21 VO 116 (formerly 114,32B, 115), Plan: 1H-116,1 H-116wp21 VO 117 (formerly 118, 28B), Plan: 1H-117,1 H-117wp22 VO 118(formerly 30A, 119), Plan: 11-1-1118, 1H-118wp21.1 VO .118 (formerly 30A,119), Plan: 111-1-1118, Rig:1H-118VO 119(formerly28q 120), Plan: 1H-119,1H-119wp22VO 70 August, 2017 - 9:47 Page 6 of 6 COMPASS �F 1H-05,1 $ 1H-05,1 10.00 _ __ _ __..___ ___,.. $ 1H-401( -� Plan: 1H �f Plan: 1.H $ PlanAH $ PlanAH Plan: 1H ,.-. 7.50 C L -)(- Plan: 1H o $ Plan: 1H Plan: 1H o ( $ Plan: 1H LL!I $ Plan: 1H 5.00--- - ._ ;. t ! _.-_. $ Plan: 1H 0 $Plan: 1H 12 o. $Plan: 1H 3.75 .._ _ _. - _._ ,.__ __ _ _.. _ _ _..__ __. _. ..Plan: IH $ Plan: 1H $ Plan: 1H 2.50 - - - - _ - - -- --------- - - - - _I _._. ______ - - r--PlanrlH .., $ Plan: 1H -� Plan: 1H 1.25 an:1 H $ Plan: 1H -*- Plan: 1H o:oo PI :1H 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 00 -�an: Measured Depth (1500 usfKn) $ Plan 1H 1H ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit 1-05, 1H -05V5 1-105, 1H -105V6 GNU), 11-1-401, 11-1-401 V0 102 (formerly3l) , Plan: 1H-102, 1H-102wp23 VO 102 (formerly 31) , Plan: 1 1-1-102L1, 1H-102L1wp23 VO 102 (formerly 31) , Plan: 1H -102L2. 1H-102L2wp23 V0 102(formerly 31) , Plan: IH -102L3, 1H-102L3wp23VO 102(formerly 31) , Plan: 1H -102L4, 1H-102L4wp23V0 103 (formerly 104,33), Plan: 1H -103,1H -10W1 VO 103(formerly 104,33), Plan: 1H-10311,1 H-103L1wp21 VO 103(formerly 104,33), Plan: 11-1-1031-2,1H-103L2wp21 VO 103(formerly 104,33), Plan: iH-1031-3, 1H-103L3wp21 VO 103(formerly 104,33), Plan: 1H -103L4, 11-1-1031,4wp2l (new INC -ON 104(formerly 101, 27), Plan: 11-1-104, 11-1-104wp21 VO 106 (formerly 108, 30E,107), Plan: 1 1-1-106,1 H-100wp21 VO 107 (formerly 106,28E, 112), Plan:1H-107,1H-107wp21 VO 108(formerly 111, 30D), Plan: 11-1-1108, 1H-108wp2l VO 109 (formerly 110, 30C), Plan: 11-1-109,1 H-109wp21 VO 110(formerly 111,113, 34D), Plan: 1 H-110,1 H-110wp21 VO 112 (formerly 107,28D, 106), Plan: 1H-112,1H-112wp21 VO 113(formerly 112,348), Plan: 1H-113, 1H-113wp21 VO - 114(formerly 30B,116), Plan: 1H-114, 1H-114wp22VO 115 (formerly 115,34A, 114), Plan: 1H-115,1 H-115wp21 VO 116 (formerly 114,32B, 115), Plan: 1H-116,1 H-116wp21 VO 117 (formerly 118, 28B), Plan: 1H-117,1 H-117wp22 VO 118(formerly 30A, 119), Plan: 11-1-1118, 1H-118wp21.1 VO .118 (formerly 30A,119), Plan: 111-1-1118, Rig:1H-118VO 119(formerly28q 120), Plan: 1H-119,1H-119wp22VO 70 August, 2017 - 9:47 Page 6 of 6 COMPASS �I�I►� �II��>�I�II �-�I�IIIII Illuummlllll�llI SIIIII FIJI (� IIII I PI II Q II III IIII �III�w��IIIIfl�II�II�I�I�i rol q -•mwu MI161A° I III � �� I � I � 1� - I I i I" I ( �V ' ��Ifll plll,� ISI III IIII (III/P „IIIbI I ,IIII � I r °Ipl'll III a��I� IIIIIIII,I�Q�I/, 9p �,iI�J� III La1�@II1�11911111II��F IIIIIIIIIIIIIIPIIill!Ililllllllll Illllulli' r' °'°I�;�III�I �.`'lllllllllllj r r •� rr� ' �r •err rr ••rr r �r .-• • .• • •1TVID MID Name • 11 11 �� •- . 1 1 •• rr of so 1714.00 1784.53 10 ..,...°.Mim r' I �...........:....nne.m:11111111111111111!1111111!lillllllllllllll:% --.....;::rllilnnnlllllllllllil�llllll;Illl,i�luII�II1�lj�11► �annnnm...I,.__I�Ilnnnen®Ilmll��nml �� l� I�Ifp111rI I pvI �� Ilpur- IP�I' IIII I) � �' I� � IIIA �� (' Ir■nlpl ' �--�..mllllllll 'IeiNlllllllllflfllllml�I�II�.�,I�II ,O �r.•- II I �) I�mll l�l�� I�III III �I��U��N 1,11110 I .nlll�ll►° III: I'll vnp�"II (l I IIIII'!IIII�„� �nnm NI ,Iml�ollll r r r 10 2017 1 H-111 wp22 11 TVD MD Name MD Inc Azi TVD pth From Depth To Tool 39.00 0.00 0.00 39.00 39.00 500.00 GYD-GC-SS 20.10 0.00 0.00 420.10 500.00 1500.00 MWD .90 11.90 2.70 17.99 110.00 107.44 600.10 1200.10 1500.00 1784.53 MWD+IFR-AK-CAZ-SC 10.56 29.92 105.36 1563.77 1784.53 3284.53 MWD 25.94 29.92 105.36 1663.77 1784.53 8050.49 MWD+IFR-AK-CAZ-SC 84.53 04.53 32.03 32.03 103.38 103.38 1714.00 1730.96 3270 - 3540 50.31 71.87 86.11 2365.36 4330-4860 60.65 71.87 86.11 3613.15 5390-5920 57.46 52.00 86.05 3945.70 6460 6990 00.49 52.00 86.05 3995.33 50.49 52.00 86.05 4272.38 11 TVD MD Name 118.10 118.10 20" x 42" 1714.00 1784.53 10 3/4" x 13-1/2 4272.37 8050.49 7" x 8-3/4" 270 240 H-114wp2 -_-- H-104wp2 - 210 H-109wp2 H-1�H-11 H-1 TC View Oleg TFace Target 0.00 0.00 0.00 0.00 1.50 110.00 2.50 -3.00 3.00 -5.00 0.00 0.00 4.00 -26.73 0.00 0.00 4.00 -25.03 0.00 0.00 4.00 -179.87 1 H-111 In 20Feb/5 BW 0.00 0.00 0.00 0.00 H-115wp21 H-11 Annotation KOP: Start 1.5%100' DLS, 110°TF, for 180.( Stan 2.5%100' DLS, -3°TF, for 611.73' Stan 3°/100' DLS, -5°TF, for 398.67' Hold for 115.38' Start 4°/100' DLS, -26.73°TF, for 58.59' Hold for W Start 4o/100' DLS,-25.03'TF, for 1045.78' Fold for 4010.34' Stan 4°/100' DLS,-179.87°TF, for 496.8' Hold for 243.04' Adjust TF to 0°, for 450' TD: 8050.49' MD, 4272.38' TVD 0 1111A, H-113wp21 (new INC -ONLY 39 420 420 600 600-790 60 790-970 970- 1150 1150- 1340 1340-1520 1520- 1700 1700- 1960 1960 2230 90 2230-2490 2490-2750 2750 -3010 3010-3270 3270 - 3540 3540-3800 3800-4330 4330-4860 120 4860-5390 5390-5920 5920 - 6460 6460 6990 6990 7520 7520-8050 (new INC -ONLY i I N Q N N 3 r M N MIDa � S O N 3 S Q .— x 'E^L V+ N 3 x F x RIM ci V + N 3 00 Q _ (r`,J S OGi p N O C N 3 a 0 o 0 M m N W a S N d 3 N N 3 N � Z r N N n 0 T T W T..... ......... 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U1, Y Ea^M NOOOO OOMOMOI� 00 0 hCO 2N Q Z ;ma XXn oOLO66O0OD) LiUDOO0OOT M0 uOi OO606 LL LL N N r T ¢00000 C) m 0 -6 207 22 1 Q W O 0 0 0 V t0 (O M OO r 4] Ln In Q 000 [t M MM 0" '77000 Q p 000 r Ln �M (hOMO (O (O >- 000cnmm F -o o�nma po�,m —O O O O OCO aOW WM o W > LOO d' O O O M m N a�'n Z Z m� 0 N 2 No m mm D Q U ��o m ❑ OO-OCDa MM W CO OO O� �� MtUN MCO. d. ¢' y �000NN o Oh ooN . � MO O r O LO d'V O4=k MN O N NOtnO� OLn oio Od'O mvoiuoi,xkn ��nN a CON Mn r W W MM COO �•-•--��NCO I�I�aD t n > a m O c D O O O O O O O O c o O O O O O O O O O O O M �t .V O M M M LO r h It Cr M (o M N (0 M N M N O O r r CO LO f, M N�t r� O N M W M M CO M� M M O CO I, M r r r r r N N N M M M M It d M Un (O CO I- M o O O O O O O O O O O O O O O O O O O O O O O O O M N O M I, Mn t N O (O M M M, I� O M CO M N CO M N M r M Mn I� M N d' r� O N Ln M M CO M M M Ln N M M M M 't � LO Ln (o CO I- a0 O N (O r O ciLO m O co z _ N III Q O O i O QCv] M _ GD� 00 LO co I 2 O .= O co Cl) N N � o ONco 0 O r T c\l T T U U N mN ? E a m N 000000 M O M OIC 00 2 Y Y m 0 0 0 p 0 0 0 0 0 0 W 0 0 M L n D O f J O Q 0 0 Z-. O O O I k O T 2N (.J LL LL Nar m ¢ UO 0 0 0 0 p W Q 0 0 0 7 M M M M 0 0 0 ¢ o 000�ri riMMcp co co co co r a 000m Mm � ooinN7 (D Q ��a 0000O�p pj ro N w o w s oovvo oommn Z ciao o U 0001�Oc07 MMS �cpOT in C7 (077 E000mm 0000Ln n on oOm moo.-rmnrnui oioo�o�ri7aoo�oo MNO�� N W ONO�U O�II iymooaC -ynj 7cON(O I�h cONpM c00 D N ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: IH -111 (formerly 109, 32D) 50103xxxxx00 Plan: IH -111 Plan: 1H-111wp22 Error Ellipse Survey Report 10 August, 2017 Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kupamk River Unit Site: Kupamk 1H Pad Well: Plan: 1 H-111 (formerly 109, 32D) Wellbore: Plan: 1H-111 Design: 1H-11lwp22 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors am at Database: Well Plan: 1H-111 (formerly 109,32D) Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.1 Dusft (Doyon 142) Tme Minimum Curvature 1.00 sigma OAKEDMP2 Project Kupamk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kupamk 1H Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.37 ° fell Plan: 1H-111 (formerly 109,32D) fell Position +N/S 0.00 usft Northing: Latitude: Version: +E/ -W 0.00 usft Easting: Longitude: osltion Uncertainty 0.00 usft Wellhead Elevation: Ground Level: 54.10 u: Wellbore Plan: 114-111 Magnetics Model Name Sample Date BGGM2017 8/4/2017 Declination Dip Angle (°) ) 17.56 80 95 Field Strength (nT) 57,493.79 Design 1H-111wp22 Date 8/42017 Audit Notes: To Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 500.00 Net) (usft) lust) (°) 1,500.00 39.00 0.00 0.00 86.00 Survey Tool Program Date 8/42017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 500.00 1H-111wp22(Plan: 1 H-111) GYD-GC-SS Gyrodata gyro single shots 500.00 1,500+00 1H-111wp22(Plan: 1 H-111) MWD MWD - Standard 1,500.00 1,784.53 1H-111 wp22(Plan: 1 H-111) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1,784.53 3,284.53 1 H-11lwp22 (Plan: 1 H-111) MWD MWD - Standard 1,784.53 8,050.49 1H-111wp22(Plan: 1H-111) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/10/2017 9:46, OOAM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well Plan: 1H-111 (formerly 109, 32D) Project: Kuparuk River Unit TVD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Well: Plan: 1H-111 (formerly 109, 32D) North Reference: Tme Wellbore: Plan: 1H-111 Survey Calculation Method: Minimum Curvature Design: 1H-111wp22 Output errors are at 1.00 sigma Moth Database: OAKEDMP2 Plan Survey Tool Program Date 8/4/2017 Depth From Depth To (usft) (usft) Survey (Wellbore) 1 39.00 500.001H-111wp22(Plan: 1H-111) 2 500.00 1,500.00 1H-111wp22 (Plan: 1H-111) 3 1,500.00 1,784.53 1H-111wp22 (Plan: 1H-111) 4 1,784.53 3,284.53 1H-111wp22 (Plan: 1H-111) 5 1,784.53 8,050.49 1H-111wp22 (Plan: 1H-111) Tool Name GYD-GC-SS Gyrodata gyro single shots MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD MWD - Standard MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC Remarks Position uncertainty and blas at survey station Measured Inclination / krutl, WNcal Hi9M1SWs lateral Varlicdl Ma9nllu" Semi+nwr Semlminar Moth Depth E. Bias Eno, Blas E., alas of aus Error Error Arimulh Tool (usm (°) (°) lusft) tuaft) (us") Dash) Davit) (use) wan) (usft) (waft) Duval (') 39 DO am 000 3900 0.00 000 000 0.00 000 000 0.00 000 000 000 UNDEFINED 100.00 0.00 000 10000 0.04 000 004 0.00 1.15 0.0 0.00 004 0.04 000 GYD-GC.SS(1, 1) 118.10 0.00 00 118.10 0.19 am 0.19 0.00 1.15 D.0 0.00 0.19 0.19 0.00 GYD-GC-SS (1, 1) 200.00 0.00 0.0 200.0 0.19 am 0.19 Om 1.15 000 0.00 0.19 DAD 0.00 GYD-GC-ss(1, t) 300.00 0.00 am 30000 0.33 0.00 0.33 000 1.15 0.01 0.01 0.33 0.33 0 D GYD-GGSS(1, 1) 40000 0.00 0.00 40000 040 0.00 048 0.00 1.15 001 0.01 0.48 048 0.00 GYD-G0SS(1, 1) 42010 0 00 0.00 420.10 0.51 am 051 am 1.15 0.01 0.01 0.51 0.51 0.00 GYD-GPSS (1, 1) 500.00 1,20 110.00 499.99 ool? am 0.59 am 1.15 0.02 062 0.59 0.59 45.00 GYD-GGSS (1, 1) &DODO 290 110.00 599.93 063 0.00 0.63 0.0 1.15 0.03 003 0.03 0.63 14.26 MNID(1. 2) 600.19 270 11000 600,10 0.63 am 063 0.0 1.15 0.03 003 0.0 0.63 1426 MWD (1, 2) 700.00 5.20 10856 69969 065 0.00 D.66 00 1.15 005 005 0.66 085 118.38 MWD(1, 2) 80.0 7.69 108.05 799.05 0.69 4101 075 0.01 1.15 0.07 0.07 075 0.70 113.55 MWD(1. 2) 900.00 10.19 107.79 09782 075 -Dol 0.91 0.03 115 0.09 009 0.91 077 111.74 MWD(1, 2) 1,00000 12.69 107.63 99583 082 -0.01 1.16 005 1.15 0.11 0.12 1.16 085 110.76 MWD(1. 2) 1,100.00 1519 107.52 1.09287 0.91 -002 149 0.08 1.14 0.13 0.16 1.49 0.96 11013 MM (1, 2) 1,20000 17.69 107.45 1,188.78 1.02 -003 1.90 0.13 1.14 0.16 021 1.90 1,08 109.69 MM(1.2) 1,211.90 17.99 107,44 1,200.10 103 -0.03 1.95 0.13 1.14 0.16 0.21 1.95 1.10 10966 MM (1, 2) 1.300.00 2063 106]8 1,28324 1.14 -0.04 239 0.19 1.14 0.19 0.27 239 1.21 10930 MWD(1, 2) 1,40000 2362 106.21 1,375.87 127 -0.05 2.97 0.27 1.14 0.22 035 2.97 1.35 108.06 MM (1, 2) 1,50000 2861 105.76 1466.41 141 -0.06 364 038 1.14 0.25 0.46 364 1.50 10842 MWD(1, 2) 1,60000 29.61 10540 1,554.60 140 -0.08 4.06 044 1.13 028 0.52 4.% 160 108.18 MWDHFR-MD- -SC(1, 3) 1.61056 29.92 105.35 1,563.77 140 -0.0 407 0.44 1.12 0.28 0.53 407 1.61 108.18 MM1lFR- -CAZ-GC(1. 3) 170.00 29.92 10535 1,641.29 149 -0.08 4.20 044 1.12 D.31 0.54 4.20 162 10808 MWD+IFR-RKCAZ-SC(1, 3) 1,72594 2982 105.36 1,663.77 150 -0.D8 424 044 1.13 0.32 0.55 425 162 10805 WM+IFR-AWCAZ-SC(1, 3) 1,784.53 3203 10338 1,714.00 151 -0.11 442 049 1.12 0.36 060 443 164 10185 MM (1, 4) 1,000.0 32.03 103.38 1,727.11 1.51 -0.11 4.50 0.51 1.12 0.35 063 4.51 1.65 10776 MM (1. 4) 1,004.53 3203 103.38 1,73088 1.51 -0.11 4.52 0.52 1.12 0.35 063 40 1.65 10173 MM (1, 4) 1,9000 35.52 10060 1,01030 1.55 -0.15 5.06 0.69 1.12 0.38 0.80 5.09 1m 10.89 MM(1.4) 2,000.DD 39.24 98.16 1,BB9.75 1.63 -020 5.79 0.91 1.12 0.42 100 5.84 176 105.70 MWD(I. D 2.100.00 43.0 96.08 1.855.07 175 -026 667 1.15 1.15 045 124 873 1.85 104.33 MM (1. 4) 2,200.00 46.79 94.27 2,035.90 189 -031 760 1.44 1.22 0.48 1.52 776 196 102.89 MWD(1. 4) 8/102017 9:46:OOAM Page 3 COMPASS 5000.14 Build 85 Company: ConomPhillips (Alaska) Inc. -Kup1 Project: Kupawk River Unit Site: Kupamk 1 H Pad Well: Plan: 1 H-111 (formerly 109, 32D) Wellbore: Plan: 1H-111 Design: 1H-111wp22 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1H-111 (formerly 109, 32D) Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.1 Ousft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station Measured 1.11.440 Atlmuth Vertical Iighaid. Idceral Venice Ma9nKude semiavajor Sem.a,lo.r Depth Depth Error Bias Emr Not Error Bias tit Bias Error Error Azimuth Tool loan) (°) 1°1 (..ft) (.on) (usit) laaa) (-aft) (usm (use) (usR) (use) ("aa) (9 2,300.00 5061 92.68 2.101.89 2.06 .036 881 1.75 1.33 0.51 183 8.91 2.09 10149 MVM (1, 4) 2,40000 54.45 91.25 2.162.72 2.25 4).42 1004 2.10 147 0.54 2.17 10.16 2.22 100.15 MWD(1, 4) 2,500.00 58.30 Bass 2,218.09 2.44 -047 11.36 2.49 lell 057 2.55 11.50 2.36 9890 MWD(1, 4) 2,600.00 62.16 88,77 2,287.73 2.65 -0.52 12.76 290 1.89 0.59 2.98 12.91 249 97,74 MWD(1, 4) 2,70000 6004 87.68 2,31140 2.86 -0.% 1421 3.34 2.14 061 3.39 14.30 261 %.67 MAD (1, 4) 2,800.00 69.92 wall 2,34890 300 -0.60 15.70 3.80 2.43 062 3.85 15.89 2.1 95.68 MWD(1, 4) 2.850.31 7187 Nil 2.38538 3.18 -062 1646 4.04 2.57 063 4.09 16.67 238 9520 MM (1, 4) 2,900.00 7187 86.11 2,98082 334 -062 17,25 4.28 2.73 064 4.33 17,44 283 9436 MM (1, 4) 3,0DO.00 ]18] 66.11 2,411.94 367 -062 18.64 /7] 3.05 085 4.81 19.01 292 93.98 MM (1, 4) 3,10000 71.87 86.11 2,44305 3.99 -062 20.44 5.25 337 067 529 2060. 301 9333 MM (1, 4) 3200.00 7187 86.11 2,4]4.1] 4.33 -0.62 22.05 5.73 3,70 068 577 22.19 3.10 9277 MM (1. 4) 3300.00 71.87 86.11 2,505.28 280 -0.50 10.36 0.49 2.19 069 098 1050 2.43 95.93 MWD+IFR-AK-CA -SC (2,4) 3,40080 71.87 08.11 2,536.39 2.76 -050 10.92 049 235 0.71 102 11.05 2.47 95.35 MND+IFRAK-CA -SC (2,4) 3,50000 7187 86.11 2.567.51 2.92 -0.50 1140 0.49 250 0.72 105 1161 2.51 94.84 MWD+IFR-AK-CA -SC (2, 4) 3,600.00 71.87 8611 2,590.62 308 -0.% 12.05 0.49 2.86 074 1.09 12.17 2.55 94.30 MW IFR AK -CA -SG (2,4) 3,70000 71.87 80.11 2.629.74 3.24 -050 12.62 049 2.82 0.75 1.13 12.73 2.59 93.95 MND+IFRAK-GA -SG (2,4) 3,80000 7187 86.11 2.860.05 3.40 -0.50 13.19 049 290 0.77 1.16 1330 2.63 9350 MM -IFR -ML -&C(2,4) 3,90000 71.87 86.11 2,691.97 3.57 -0.50 13.77 049 3.14 0.78 1.20 13.87 268 9324 MM+IFR-AK-CA-SC(2.4) 4.00000 71.87 86.11 2,72308 3.73 -0.50 14.35 049 3.30 0.00 125 14.45 2.72 9293 1iW0+IFR-AKCA2-SC(2,4) 4,100.00 71.87 86.11 2,754.19 3.90 -0.50 14.93 049 3.47 0.82 129 1502 276 92.64 MW0+1FR-AK-CA-SC(2.4) 4.200.00 71.87 86.11 2,78531 4.07 A.50 15.51 0.49 363 0.83 1.34 1560 280 9238 MWD+1FR-AR-0A-SC(2,4) 4,300.00 71.87 86.11 2,81642 4.24 -050 16.09 0.49 379 0.85 1.30 18.10 2.84 9214 MWD+1FR-AK-CA2-SC(2,4) 4,400.00 7187 86.11 2,847.54 4.40 -0.50 1667 0.49 3.95 Oar 1.43 16.75 2.89 91.91 MWD+IFR-AWLAZSC(2,4) 4,50000 71.87 8511 2.878.65 457 -0.50 1].26 0.49 4.12 0.88 1.40 1]34 293 91.71 MWD+IFR-AK-CA -SC (2.4) 4,600.00 71.87 86.11 2,909.76 4.74 -0.50 R85 0.49 428 090 153 17.92 2.97 91.52 MWD+IFR-AK-CA-S0(2,4) 4,700.00 7187 86.11 2.940.06 4.91 -0% 18.43 049 4.44 0.92 1.58 18.54 302 91.34 MWD+1FR-AK-CA-SC(2,4) 4,800.00 7187 86.11 2.97199 5.08 -0.50 1902 049 4.61 0.91 163 1909 3.06 91.17 MWD+IFR-AK-CA -SC (2, 4) 4,900.00 ]1.8] 86.11 3,003.11 525 -0.50 19.61 049 4.77 095 1.68 1988 3.10 91.02 MWDNFR-AK-CA-SC(2,4) 5.000,0 ]1.8] MAI 3,034.22 5.42 -0.50 2D.20 049 4,94 097 174 20.27 3.15 90.87 MWD+IFR-AK-CA-SC (2.4) 5,100.00 7187 85.11 3.08533 5.59 -0.50 20.79 0.49 5.10 0.99 1.79 20.86 3.19 9034 MWD+IFR-AK-0A-SC(2,4) 5,20000 71.87 08.11 3,09645 517 -050 21.30 049 5.27 1.01 185 21.45 324 90.61 MWD+IFR-AK-CA-W(2.4) 5300.00 71.07 08.11 3.127.56 594 -050 21.97 0.49 543 1.03 191 22.04 3.28 90.49 MWD+IFR-AH-CA-SC(2,4) 5,400.00 71.87 86.11 3,15868 811 -0.50 22.58 0.49 5,60 105 1.% 2283 3.33 90.38 MWD+IFR-AK-CA-SC(2,4) 5,%D00 71.87 86.11 3.189.79 8.28 -050 23.16 0.49 576 107 2.02 2322 338 90.27 MWD+IFR-AK-CA -SC (2,4) $.800.00 7187 86.11 3.22090 6.45 .0.50 n.75 049 593 109 208 23.81 3.42 90.17 MM+IFRAK-CA-SC(2, 4) 5,700.00 7187 86.11 3,25202 663 -0.50 2634 049 6.09 111 2.15 2440 3.47 90.07 MWD+IFRAK-CAZSC(2, 4) 5.800.00 71.87 MAI 3,283.13 8.00 -0.50 24.94 049 6.26 1.13 221 24.99 3.52 89.90 MWD+IFRAK-CALSC(2. 4) 5,900.00 71.87 86.11 3,31425 697 -0.50 25.55 049 6,42 1.15 227 25.59 3.56 8990 MND+IFRAK-CA-SC(2,4) 500000 7187 86.11 3,34536 7.14 -050 28.12 0.49 6.59 117 234 26.18 361 8981 MW0+1FR-AK-CA-SC(2.4) 0,100.00 7187 86.11 3,370.48 7.32 -050 2872 0.49 675 1.19 240 26.77 366 0934 MVM -IFR -M-0 -SC (2.4) 6,20000 71.87 86.11 3407.59 7.49 -0150 2]31 049 6.92 122 2.47 27.37 371 89.66 MWD+1FR-AR-CA-SC(2.4) 6,30o w 71,87 88.11 3,438.]0 7.66 .0m 27,91 049 TO 1.24 2.54 27.96 175 09.59 MM+IFR-AR-CAZSC (2,4) 6,400.00 7187 86,11 3,469.82 7.83 -0.50 2850 0.49 725 1.26 261 2855 3.80 89.52 MWD+IFR-AK-CA -SC (2+ 4) 6.500.00 ]1.8] 80.11 3,500.93 001 -0.50 29.10 a49 7,41 128 260 29.15 385 89.46 MWD+IFR-AK-CA -SC (2,4) 6,60000 7187 86.11 3.53205 8.18 .0.50 29.70 049 7,50 1.30 2.75 2974 3.90 89.40 MWD+IFRAK-M-SC(2, 41 8,700.00 71.87 86.11 3,563.16 8.35 -050 30.29 049 7.75 133 2.02 30.34 3.95 89.34 MWDHFRAK-CASK(2.4) 6,80000 71.87 88.11 3,59427 8.53 -050 30.09 049 7.91 1.35 2.89 30.94 4.00 89.20 M0D+IFRAK-CM-SC(2,4) 6,860.65 71.87 86.11 31813.15 8.53 -0.50 3125 0.49 0.01 1.36 293 31.30 4.03 8925 MWD+IFR-MK- -SC (2.4) 8,900.00 70.30 86.10 3,625.90 872 -042 31.46 049 0.08 1.37 2.96 31.50 4.05 89.23 MWD+IFR-AK-CA-W(2.4) ],00000 6630 sees 3.682,07 8.91 -0.22 31.92 049 824 140 304 31.96 4.10 8920 MWD+IFR-AK-CA SC (2.4) 7.100.00 8230 86.08 3,708.23 905 -0.01 32.37 0.49 8.39 144 3.13 3241 4.15 09.16 MWD+IFR-AK-CA-SC(2,4) 7,200.00 58.30 86.07 3,]55.7] 9.16 0.21 32.81 049 851 149 3.23 32.85 421 89.13 MW0+1FR-AK-CA-SO(2, 4) 7,300.00 54.30 8606 3.81124 921 0.44 3323 0.49 880 1M 3.33 3327 4.20 89.11 MWD+IFR-AK-CA-SC(2, 4) 7,35746 52.00 Was 3,845.70 9.22 0.57 33.46 049 8.75 150 3.39 33.51 4.32 89.10 MW IFRAK-CA-SC (2, 4) 8/10/2017 9:46:OOAM Page 4 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kupauk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-111 (formerly 109, 32D) Wellbom: Plan: 1H-111 Design: 1H-111wp22 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1H-111 (formerly 109, 32D) Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Measured InclinMian AZimulh Verllaal Hi9hside 141era1 Target Name VeM.1 Ma9naude 6em,malm seml+unor oeoh •hWmiss target Dip Angle Dip Dir. TVD Depth Emor aiaa Emar Biaa Ertor Biaa dBiu Ermr Emr Azimuth Tool loan) (1) 19 (usft) lash) lush) (ush) (usft) lush) lift) (.1%) (ado (aft) f) 7,400.00 5200 8605 3,871.89 9.29 057 3365 0.49 8.81 161 3.43 33,70 4.35 09.08 MWD+1FR-AM-CAZ-SC(2.4) 7,500.00 5200 sees 3933.46 9W 0.57 34.10 0.49 0.93 1.68 3.54 34.23 444 0906 MWD+1FR-AK-OAZ-BC(2,4) 7,600.00 5200 Wes 3995.03 9.60 0.57 34.70 0.49 905 1.75 365 34.75 4,52 8903 MWD+1FR-AK-CAZ-SC(2,4) 7.600.49 52.00 06.05 3,995.33 960 057 34.70 0.49 905 1.75 365 34.75 4.52 89.03 MMNFR-AK-CAZ-SC(2,4) 7.70000 5200 86.05 4,058.59 9,75 0.57 352'3 0.49 9.10 1.82 3A 35.20 4.61 89.01 MWDNFR-AK-CAZ-SC(2,4) 7,800.00 52.00 86.05 4.118.16 9.91 0.57 35.76 0.49 930 1.69 3.88 3580 489 8800 MW IFR-AK-CAZ-SC(2,4) 7,900.00 52.00 8605 4,179.79 10,06 0.57 3829 0A9 9.43 1.97 4.00 36.33 4.78 8896 MW IFR -Mx M-SC(2,4) 8,00000 5200 Sees 4,24129 10.22 0.57 36.81 049 9.55 2.04 4.11 36.136 4.87 8894 MWV+IFR-MA -80 (2,4) 8,050.49 52.00 8605 4,272.38 10.30 0.57 Pea 0.49 9.61 208 4.18 37.13 4.91 88.93 MWD+IFR-Mr(-&C (2.4) Design Targets Vertical Depth Depth Target Name (usft) 118.10 118.10 20"x42" •hWmiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting •Shape (1) (1) Wall) (usft) (usft) (usft) (usft) Latitude Longitude 1H-111 D 080217 RP Wtl 0.00 0.00 3,805.39 -1,602.92 6,758.83 5,979,065.50 1,696,362.38 701 21' 13.850 N 149° 32'44.477 W - plan misses target center by 2024.02usft at 8050.49usft MD (4272.37 ND, 189.34 N, 5942.51 E) - Circle (radius 100.00) 1H-111 b 20Feb15 BW 0.00 0.00 3,845.70 151.72 5,397.68 5,980,811.00 1,694,989.88 70'21'31.118 N 149133' 24,227 W - plan hits target center - Circle (radius 100.00) Casing Points Measured Vertical Depth Depth (usft) (usft) 118.10 118.10 20"x42" 1,784.53 1,714.00 103/4"x13-1/2 8,050.49 4,272.38 7" x 8-3/4" Name Casing Diameter 20 10-3/4 7 Hole Diameter ("1 42 13-1/2 B-3/4 811012017 9:46,OOAM Page 5 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupamk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-111 (formerly 109, 32D) Wellbore: Plan: 1H-111 Design: 1H-11lwp22 Formations Measured Vertical Depth Depth Plan Annotations (usft) inert) 1,668.25 1,613.77 PFROST 1,869.49 1,785.30 T-3 2,159.76 2,007.96 K-15 5,247.57 3,111.25 UG_C 6,036.67 3,356.77 UG_B 6,438.93 3,481.93 UG_A 6,870.50 3,616.24 Na 7,217.21 3,764.90 WS_D 7,306.30 3,814.93 WS._C 7,340.52 3,835.35 WS_B 7,398.71 3,871.10 WS -A4 7,469.92 3,914.94 WS -A3 7,600.49 3,995.33 WS A2 7,765.81 4,097.11 WS Al 7,900.77 4,180.20 WS -BASE Name ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1H-111 (formerly 109, 32D) Plan: 54.1+39 @ 93.10usR (Doyon 142) Plan: 54.1+39 @ 93.10usR (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Dip Dip Direction Lithology (1) (1) 8/102017 9:46:OOAM Page 6 COMPASS 5000.14 Build 85 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W inert) (usft) (usft) (usft) Comment 420.10 420.10 0.00 0.00 KOP: Start 1.5°/100' DLS, 110° TF, for 180.07' 600.17 600.10 -1.45 3.99 Start 2.5'/100' DLS, -3° TF, for 611.73' 1,211.90 1,200.10 -34.89 108.28 Start Wit 00' DLS, -5° TF, for 398.67' 1,610.56 1,563.77 -79.85 263.47 Hold for 115.38' 1,725.94 1,663.77 -95.10 318.96 Start 4"/100' DLS, -26.73° TF, for 58.59' 1,784.53 1,714.00 -102.57 348.18 Hold for 20' 1,804.53 1,730.96 -105.02 358.50 Start 4"/100' DLS, -25.03° TF, for 1045.78' 2,850.31 2,365.36 -136.87 1,160.02 Hold for 4010.34' 6,860.65 3,613.15 121.91 4,962.51 Start 4.1100' DLS, -179.87° TF, for 496.8' 7,357.46 3,845.70 151.72 5,397.68 Hold for 243.04' 7,600.49 3,995.33 164.91 5,588.75 Adjust TF to 0°, for 450' 8,050.49 4,272.38 189.34 5,942.51 TD: 8050.49' MD, 4272.38' TVD Checked By. Approved By: Date: 8/102017 9:46:OOAM Page 6 COMPASS 5000.14 Build 85 Pool Report 10:00, A t 10 R➢1� 1 H-111 wp22 Quarter Mile View IH -11 9wp 2 1H-118wp711 1fH _3Ca203L4wp21�F� IJC-O19H#N wp -120w 1 _114w 2 9 19S 2550 1700 S 850 N J O OJ s r z 0 s 5 0 850 1 -1700 1H-11 1 H-116 1 H-117wp _ 1 H-109 ig 1 1 H-111 wp22 1 411 n4WRn 850 1700 2550 3400 4250 5100 5950 6800 7650 West( -)/East(+) (850 usft/in) m 1H-111wp22 Surface Location .M CPA7 Coordinate From: Datura NAD63 Region: lalaska f• Latitude/Longitude jDaurnalDegrees, C UTM Zone: r- r- South • State Plane Zone: r4 `-:,] Units: urlt . C Legal Description (NAD27 only) Toc Datum: NAD27 Region alaska C Latitude/Longitude IDecimalDegrees r UTM Zone: True f— South G State Plane Zone: I" J Urds: ustt C Legal Description (NAD27 only) Starting Coordinates: F Ending Coordinates:- --- -- X: 1689593.83 X: 549562.207159183 Y: 5980623.86 Y: 5%0872.04887523 i Transform i quit Help 1H-111wp22 Surface Location Q CPX Coordinate Converter From. Datum: FN—AD-8-3---,l Region: alaska _J * Latitude/Longdude IDecimalDegrees r UTM Zone: r' r South 6' State Plane Zone: ] Unity. us -Ft �;,ki n ir! U)-'7 only] Starting Coordinates: ------- x: 1689593.83 Y: 5980623.86 To: Datum: Npp27 Region: alaska C' Latitude/Longitude IDecknal Degrees—� C UTM Zone: True r South r' State Plane Zone: I' J Unils: F. . i 6 Legal Description (NAD27 only) Township: 012 I"J Range: 010 FJ] Meridian: IU� Sectionf28 FSL 169.08261 FEL 778.048% �Transfarm __ ' Quit Help 1H-111wp22 Surface Casing Q CPAI Coordinate From:___. 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Ft r Legal Description (NAD27 only) To: - - Datum: INAD27 Region: alaska • Latitude/Longitude IDecimalDegrees f•UTM Zone:True r South (: State Plane Zone: F--il Units: us{t r Legal Descr'ption (NAD27 only) Starting Coordinates: -------- -Ending Coordnates: --� X: 1694989.E IIS Y- 15549511713062056 i Y: 1598W11.00 Y: 5981059.09229698 -Transform __ Quit Help 1H-111wp22 Production Horizon 4 CPA] Coordinate Converter From: - Datum: NAD83 Region: alaska r LatludOl-ongdude iDecimalDegrees f UTM Zone: F— r South G State Plane Zone: Unts: us fl C la „ I - Starting Coordnates: - ---------- ---- - -- X: 1694989.88 Y: 5980811.00 To Datum: INAD27 Region alaska r LetRude/Longitude Decimal Degrees • UTM Zone: Tne r South • Stale Plane Zone: F ----J Units: -.ry G Legal Description (NAD27 only) Towrahip: � Ott Range: 010 I` J Meridian FU -----j SCOM 27 F---3 318.49282 FEL 660.10422 Transform Quit Help 1H-111wn22 TD Q CPAI Coordinate Converter From:.._....___.. __ To:-- ¢Datum: Datum:NAD63 Region: alaska Datum NAD27 Region: alaska I T Latitude/Longitude iDecimalDegiew r LaUlude/Longitude iDecknalDegrees r UTM Zone: r South F C UTM Zone: Truer South f. State Plane Zone: Units:us Ft f• Slate Plane Zone: 4F Units: w.ft ?' Legal Description (NAD27 only) C Legal Description (NAD27 only) _' Starting Coordinates: r Ending Coordinates: X: 11695534.39 X: 555502.678952424 Y 5980852.19 Y 5981100.26100091 ( ................_Transform Qua Help 1H-111wp22 TD M CPAICoordinate Conerter From: Datum: FNAD83 Region: alaska (' LatitudeA-ongitude IDecimalDegrees * UTM Zone: C— r South f State Plane Zone:rUnits: usft _alDescnpti��rINAD2?oedyi Starting Coordnates: - ---- X: 1695534.39 Y: 5980852.19 Datum NAD27 Region: alaska r Latitude/Longitude Decimal Degrees —� f•UTM Zone: True r South • State Plane Zone:r -:( Umis us -ft f• Legal Descrplion (NAD27 only)) Legal Description ----- - -- Tmnship: 012 I'"J Range: 010 Meridian: l" - Section: 27 FSL . 355.65629 FEL . 115.21293 Transform Quit I Help As -built 1 12/05/01 MRT I CC I IRev. Per K05014ACS 12 02/01/11 JAH I LGM I Rev. Per K170005ACS *12 N e11 25 30 29 26 27 I 1 25 016 *21 *15 I 61 _ 92 07 36 KCS 31 IH 32 33 34 35 36 T1 N 1 T11NNIOE 5 4 3 6� 2 1 0120 IA ASP GRID NORTH 118 2 CPPl ,�v 10. 7 C 6 9 Fro it z 0117 0116 0115 18 7 16 s 4 3 0114 ,E LEGEND 0113In 0112 to za 24 19 20 21 2 23 0 AS—BUILT CONDUCTOR ®111 0110 VICINITY MAP • EXISTING CONDUCTOR 0109 SCALE: 1" = 2 MILES 0104 0108 ®103 28 27 33 34 0102 0106 0101 DS1H *UGNU 01 •4 SEE SHEET 2 & 3 FOR COORDINATE TABLE NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSO 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS 28 AND 33, TOWNSHIP 12 NORTH, RANGE 10 EAST, UMIAT MERIDIAN, ALASKA. 5. DATES OF SURVEY: 12-26-16 THRU 1-31-17 FIELD BOOKS 1_16-35, L16-40, L17-02 & L17-03. 6. ALL DISTANCES SHOWN ARE GROUND. GRAPHIC SCALE 0 00 200 400 1 inch = 200 ft. f&LOUNSBURY x A&40CU7W, INC. URWYORS ENGINEERS PL NM ConocoPhillips WELL DS1H CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CALK6 08d31 2/05/05 DRAWING NO. CEA—D1HX-6108D31 PART' 1 OF 3 REV: 2 914 05 920 *12 019 e11 •22 *10 *17 06 016 *21 *15 913 61 •9 92 07 03 e18 •8 •4 SEE SHEET 2 & 3 FOR COORDINATE TABLE NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSO 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS 28 AND 33, TOWNSHIP 12 NORTH, RANGE 10 EAST, UMIAT MERIDIAN, ALASKA. 5. DATES OF SURVEY: 12-26-16 THRU 1-31-17 FIELD BOOKS 1_16-35, L16-40, L17-02 & L17-03. 6. ALL DISTANCES SHOWN ARE GROUND. GRAPHIC SCALE 0 00 200 400 1 inch = 200 ft. f&LOUNSBURY x A&40CU7W, INC. URWYORS ENGINEERS PL NM ConocoPhillips WELL DS1H CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CALK6 08d31 2/05/05 DRAWING NO. CEA—D1HX-6108D31 PART' 1 OF 3 REV: 2 1 1 102/01/14 JAH I LGM I lCreate Per K170005ACS I I I I I I I CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28, T. 12 N.. R. 10 E.. UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geo ra hic Coordinates Section Offset. Elev. Y X Lot. Long. F.S.L F.E.L. O.G. PAD *103 5,980,722.55' 549,573.20' N 70. 21' 29.220" W 149' 35' 50.536" 19' 768' 48.0' 54.1' *104 5,980,782.43' 549,568.74' N 70. 21' 29.809" W 149' 35' 50.655" 79' 772' 48.0' 54.1' *108 5,980,752.52' 549,570.98' N 70' 21' 29.515" W 149' 35' 50.595" 49' 770' 48.0' 54.0' *109 5,980,812.20' 549,566.50' N 70. 21' 30.102" W 149' 35' 50.714" 109' 774' 48.0' 54.0' *110 5,980,842.21' 549,564.40' N 70. 21' 30.398" W 149' 35' 50.770" 139' 776' 48.0' 54.0' *111 5,980,872.05' 549,562.21' N 70. 21' 30.691" W 149' 35' 50.828" 169' 778' 48.0' 54.1' *112 5,980,902.08' 549,559.94' N 70. 21' 30.987" W 149. 35' 50.889" 199' 780' 48.0' 54.0' *113 5,980,932.00' 549,557.76' N 70. 21' 31.281" W 149' 35' 50.947" 229' 782' 48.0' 54.0' *114 5,980,961.86' 549,555.50' N 70. 21' 31.575" W 149' 35' 51.006" 259' 784' 48.0' 54.1' *115 5,980,991.68' 549,553.43' N 70' 21' 31.868" W 149. 35. 51.062" 289' 786' 48.0* 54.1' *116 5,981,021.61' 549,551.58' N 70' 21' 32.163" W 149' 35' 51.110" 319' 787' 48.0' 54.1' *117 5,981,051.73' 549,548.80' N 70' 21' 32.459" W 149' 35' 51.185" 349' 790' 48.0' 54.0' *118 5,981,081.22' 549,546.95' N 70' 21' 32.750" W 149. 35' 51.234" 378' 791' 48.0' 54.0' *119 5,981,111.42' 549,544.52' N 70' 21' 33.047" W 149' 35' 51.299" 408' 794' 48.0' 54.2' *120 5,981,141.33' 549,542.48' N 70' 21' 33.341" W 149. 35' 51.353-1438- 795' 48.0' 54.1' * CONDUCTOR ASBUILT THIS SURVEY 0 "•"•......... 1SURVEYOR'S CERTIFICATE 49th / V ';♦// I HEREBY CERTIFY THAT 1 AM PROPERLY REGISTERED AND ................................ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY .................•"••'" ... DONE BY ME OR UNDER MY DIRECT SUPERVISION AND :MIAH F. CORNELL �: THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION LS -12663 °`: ARE CORRECT AS OF JANUARY 31, 2017. FfSSIONPt.�'I'D •• I O/tT" �� URLOUNSBURY aLTORS RS ASSOCIATEINC. NERS 1H Ihillips Alaska, Inc. DS1H WELL CONDUCTOR SBUILT LOCATIONS 6 1 CEA-D1HX-6108D31 1'""" 3 of LSI 1H-111 Drilling Hazards Summary 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strategy Broach of conductor Low Monitor cellar continuously during interval. Gas hydrates Moderate Control drill, reduced pump rates, reduced drilling fluid Abnormal reservoir pressure Low temperatures, additions of Lecithin. Running sands and gravels Low Maintain planned mud parameters, increase mud weight, Differential sticking Moderate use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), Hole swabbing on trips Moderate pumping out Washouts / hole sloughing Low Cool mud temperatures, minimize circulating times when Fault crossings and concretions Moderate possible. 8-3/4" Open Hole / 7" Casing Interval Hazard Risk Level Mitigation Strategy Running sands and gravels Low Maintain planned mud parameters, increase mud weight, use weighted sweeps. Stuck pipe Loµ, Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight. Abnormal reservoir pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, add LCM. Differential sticking Moderate Follow mud program, keep pipe moving when able. Anti -collision Moderate Follow real time surveys very closely. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out or back reaming. Getting casing to bottom Moderate Utilize proper drilling and hole cleaning practices, follow mud program. Fault crossings and concretions Moderate Use developed best practices for concretion drilling. 1H-111 Drilling Hazards.doc 8/25/201710:43:02 AM e 0 Wellhead/Tubing Hanger/Tree, IH -111 Infector Well Design 13-3/8" x 4-Y:" IBTM, SM PTD Wellbore Schematic Insulated Conductor 20" Casing Feed Through Packer 43: 7217'MD 2.812" Carrico DS Nipple Upper MMG Gauge Mandrel —,Z' Lower MMG Feed Through Packer 42: 7340'MD — Upper MMG Gauge Mandrel Lower MMC : 4-1/2"x3-12" tubing 10-3/4" 45.5#, L^80 HYD563DL Q 1785 ft MD 3-12", 9.2 #, L8Q EUEAB 3-12" MMG with SOV Feed Through Packer #1: 7399MD —01 2.75" Cameo D Nipple � Upper MMG L Gauge Mandrel — Lower MMG Baker WIV "D" Sand Perforations: 7179-7372'MD "B" Sand Perforations: 7322-7414'MD A2 perfs:7414.7458'MO A3 parts: 7561-7619'MO A4 perfs: 7606-7656'MD Top of float collar Scraper/Magnet Ass, J•-� 7" 269, L-80, HYD563/TXP Dumb iron mnleshoe /r 8050' MD ConocoPhillips Alaska, Inc. DRAWN BY: TITLE: DS1H LAYOUT DRAWING ALKET MICI I ATE O7 -J1-2017 REV: 1 Attachment 6 BOP Configuration The following ram configuration will be utilized for the West Sak wells. Further details regarding the BOPE specifications can be found with the Doyon 142 documentation on file with the State. Bettis, Patricia K (DOA) From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Friday, September 22, 2017 5:04 PM To: Bettis, Patricia K (DOA) Subject: Re: [EXTERNAL]KRU 1 H-111 (PTD 217-133): Permit to Drill Application Patricia, Good afternoon. No, ConocoPhillips will not be pre -producing the 1 H-111. The well is configured for injection only. Please let me know if you have any follow-up or further questions. Thanks, Tolman 307-231-3550 From: Bettis, Patricia K (DOA) Sent: Friday, 22 September, 4:59 pm Subject: [EXTERNAL]KRU 1 H-111 (PTD 217-133): Permit to Drill Application To: Tolman, Ben V Good afternoon Ben, Will ConocoPhillips pre -produce KRU 1 H-111; and if so, for what duration? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 71 Ave., Ste 100 Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or patricia.bettis(a)alaska.gov. Name KRU IH -111 I <== Data Input <== Data Mud Weight (ppg) 1 9.50 i <== Data Input Neak point or LOT - Measured depth (ft) 11786' <== Data Input Weak point or LOT True vertical depth (ft) 1,714' <== Data Input Neak point or LOT - Hole angle (deg) 30.0" <== Data Input Weak point or LOT - Hote size (in) 13.500" <== Data Input Weak point pressure or LOT - EMW (ppg) 11.50 <== Data Input Zone of interest - Measured depth (ft) 7,200' <== Data Input Zone of interest - True vertical depth (ft) 3,756' <== Data Input Zone of interest - Hole angle (deg) 58.30 <== Data Input Zone of interest - Hole size (in) 8.750" <== Data Input Zone of interest - Pore pressure EMW (ppg) 8.60 <== Data Input Gas gradient (psi/ft) 0.10 <== Data Input Bottom hole assembly OD (in) 1 8.0" <== Data Input Bottom hole assembly length (ft) I 15V <== Data Input Drill pipe OD (in) r-775-55-771 <== Data Input BHA annular vol @@ zone of interest} bbllft) I 0.0122 DP annular vol. zone of interest (bbl/ft) 0.0501 DP annular vol. A weak point bbllft 0.1528 margin (psi) i 0.00 <== Data Weak point pressure (psi): P10 1,025 psi Weak point pressure - safety margin: Max anticipated formation pressure (psi): Pmax Pmax EMW Pf 1,025 psi 11.50 ppg 1,680 psi Weak Pt to Zone of Interest distance (TVD ft): OH (TVD) 2,042' Weak Pt to Zone of Interest distance (MD ft): OH (MD) 5,415' Maximum influx height at the bit (TVD ft): H (TVD) 744' Maximum influx height at the bit (MD ft): H (MD) 1,417' Calc. volume of (H) around BHA: Calc. volume of (H) around drill pipe: Calc. volume that H equals @ initial shut in: V1 bha Vl dp V1 1.8 bbl 63.4 bbl 65.2 bbl Calc. vol. that H equals @ weak point (MD ft): VWp 131.3 bbi Calc. volume of Vwp Q initial shut in: V2 80.1 bbi V TRANSMITTAL LETTER CHECKLIST WELL NAME: f' p (ti 1} - (/ PTD: ai - 133 Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: Kt�k rt �C Z-V6r 't j4Sr � Q Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50 - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50— from from records, data and logs acquired for well name on permit). The permit is approved subject to fall 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) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are / also required for this well: Well Logging Requirements V 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