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Home My WebLink About218-053MEMORANDUM 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-115 KUPARUK RIV U WSAK 1H-115 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/08/2025 1H-115 50-029-23605-00-00 218-053-0 W SPT 3840 2180530 1500 1104 1101 1108 1107 275 280 280 280 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 U WSAK 1H-115 Inspection Date: Tubing OA Packer Depth 370 2020 1960 1950IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250823131413 BBL Pumped:1.9 BBL Returned:1.8 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-115 50-029-23605-00 218053_1H-115_IPROF RSTWFL_09May2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:34:11 -09'00' MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 4, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1H-115 KUPARUK RIV U WSAK I H-115 Src: Inspector Reviewed By: P.I. Supry Comm Well Name KUPARUK RIV U WSAK 1H-115 API Well Number 50-029-23605-00-00 Inspector Name: Bob Noble Permit Number• 218-053-0 Inspection Date: 8/2/2021 — Insp Num: mitRCN210802131354 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -- Type J Well IH -115 I e In' W- TVD 3840 TUbing 1130 - _ 1130 1130' 1130- PTD .i 2180530 ' Type Test! SPT- Test psi 1500 IA 430 1800—' 1750 - 1740_ - BBL Pumped: 1.4 B Returned: 14 OA 714 - 730 730 730 Interval) 4YRTST P/F 1 P - Notes: Wednesday, August 4, 2021 Page 1 of I 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: 2180530 E-Set: 34543 Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax 1H-119 -Thl-1115 1H-1086 IH -116 -00 64 65 Signature return via courier or sign/scan and email a copy Delivered to: AOGCC >. y ATTN: Natural Resources Technician II J Alaska oil & Gas Conservation Commision 1 333 W. 7th Ave, Suite 100 -- Anchorage, AK 99501 2 180 53 3 197 1 TRANSMITTALDATE.24-Jan-20 24Ja n20 -JW 02 RIVER WL IPROF FINAL FIELD 10 -Jan -20 1 RIVER WL IPROF-WFL FINAL FIELD 15•Jan-20 RIVER WL (PROF-WFL FINAL FIELD 1 16 -Jan -20 RIVER WL IPROF-WFL FINAL FIELD 1 17.1an-20 RIVER WL IPROF-WFL FINAL FIELD 1 18 -Jan -20 RIVER WL WFL FINAL FIELD 1 19 -Jan -20 RIVER WL1 IPROF FINAL FIELD 20 -Jan -20 1 Date and CPAI. Schlumberger -Private 7 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. Schlumberger -Private 2 190 53 Originated:1 1 9 4 Delivered to: Schlumberger TRANSMITTALD' 11-Se19 •s� 4 AOGCC TRANSMITTAL # 11 Se 19-JWo1 PTS - PRINT CENTER ATTN: Natural Resources Technician It 6411 A Street Anchorage, AK 99518 jx Alaska Oil & Gas Conservation Commision (907) 273-1700 main (907)273-4760 fax 333 7th Ave, Suite 100 --AA Anchoorr age, AK 99501 Schlumberger -Private Conocopvm-w ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 6, 2019 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7a' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Hollis French: air-os3 MAY 0 8 2019 AOGCC 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, 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 Dumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 1J-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 1 H-102 50029235800000 2170970 2'9" 0.65 8" 5/4/2019 1.7 5/5/2019 1 H-103 50029235930000 2180030 2'2.5" 1 0.45 9" 5/4/2019 2.2 1 5/5/2019 IH -104 50029236100000 2180840 2'.5" 1 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 IH -109 50029235950000 2180130 2'3" 0.40 9" 5/4/2019 2.2 5/5/2019 1H-110 50029236010000 2180310 2'6.5" 0.65 8.5" 5/4/2019 2 5/5/2019 1H-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 1H-117 50029236020000 2180320 1'11" 0.35 7" 5/4/2019 1.7 5/5/2019 1H-118 50029235780000 2170840 2'4" 0.50 8.5" 5/4/2019 2 5/5/2019 1 H-119 50029235910000 2171780 3' 0.8 0 8" 5/4/2019 1.8 5/5/2019 DATA SUBMITTAL COMPLIANCE REPORT 11/2612018 Permit to Drill 2180530 Well Name/No. KUPARUK RIV U WSAK 1H-115 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23605-00-00 MD 10706 TVD 4239 Completion Date 7/19/2018 Completion Status WAGIN Current Status WAGIN UIC Yes REQUIRED INFORMATION Mud Log No / Samples No �/ — Directional Survey Yes, / V DATA INFORMATION List of Logs Obtained: GR/ RES/ CBL/ CCL (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 ED C 29535 Digital Data 33 1802 _ 7/18/2018 _Comments Electronic Data Set, Filename: CPAI 1H- 115_Scope_Gamma Ray_LWD001_RM_LAS.Ias ED C 29535 Digital Data 1666 10706 7/18/2018 Electronic Data Set, Filename: CPAI_1H- 115_VISION_Resistivity_LW D002_RM_LAS.Ias ED C 29535 Digital Data 33 10706 7/18/2018 Electronic Data Set, Filename: CPAI-111-1- 115—VISION — ResistMty_RM LAS.Ias ED C 29535 Digital Data 7/18/2018 Electronic File: CPAI _1H- 115_Scope_Gamma_Ray_RM_DLIS_LW DO01.dli s ED C 29535 Digital Data 7/18/2018 Electronic File: CPAI _1H- 115_ Scope_Gamma_Ray_RM_DLIS_LW DOOt.ht ml ED C 29535 Digital Data 7/18/2018 Electronic File: CPAI 11-1- 115_V ISION_Resistivity_RM_DLIS_LW D002.diis ED C 29535 Digital Data 7/18/2018 Electronic File: CPAI-11-1- PAI1H- 115_VISION_Resistivity_RMDLIS_LW D002.htm 115 — VISION—Resistivity_RM I ED C 29535 Digital Data 7/18/2018 Electronic File: CPAI - _1H 115_V I S ION_Resistivity_DL IS_RM.d I is ED C 29535 Digital Data 7/18/2018 Electronic File: CPAI _1H- 115_VI SI ON_Resistivity_D LI S_RM. htmt ED C 29535 Digital Data 7/18/2018 Electronic File: CPAI 1H - 115_V IS I ON_Resistivity_2 MD_RM.pdf ED C 29535 Digital Data 7/18/2018 Electronic File: CPAI-1 H- 115_VISION_Resistivity_2TVD_RM.pdf ED C 29535 Digital Data 7/18/2018 Electronic File: CPAI 1H - 115_V I SI ON_Resistivity_5MD_RM. pdf AOGCC Page I of 7 Monday, November 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 11/26/2018 Permit to Drill 2180530 Well Name/No. KUPARUK RIV U WSAK 1H-115 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23605-00.00 MD 10706 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 ED C ED C AOGCC TVD 4239 29535 Digital Data 29535 Digital Data 29535 Digital Data 29535 Digital Data 29535 Digital Data 29535 Digital Data 29535 Digital Data 29535 Digital Data 29535 Digital Data 29535 Digital Data 29535 Digital Data 29535 Digital Data 29535 Digital Data 29535 Digital Data Completion Date 7/19/2018 29535 Log Header Scans 29547 Digital Data 29547 Digital Data Completion Status WAGIN Current Status WAGIN UIC Yes 7/18/2018 Electronic File: CPAI_1H- 115_V IS I ON_ Resistivity_5T V D_RM.pdf 7/18/2018 Electronic File: CPAI_1H-115_PdntSurveyList.csv 7/18/2018 Electronic File: Gyrodata Survey - 1 H-115 - Post SLB SAG.pdf 7/18/2018 Electronic File: Gyrodata Survey - 1 H-115 - Post SLB SAG.xlsx 7/18/2018 Electronic File: 1H-115 NAD27 EOW Compass Surveys [Canvas].txt 7/18/2018 Electronic File: 1H-115 NAD27 EOW Compass Surveys [Macro].txt 7/18/2018 Electronic File: 1H-115 NAD27 EOW Compass Surveys [Petrel].txt 7/18/2018 Electronic File: 1H-115 NAD27 EOW Compass Surveys [Surveys].txt 7/18/2018 Electronic File: 11-1-115 NAD27 EOW Compass Surveys.pdf 7/18/2018 Electronic File: 1H-115 NAD83 EOW Compass Surveys [Canvas].txt 7/18/2018 Electronic File: 1H-115 NAD83 EOW Compass Surveys [Macro].txt 7/18/2018 Electronic File: 1H-115 NAD83 EOW Compass Surveys [Petrel].txt 7/18/2018 Electronic File: 1H-115 NAD83 EOW Compass Surveys [Surveys].txt 7/18/2018 Electronic File: 1H-115 NAD83 EOW Compass Surveys.pdf 0 0 2180530 KUPARUK RIV U WSAK 11-1-115 LOG HEADERS 10245 10592 7/27/2018 Electronic Data Set, Filename: CPAI_1 H- 115_SCMT_14Ju118_ConCu_R02_L006Up_Repe at.las 2850 10583 7/27/2018 Electronic Data Set, Filename: CPAI_1H- 115_SCMT_14JU118_ConCu_RO2_LO08Up_Main. las Page 2 of 7 Monday, November 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 11/26/2018 Permit to Drill 2180530 Well Name/No. KUPARUK RIV U WSAK 1H-115 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23605-00-00 MD 10706 TVD 4239 Completion Date 7/19/2018 ED C 29547 Digital Data 7/27/2018 ED C 29547 Digital Data ED C 29547 Digital Data Log C 29547 Log Header Scans Log C 29548 Log Header Scans ED C 29548 Digital Data ED C 29548 Digital Data ED C 29548 Digital Data ED C 29549 Digital Data ED C 29549 Digital Data ED C 29549 Digital Data Log C 29549 Log Header Scans ED C 29731 Digital Data ED C 29731 Digital Data Completion Status WAGIN Current Status WAGIN UIC Yes 7/27/2018 Electronic File: CPAI _1H- 115_SCMT_14Ju118_ConCu_RO2_LOO6Up_Repe at.cis 7/27/2018 Electronic File: CPAI 1H- 115_SCMT_14Jull8_ConCu_RO2_LO08Up_Main. dlis 7/27/2018 Electronic File: CPAI_i H- 115_SCMT_14J ul18_Field Pri nt. Pdf 0 0 2180530 KUPARUK RIV U WSAK 1H-115 LOG HEADERS 0 0 2180530 KUPARUK RIV U WSAK 1H-115 LOG HEADERS 2744 3053 7/27/2018 Electronic Data Set, Filename: CPAI _iH- 115_TCP_15Ju118_ConCu_Ro3_L003Up_UPCT.I as 7/27/2018 Electronic File: CPAI11- —1 115_TCP_15Jull8_ConCu_R03_LO03Up_UPCT. dlis 7/27/2018 Electronic File: CPAI 1H- 115_TCP_15JUl18_Field Print. Pdf 2358 3017 7/27/2018 Electronic Data Set, Filename: CPAI 1H- 115_TCP_18Jull8_ConCu_RO4_Lo15Up_UPCT.I as 7/27/2018 Electronic File: CPAI-1H- PAI1H- 115 — TCP-18Jull8—ConCu—RO4—Lol5Up_UPCT. 115_TCP_18Jull8_ConCu_RO4_Lol5Up_UPCT. dlis 7/27/2018 Electronic File: CPAI 111- 115_TC P_18Ju118_R04_UPCT. Pdf 0 0 2180530 KUPARUK RIV U WSAK 1H-115 LOG HEADERS 9846 10450 10/2/2018 Electronic Data Set, Filename: CPAI_1H- 115_(PROF_ 21SEP18_ConCu_R01_L003_Dn_4 OFPM.las 9844 10457 10/2/2018 Electronic Data Set, Filename: CPAI-1 H- 115 -PROF _ 21SEP18_ConCu_R01_1-004_Up_4 OFPM.las AOGCC Page 3 of 7 Monday, November 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 11/26/2018 Permit to Drill 2150530 Well Name/No. KUPARUK RIV U WSAK 1H-115 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23605-00-00 MD 10706 TVD 4239 Completion Date 7/19/2018 Completion Status WAGIN Current Status WAGIN UIC Yes ED C 29731 Digital Data 9836 10454 10/2/2018 Electronic Data Set, Filename: CPAI-11-1- 115_( PROF_21SEP18_ConCu_R01 L005_Dn_8 OFPM.las ED C 29731 Digital Data 9836 10452 10/2/2018 Electronic Data Set, Filename: CPAI-1 H- 115 PROF _21SEP18_ConCu_R01_LO07_Dn_1 20FPM.[as ED C 29731 Digital Data 9726 10462 10/2/2018 Electronic Data Set, Filename: CPAI _1H- 115_(PROF_ 21SEP18_ConCu_R01_L008_Up_1 0F 2PM.las ED C 29731 Digital Data 9799 10486 10/2/2018 Electronic Data Set, Filename: CPAI 1H- 115_IPROF_21SEP18_ConCu_R01_L009_Up_8 OFPM.las ED C 29731 Digital Data 43365 43365 10/2/2018 Electronic Data Set, Filename: CPAI 11-1- 115_IPROF_21SEP18_ConCu_RO1_ST001 103 75.1as ED C 29731 Digital Data 43365 43365 10/2/2018 Electronic Data Set, Filename: CPAI _1H- 115_IPROF_21SEP18_ConCu_R01_ST002_102 80.1as ED C 29731 Digital Data 43365 43365 10/2/2018 Electronic Data Set, Filename: CPAI_1H- 115_IPR0F_21SEP18_ConCu_R01 ST003_101 79.1as ED C 29731 Digital Data 43365 43365 10/2/2018 Electronic Data Set, Filename: CPAI _1H- 115_ IPROF_21SEP18_ConCu_RO1_ST004 100 50.1as ED C 29731 Digital Data 43365 43365 10/2/2018 Electronic Data Set, Filename: CPAI_1H- 115_IPROF_21SEP18_ConCu RO1_ST005_990 Was ED C 29731 Digital Data 43365 43365 10/2/2018 Electronic Data Set, Filename: CPAI_11-1- 115_IPROF_21SEP18_ConCu RO1_ST008 101 80.1as ED C 29731 Digital Data 43365 43365 10/2/2018 Electronic Data Set, Filename: CPAI 1H- 115 IPROF_21SEP18_ConCu_R01_ST009 100 79.1as ED C 29731 Digital Data 43365 43365 10/2/2018 Electronic Data Set, Filename: CPAIII 50.1as ED C 29731 Digital Data 43365 43365 10/2/2018 Electronic Data Set, Filename: CPAIH- _1 115 IPROF_21SEP18 ConCu_R01 ST011 990 Was AOGC(' Page 4 of 7 Monday, November 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 11/26/2018 Permit to Drill 2180530 Well Name/No. KUPARUK RIV U WSAK 1H-115 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029.23605-00-00 MD 10706 TVD 4239 Completion Date 7/19/2018 ED C 29731 Digital Data ED C 29731 Digital Data ED C 29731 Digital Data ED C 29731 Digital Data ED C 29731 Digital Data ED C 29731 Digital Data ED C 29731 Digital Data ED C 29731 Digital Data ED C 29731 Digital Data ED C 29731 Digital Data ED C 29731 Digital Data ED C 29731 Digital Data ED C 29731 Digital Data AOGCC Completion Status WAGIN Current Status WAGIN UIC Yes 10/2/2018 Electronic File: CPAI 1H- 115 PROF-21SEP18_ConCu_R01_L003_Dn_4 OFPM.dlls 10/2/2018 Electronic File: CPAI 1H- 115_(PROF_ 21SEP18_ConCu_R01__L004_Up_4 OFPM.dlis 10/2/2018 Electronic File: CPAI 1H- 115_IPROF_ 21SEP18_ConCu_R01_L005 Dn 8 OFPM.dlis 10/2/2018 Electronic File: CPAI 1H - 115_I PROF_ 21SEP18_ConCu_R01_L007 Dn 1 20FPM.dlis 10/2/2018 Electronic File: CPAI _1H- 115 IPROF_21 SEP18_ConCu_R01_L008_Up_1 20FPM.dlis 10/2/2018 Electronic File: CPAI-11-1- 115 -PROF _ 21SEP18_ConCu_R01_L009_Up_8 OFPM.dlis 10/2/2018 Electronic File: CPAI 1H- 115_lPROF_21SEP18_ConCu_R01_ST001_103 75.dlis 10/2/2018 Electronic File: CPAI1H- 115_ IPROF_21SEP18_ConCu_R01_ST002 102 80.dlis 10/2/2018 Electronic File: CPAI 1H- H - 115 115_I PROF_ 21SEP18_ConCu_Ro1 ST003_101 79.dlis 10/2/2018 Electronic File: CPAI 1H- 115_IPROF_21SEP18_ConCu_R01_ST004 100 50.dlis 10/2/2018 Electronic File: CPAI1 H- 115_IPR0F_21SEP1_8_ConCu_R01_ST005 990 O.dlis 10/2/2018 Electronic File: CPAI 1H- 115_IPROF_21SEP18_ConCu_R01_ST008 101 80.dlis 10/2/2018 Electronic File: CPAI? H- 115 PROF _21SEP1_8_ConCu_R01_ST009 100 79.dlis Page 5 of 7 Monday, November 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 11/2612018 Permitto Drill 2180530 Well Name/No. KUPARUK RIV U WSAK 1H-115 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23605-00-00 MO 10706 TVD 4239 Completion Date 7/19/2018 Completion Status WAGIN Current Status WAGIN UIC Yes ED C 29731 Digital Data 10/2/2018 Electronic File: CPAI 1H- 115_[PROF_ 21SEP18_ConCu_R01_ST010_100 50.d1[s ED C 29731 Digital Data 102/2018 Electronic File: CPAI 1H- 115_ IPROF_21SEP18_ConCu_R01_ST011 990 0.dlis ED C 29731 Digital Data 10/2/2018 Electronic File: CPAI 1H- 115_IPROF_21Sep18_Field Print.Pdf Log C 29731 Log Header Scans 0 0 2180530 KUPARUK RIV U WSAK 1H-115 LOG _ HEADERS Well Cores/Samples Information; — — Name INFORMATION RECEIVED Completion Report (S Production Test Information Y /6 Geologic Markers/Tops COMPLIANCE HISTORY Completion Date: 7/19/2018 Release Date: 5/30/2018 Description Comments: AOGCC Sample Interval Set Start Stop Sent Received Number Comments Directional / Inclination Data 10 Mud Logs, Image Files, Digital Data Y /� Core Chips Y /t'lV" Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files /Q Core Photographs Y / Daily Operations Summary Y� Cuttings Samples Y /19 Laboratory Analyses Y / f A Date Comments Page 6 of 7 Monday, November 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 11/2612018 Permit to Drill 2180530 Well Name/No. KUPARUK RIV U WSAK 1H-115 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029.23605-00-00 MD 10706 TVD42tion Date 7/19/2018 Completion Status WAGIN Current Status WAGIN [�UIC Yes Compliance Reviewed By_ 39 : JA ( Date: _ A0G( < Page 7 of 7 Monday, November 26, 2018 Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: a AOGCC ATTN: Natural Resources Technician 11 Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 S Anchorage, AK 99501 21 8053 29 73 1 WELLNAME API It ORDERSERVICE FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA DATELOGGED ar 1H-115 50-029.23605-00 E540.00022 KUPARUK RIVER WL (PROF FINAL FIELD 21 -Sep -18 1 LH -109 50-029-23595-00 E540-00024 KUPARUK RIVER WL [PROF FINAL FIELD 23 -Sep -18 1 2T-31 50-10320226-00 DSOS-00162 KUPARUK RIVER WL LDL FINAL FIELD 27 -Sep -18 1 2T-31 50-103-20226-00 DSOS-00163 KUPARUK RIVER WL Caliper FINAL FIELD 28 -Sep -18 1 3N-09 50-029-21541.00 DSOS-00164 KUPARUK RIVER WL LDL FINAL FIELD 29 -Sep -18 1 3B-02 50.029.21319-00 DSOS-00165 KUPARUK RIVER WL IPROF FINAL FIELD 30 -Sep -18 1 111-14 50-029.21386.00 DSOS-00166 KUPARUK RIVER WL PPROF FINAL FIELD 1 -Oct -18 1 022 064 - Signature Please return via courier or sign/scan and email a copy to Date and CPAI. . Schlumberger -Private 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 - K2kk 114 - j I P1b zf X60530 Regg, James B (DOA) From: NSK West Sak Prod Engr <nl638@conocophiIli ps.com> ' Sent: Thursday, August 30, 2018 8:29 AM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Caldelas, Fede M; Autry, Sydney; Fox, Pete B; Thomson, Stephanie; Braun, Michael (Alaska) Subject: LPP/SSV Return to Service on CPAI Wells 1 H-113/1 H-115 Jim, The low pressure pilot (LPP) on wells 1H-113 (PTD# 217-168) & 1H-115 (PTD#218-053)) was returned to service and removed from the "Facility Defeated Safety Device Log" today on 8/30/2018 after the wells were allowed to return to their normal injection rates to support drilling operations on 11-1-104. The LPP had been defeated on 8/27/2018 after the wells were limited on injection pressure to support reservoir pressure concerns for the rig. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Courtney Gallo / Marina Krysinski West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Cell: (720) 318- 5762 Pager: (907) 659-7000 #497 From: Regg, James B (DOA) <jim.regg@alaska.gov> Sent: Monday, August 27, 2018 3:11 PM To: NSK West Sak Prod Engr <n1638@conocophillips.com> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; CPF1&2 Ops Supt <n2073@conocophillips.com>; Caldelas, Fede M <Fede.M.Caldelas@conocophillips.com>; Autry, Sydney <Sydney.Autry@conocophillips.com>; Fox, Pete B<Pete.B.Fox@conocophiIIips.com>; Thomson, Stephanie <Stephanie.Thomson@Conoco ph illips.com>; Braun, Michael (Alaska) <Mich I.Braun@conocophillips.com> Subject: [EXTERNAL)RE: LPP/SSV Defeated on CPAI Wells 1H -113/1H-1 KRU 11-1-15 permit to drill # should be 218-053 Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e -avail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State o�ska 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, (`"' M 14 -ll S pl--b z160s30 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, August 27, 2018 3:11 PM Zell, OI Z 1(10 To: 'NSK West Sak Prod Engr' 1\ l Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Caldelas, Fede M; Autry, Sydney; Fox, Pete B; Thomson, Stephanie; Braun, Michael (Alaska) Subject: RE: LPP/SSV Defeated on CPAI Wells 1H -113/1H-115 KRU 11-1-15 permit to drill # should be 218-053 Jim Regg Supervisor, Inspections AOGCC 333 W.711 Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or lim.regg@alaska.gov. From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, August 27, 2018 3:00 PM To: Regg, James B (DOA) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; CPF1&2 Ops Supt <n2073@conocophillips.com>; Caldelas, Fede M <Fede.M.Caldelas@conocophillips.com>; Autry, Sydney <Sydney.Autry@conocophillips.com>; Fox, Pete B<Pete.B.Fox@conocophillips.com>; Thomson, Stephanie <Stephanie.Thomson@ conocophillips.com>; Braun, Michael (Alaska) <Michael.Bra un@Conoco phillips.com> Subject: LPP/SSV Defeated on CPAI Wells 1H -113/1H-115 Jim, The low pressure pilot (LPP) on both wells IH -113 (PTD# 217-168) & 1H-115 (PTD#218-035) were defeated today on 8/27/2018 after the wells were BOL at a reduced wellhead pressure in order to manage pressure for drilling in the offset producer 11-1-104. The well 1H -113i is currently injecting at a wellhead pressure of 360 psi and a rate of 220 BWPD & 1H-115 is injecting at 490 psi and a rate of 500 BWPD. The LPP and surface safety valves (SSV) will be tagged and their status recorded in the "Facility Defeated Safety Device Log" The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Thanks, Courtney Gallo NSK West Sak Production Engineer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . 2P.id15-6 V &. Ill AUG 17 2018 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ❑ Gas[] SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAc 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE) WDSPL ❑ No. of Completions: 1 b. Well Class: Development ❑ Exploratory ❑ Service 0 Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 7/19/2016 14. Permit to Drill Number / Sundry: 218-053 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 7/4/2018 15. API Number: 50-029-23605-00-00 4a. Location of Well (Governmental Section): Surface: 289' FSL, 786' FEL, Sec 28, T12N, R10E, UM Top of Productive Interval: 3571' FNL, 3640' FEL, Sec 26, T12N, R10E, UM Total Depth: 3114' FNL, 3179' FEL, Sec 26, T12N, R10E, UM 8. Date TO Reached: 7110/2018 16. Well Name and Number: KRU 1H-115 / 9. Ref Elevations: KB:92.9f GL: 54.10 BF: 17. Field / Pool(s): Kupsruk River Field/West Sak Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25638, ADL 25639 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 649553 y- 5960992 Zone- 4 TPI: x- 557246 y- 5982467 Zone- 4 Total Depth: x- 557703 y- 5982927 Zone- 4 11. Total Depth MD/TVD: 10706/4239 19, DNR Approval Number: 931695000, 80-261 12. SSSV Depth MDfrVD: N/A 1 20. Thickness of Permafrost MD/TVD: 1664/1637 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) I 21. Re-drill/Lateral Top Window MD/TVD: 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 GR/Res/CBL/CCL 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 78.67 B 39 119 39 119 42 Existing cement to surface 103/4 45.5 L-80 40 1798 40 1760 131/2 994 sx 11.0ppg Class G, 202 sx 12.Oppa Class 7 26 L-80 38 10696 38 4233 83/4 1049 sx 15.6ppg Class G 24. Open to production or injection? Yes 2] No ❑ If Yes, list each interval open (MDfrVD of Top and Bottom; Perforation Size and Number; Date Perfd): PERFORATIONS @: 9957-10046 MD and 3864-3909 ND... 7/15/2018 CO9pl ETION 10105-10171 MD and 3938-3971 TVD... 7/15/2018 nP T'= 10204-10235 MD and 3988-4003 TVD... 7/15/2018 HISS' /// r 10317-10350 MD and 4044-4061 TVD... 7/15/2018 , --'.-_,',., 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDfFVD) 31/2 10515 9908/3840, 10187/3979, 10075/3924 10284/4028 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): INJECTION ONLY - NOT PRE -PRODUCED Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl Choke Size: Gas -Oil Ratio: Flow Tubing P Casino Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravitv - API (torr): Ftnn 10-407 Revised AUG 1 710 NTINU or�� E 2 /z/e ^ I,BU I Submit ORIGINAL onlcl , 16 � 28. CORE DATA Conventional Core(s): Yes ❑ No El Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top . Surface Surface Permafrost - Base 1664 1637 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 9957 3865 information, including reports, per 20 AAC 25.071. Formation @ TPI -West Sak Ugnu 6422 3092 TD 10706 4239 Formation at total de the West Bak 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolooiral rresults. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L. Alvord Contact Name: Nick Lehman Authorized Title: AlasWrilling Manager Contact Email: Nick.R.Lehman co .com Authorized/ ( , Contact Phone: 263-4951 Signature: Date: (J INST UC ONS 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 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 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 forth 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 4r �c Wellhead / Tubing Hanger / Tree 13-3/8" x 4-%" HYD563, 5M Insulated Conductor: 20" Casing 3-1/211, 9.2 If, L-80, Hyd 563 Feed Through Packer #4: 9908' MD Multi Drop Gauge Mandrel — 2.812" Cando DS Nipple Upper MMC s Lower MMG Feed Through Packer #3: 10,075' MD Mulu Drop Gauge Mandrel — Upper MMG Lower MMG Crossover below TH : 4-12" x 3-1/2" Tubing 10-3/4" 45.5#, L-80 HYD563 9 1,798 ft MD Feed Through Packer #2: 10,187' MD Mufti Drop Gauge Mandrel Upper MMG Lower MMG Feed Through Packer #1: 10,284"MD Single Drop Gauge Mandrel 2.813" Camco X Nipple -- Upper MMG _ Lower MMG Baker WIV RA/PIP Tags @ 2,940' & 9,751' MD 1 H-115 Injector Final Drilled & Completed Schematic Formation Tops Base of Permafrost: 1,664' MD / 1,637' TVD Ugnu Top: 6,422' MD / 3,092' TVD N Sands: 9,288' MD / 3,593' TVD West Bak D: 9,957' MD / 3,865' TVD West Bak B: 10,104' MD / 3,939' TVD West Bak A: 10,173' MD / 3,973' TVD "D" Sand Perforations: 9957' - 10046' MD "B" Sand Perforations: 10105'- 10171' MD A4 Sand Perforations: 10204'- 10235' MD A3 Sand Perforations: 10317'-10350' MD 7" 26#, L-80, HYD563/TXP @ 10,696' MD 4234' TVD KUP INJ Caio4hillips hn" Well Attribut Fell Notre AtaslUsTru: WESTSAK AST WO: 1H-115 111415. Whisc Na3650PM Last Tag Vemzl xne.neeed Annotation the Gate Geprola(s) Las[MaG By LAST TAG: jennalt 14WGER: 39.E Last Rev Reason • ...............................'•.... ................ Annoltlbn Moor Iaat MOGBy Rev Reason Pull SOV 81nsudled DV, Set WFRV's 7131/2018 zembaej Cuing Strings Desctlpuoo oG(io) IDlinl Tope11Ka1 Set choon elud set Depth (TVD)... wNsn ll... aeatle TOPTnreM ............................................................ ............(ver, CONDUCTOR 20 1920 39.0 1190 1190 ]8.6] B C.InB Dese,iPlion OG(in) IDlinl Top Incl set UQM 111KB1 set ones Ivor VellLen(I...GrI Top TM1iead SURFACE 10 Y4 9.95 405 1,]9]9 1)60.1 4550 71$0 Hydril 563 Cesln00escnPtlon (trip ID end TopinitBl BN worfroKko sN Oens RVP1"'MI#Len(1-GrMe TOP Tnreatl IOU PRODUCTION ] 628 3]6 114,233.5 26.00 71$0 TXPBTC Tubing Strings Tnom9 De:cnpoon Slnn9 Me_- 1011m Top ltlKB1 Sed Oepin ct sH Oep1n IND I- wt111J1a Grace Top ten 77 TUBING 3112 2.99 32.9 10,514.8 4,143.3 9.30 L-80 .'d563 Completion Details CONDUCTOR: 3SD11e0 IDP I'D) Topincl nominal Top MKel InKel PI Item pass Com IDlinl 32.9 32.9 013 HANGER Vewo MB2284-1/2'Tubing hanger w/parent bowl OD= IJM 3.900 suRFucE;as+.nTe� ,501.9 2,290.0 55591NJ 35"X15"M w C -1 -SOV RK Iamn, psi 2915 2]3AG06)I AS" #14) 9,9080 3,840.0 60.21 PACKER HES Feed Through Packer #4 SN: 2920 (Asst'#13) Iw,xmis 9,921) 3,8468 ED 07 GAUGE HE#, rm - gauge, annulus pressure. R 29]2 4513461411.22) %wu 3.8556 60110 NIPPLE amm D mppe r m(Any 2.812 #12) 9,946.6 3,859.3 60.00 INJ 35"X15" MMGW Mandrel wl DV 8rd-m ISN 069AG12) 2.915 9,9870 3,8794 59.99 INJ 35"X15" MMGW Mandrel W1 Do 8rd-m N: ssy 2915 #11) PACRER:B,BLBO -------------------- 10,0]54 3,923] 60.00 PACKER HES Feed Through Packer#3 2920 (Any #10) 10,0891 3,930.5 60.01 GAUGE HE #2 EUE Bid -m, gauge, annulus Pressure, 2972 (SN451346141120) NIPPLE; 8.89.3 10,1068 3.938.4 60.01 INJ 3 5 1 5' MMGVV Manerel w/ Do Bud -m( N: M Any 2.915 Iru: e,een 10,144.6 3.9582 fi0.031NJ 3.5"X15" M WMan wl V -m N: M Any 2.915 #8) IN.I;eers0 10186 3,91 8004 PACKER HES feedtrough Packer# N: Assy 2.920 PERF.%ad010.0M0 #]) 10,2004 3,986,1 60.05 GAUGE HE691,LUh SI - , annulus Pressure N: 2972 4513461411.25) 10,2169 3,994.6 0,05 INJ 3.5"X1.5'MMGWMan@eIw/ m-m(SN 759Mssy 2.915 PACKER: 10,0754 #6) Cv1VaE: 10.(61 1, 40142 60 04 15'X 1.5"MMGW Mantlrel vv/ Do 8d-m(SN:(May 2.915 til 10,2840 4,0229 6003 PACKER HES feet) through Packer 91 (SN0004048023-04 ssy 2920 #4) Mt 1D, 1.. 1 , ]J 4,034) 60.02 GAUGE HEB X 1, EUE Brd-m, ROC -150, annulus pressure ( _ 2972 4513481411019) IPERF', 10.10501 10,314.3 4,043.0 60.02 NIPPLE Camco 2813 XdINdkh EUE8rd-m(SN:3902634) (Any#3) 2.813 INJ', m.144.6 10322.2 7.0 60.02 1 INJ 3.5- X 15" MMGW Mandrel w/ DV 8th -m (SN: 75 MZ01) 2.915 10361.9 4,088.8 60. INJ" .5 MMGW Mandrel w/ DV WI N_ 749MZ 1 ) Any 2.915 #2) PACKER: none 10,506.5 4,139.1 59.93 CIRC BUB 3IQ" Baker WIV EUE-MOD 0001 GAUGE: 10.. 10,509.0 4,140.4 59.94 SHOE 31Q" Muleshoe tubing tail 2990 Perforations & Slots IPERF; l0,A4,610.950 INI; 10,3168�� an. Oen MP(TVD)Bt (apo) ta.M Top Bm(MB) 1KS) (taken LmF,M2one TyPe 9.9570 10,046.0 3.885 . 3.§90 WSD111-115 7/152018 601PERF 6 ELMILLENNIUM INp 1p,zsss GUNS60 DEG PHASE PACKER; 1n.m4o 10,1050 10,1710 3,938.5 ,9]14 WS B. 1H-115 711512018 6.0 IPERF MILLENNIUM GUNS Be DEG PHASE .n; nSU'7 10,204.0 10,235.0 3987.9 4, 0.6 WS A6,1H-115 7115/2018 6.0 IPERF 7.12Y PF MILLENNIUM GUNS 60 DEG PHASE NIPPLE: 10,3143 10,317.0 10,350.0 4,044.4 4-.DAT.T WS A31H-115 7752018 60 IPERF 7.12977PF MILLENNIUM GUNS fi0 DEG PHASE IW'.1Q3ss Mandrel Inserts IPERF, 10.41] 010,E 0 8I aH INI:10,Y18 an N Top I5KBI Top (TVD) Make Mo4el 00 (in) VBIM LifthType Po(in) TRO l Sery Type (in) Well Run Deet Com 1 ,501.9 211 2,290.9 Camco MMG 1 l2 IMY INJ DMY RK 0000 ]2]2018 2 9,946.6 3,8593 Camco MM - 112 INJ DMV RK 0.000 ]/18201 W 3 9,98].0 3.6]9.4 Camco i 1Q INJ WFRV RK 713012718 Iff W BWP D 4 10.1048 3,938.4 Co.. MMG- 112 INJ GUY RK DOW 7/182018 W 5 10.144.6 3,958.2 Camco G- 1112 INJ WFRV RK 7MOQ018 5 W BWP D 10,216e 39946 hCard. MM - 112 INJ DMY RK 0000 W ] 10,256.6 4,014.2 Cash. MMG- 112 INJ WFRV RK )292018 W BAP PROOVLTION, 3T 010.65.6 D Cmoa;killips KUP INJ 1H-115 Alaska. Im 1M11S.MG3SS3 W%W Vei9 eednemvh (.4 ................................................................ ............... NVIGER; 329 .................................................................. ................... Mandrel Inserts .......................................................... ............ t st °tJ" T-0 (W TOP ITVOI (M E) Me. Model OO(In) Sew WM Type IeOCM1 Type Por1Stre TRO Run 9n) (W Run Bab COM 103222 4,0470 Camco MM - 11R INJ MAY RK 0.000 ➢1812018 W 9 10,361.9 4,066.8 Calnm MMG- 112 INJWFRV RK 2/302018 1000 W BWP D Notes: General & Safety End Dzh i Annoteuon CONDUCT .39&1190 moTE. 3URFACE,K S1.M9� NJ; Z. PACKER; 99-A.0 13AWE; 9,921) N1P ;9.0392 IHJ: B.BW.6 I.AW]0 IPERFe.W O-IsM60- PACKER; IOWE4 WVGE: 10.0W1 IW.10.1N.6 PERF. 101 W 1110.1]10 NJ: 101446 PACKER,10183.] G GE;10=4 IPERF; 10}MLLOMO 1X1;102168 INJ; 10Sti6 PPCKER: IO.M 1 GPUGE: IO,A]] HIPPIE: 10,3163 INJ; 10.913] IPERF; 10.31>6103 0� NJ: 10.19 PROW WON, 37 &10.M 6� Operations Summary (with Timelog Depths) 1 H-115 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Depth SM Time EndTime our (hn Phase Op Code Activity Code Time P -T -X Operation (M(B) Ertl Depth MKS) 7/3/2018 7/3/2018 0.75 MIRU MOVE MOB P Move pipe shed & rockwasher. 0.0 0.0 00:00 00:45 7/3/2018 7/3/2018 0.50 MIRU MOVE MOB P Move / stage motor, pump & pit 0.0 0.0 00:45 01:15 modules. 7/3/2018 7/3/2018 0.75 MIRU MOVE MOB P Skid rig floor, install tongue onto sub 0.0 0.0 01:15 02:00 base & raise stompers. 7/3/2018 7/3/2018 0.75 MIRU MOVE MOB P Jack up sub base & move off of 1 H- 0.0 0.0 02:00 02:45 1 108. 7/3/2018 7/3/2018 0.75 MIRU MOVE MOB P Shuffle dg mats from 1 H-108 to 1 H- 0.0 0.0 02:45 03:30 115. Move sub base 320'& spot on 1 H -115. 7/3/2018 7/3/2018 0.75 MIRU MOVE MOB P Set stompers, remove tongue from 0.0 0.0 03:30 0415 sub base, & skid rig floor over well center. 7/3/2018 7/3/2018 1.75 MIRU MOVE MOB P Spot pits, pump, & motor modules. 0.0 0.0 04:15 06:00 7/3/2018 7/3/2018 1.00 MIRU MOVE MOB P Shim motor module, spot rock washer 0.0 0.0 06:00 07:00 1 1& pipe shed. 7/3/2018 7/3/2018 3.50 MIRU MOVE RURD P Spot cuttings tank. Hook up electrical 0.0 0.0 07:00 10:30 & fluid interconnects. Berth up around cellar. Lower skate rail, spool up skate winch, & function test skate. Swap to high -line power at 10:00 hrs. Complete rig acceptance check list 10:30 hrs. 7/3/2018 7/3/2018 2.00 MIRU MOVE NUND P Obtain RKB's to pad level 38.86'& to 0.0 0.0 10:30 1230 landing ring 40.51'. Pad elevation 54.10'. Nipple up riser & mouse hole. Secure annular & hook up hydraulics to accumulator system. SIMOPS clean cement from flow line; load BHA in the shed; take on mud to the pits; load & strap 4-1/2" DP in shed. 7/3/2018 7/3/2018 0.50 MIRU MOVE PULD P Make up stand of DP & RIH tagging fill 0.0 0.0 12:30 13:00 at 98.65'& mouse hole at 91.45'. Rack back DP. SIMOPS function test diverter system. 7/3/2018 7/3/2018 0.50 MIRU MOVE BOPE P Perform diverter test; annular closing 0.0 0.0 13:00 13:30 time 17 sec; knife valve opened 6 sec. Initial system pressure 2950 psi, pressure after closure 1950 psi, 200 psi recharge time 6 seconds, full recharge time 47 sec. Nitrogen bottles total 6 at an average of 2166 psi. Tested gas system, flow show, & pit level alarms. Wdness waived by AOGCC Rep Guy Cook. 7/3/2018 7/3/2018 1.50 MIRU MOVE BHAH P Mobilize BHA to the rig floor & pipe 0.0 0.0 13:30 15:00 shed. SIMOPS load, strap, & tally HWDP. 7/3/2018 7/3/2018 0.75 MIRU MOVE SFTY P Pre -spud meeting with CPAI Rep, DDI 0.0 0.0 15:00 15:45 crew, SLB & MI reps. 7/3/2018 7/3/2018 2.00 MIRU MOVE BHAH P Make up 13-1/2" surface BHA 1 to 94' 0.0 94.0 15:45 17:45 MD, as per SLB DD. 7/3/2018 7/3/2018 0.75 MIRU MOVE SEQP P Flood mud lines & fill conductor with 94.0 94.0 17:45 18:30 spud mud. Pressure test mud lines to 3500 psi, good. Hold pre -spud with on coming crew & perform table top diverter drill. 7/3/2018 7/3/2018 0.75 MIRU MOVE DRLGP Clean out conductor f/ 94'-119' MD, 94.0 119.0 18:30 19:15 500 gpm, 920 psi, FO 30%, 60 rpm, Tq on 4K. Page 1/15 ReportPrinted: 811 412 01 8 Operations Summary (with Timelog Depths) IH -115 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operation Stan Depth (RKB) End Depth(ftKB) 7/3/2018 7/4/2018 4.75 SURFAC DRILL DDRL P Directional drill 13-1/2" surface hole f/ 119.0 418.0 19:15 00:00 119'-418' MD, 418' TVD, 500 gpm, 920 psi on, 700 psi off, FO 30%, 60 rpm, Tq on 4K, off 1K, WOB 24K, PU 76K, SO 80K, ROT 77K, MW 9.0 ppg, Max Gas 0, AST .22, ART 2.36, ADT 2.58, BIT 2.58, Jars 14.93. Total Footage 299' 7/4/2018 7/4/2018 6.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface hole f/ 418.0 846.0 00:00 0600 418'-846' MD, 846' TVD, 500 gpm, 1130 psi on, 820 psi off, FO 30%, 60 rpm, Tq on 5K, off 1K, WOB 28K, PU 86K, SO 88K, ROT 87K, Max Gas 0, AST .96, ART 1.97, ADT 2.93, BIT 5.51, Jars 17.86. Total Footage 428' MD. 7/4/2018 7/4/2018 6.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface hole f/ 846.0 1,367.0 06:00 12:00 846'-1367' MD, 1356' TVD, 550 gpm, 1340 psi on, 1080 psi off, FO 30%, 60 rpm, Tq on 5K, off 2K, WOB 30K, PU 97K, SO 96K, ROT 95K, Max Gas 7428, AST 1.64, ART 1.87, ADT 3.51, BIT 9.02, Jars 21.37. Total Footage 521' MD. 7/4/2018 7/4/2018 4.75 SURFAC DRILL DDRL P Directional drill 13-1/2" surface hole f/ 1,367.0 1,803.0 12:00 16:45 1367'-1803' MD, 1764' TVD, 550 gpm, 1430 psi on, 1230 psi Off, FO 30%, 60 rpm, Tq on 5K, off 1.5K, WOB 22-30K, PU 104K, SO 102K, ROT 99K, Max Gas 800, AST 1.57, ART 1.23, ADT 2.8, BIT 11 .82, Jars 24.17. Total Footage 436' MD. 7/4/2018 7/4/2018 0.75 SURFAC CASING BKRM P BROOH f/ 1803'-1750' MD, while CBU 1,803.0 1,750.0 16:45 1730 @ 650 gpm, 1540 psi, FO 33%, 60 rpm, Tq 2K, laying down single NIS. Obtain final surveys. 7/4/2018 7/4/2018 2.75 SURFAC CASING BKRM P BROOH f/ 1750'-1040' MD, while CBU 1,750.0 1,040.0 17:30 2015 @ 550 gpm, 1030 psi, FO 30%, 60 rpm, Tq 2K, 400 fph. 7/4/2018 7/4/2018 1.00 SURFAC CASING BKRM P BROOH f/ 1040'-847' MD, while CBU 1,040.0 847.0 20:15 21:15 @ 550 gpm, 1030 psi, FO 30%, 60 rpm, Tq 2K, 200 fph. Pumped BU 2 times. PU 85K, SO 89K 7/4/2018 7/4/2018 0.25 SURFAC CASING OWFF P Monitor well, static. Blow down TD. 847.0 847.0 21:15 21:30 7/4/2018 7/5/2018 2.50 SURFAC CASING BHAH P Rack back 1 stand of HWDP & lay 847.0 76.0 21:30 00:00 1 1 1 down BHA i f/ 847'-76' MD. 7/5/2018 7/5/2018 1.50 SURFAC CASING BHAH P Finish laying down BHA 1 as per SLB 76.0 0.0 00:00 01:30 DD. Bit grade 2,2,WT,A,E,1,NO,TD. Clear & clean rig floor. 7/5/2018 7/5/2018 1.00 SURFAC CASING RURD P Rig up casing handling equipment. 0.0 0.0 01:30 02:30 7/5/2018 7/5/2018 1.00 SURFAC CASING PUTB P Make up 10-3/4", 45.5#, L-80, Hydril 0.0 167.0 02:30 03:30 563, DL, casing shoe track as per detail. Bakerl-ok all joints to the pin end of joint 4. Install stop rings & centralizers as per detail. Check floats, good. 7/5/2018 7/5/2018 5.25 SURFAC CASING PUTB P Run 10-3/4", 45.5#, L-80, Hydril 563, 167.0 1,743.0 03:30 0845 DL, casing as per detail f/ 167'-1743' MD. Install centralizers on each coupling & torque connections to 19.4K It/lbs. Fill every 5 joints. PU 117K, SO 105K. Page 2115 ReportPrinted: 811412018 Operations Summary (with Timelog Depths) 1 H-115 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dur(hd Phase Op Code Activity Code Time P -T -X Opembon Start Depth (ftKB) End Depth(ftKB) 7/5/2018 7/5/2018 4.75 SURFAC CASING PUTB T Work through tight hole or fill f/ 1743'- 1,743.0 1,683.0 08:45 13:30 1754' MD, stage up pump 3-9 bpm, 70 -125 psi, FO 23%, PU 122K, SO 105K. Reciprocate & wash down picking up 2 joints that were not in string to clean up to 1803' MD. A total of 1200 bbls circulated while working to TD. Lay down joints NIS to 1683' 7/5/2018 7/5/2018 0.75 SURFAC CASING HOSO P Continue to run 10-3/4", 45.5#, L-80, 1,683.0 1,797.0 13:30 1415 Hydril 563, OL, casing as per detail f/ 1683'-1797' MD. Rana total of 44 centralizers & 3 stop rings. Make up hanger with landing joint. Land on hanger. PU 122K, SO 105K. 7/5/2018 7/5/2018 1.00 SURFAC CEMENT CIRC P Make up cement lines & stage pump 1,797.0 1,797.0 14:15 1515 up to 9 bpm, 330 psi, FO 25%, PU 117K, SO 103K. SIMOPS PJSM w/ cementers, rig crew, trucking, & CPAI Rep. 7/5/2018 7/5/2018 3.50 SURFAC CEMENT CMNT P Line up on SLB cement unit & pump 5 1,797.0 0.0 15:15 18:45 blots of CW 100, 4 bpm, 97 psi. Pressure test lines to 3500 psi, good. Pump 35 bbls of CW 100, 4 bpm, 100 psi. Pump 78.2 bbls, 10.5 ppg MP ll, 3 -4 bpm, 100 psi. Drop bottom plug. Pump 338.2 bbls of 11.0 ppg DeepCRETE lead cement, 5.5 bpm, 160-225 psi. Pump 59.5 bbls of 12 ppg LiteCRETE tail cement, 4.8 bpm, 215 psi. Drop top plug. Pump 10 bbls of water, 6 bpm, 175 psi. Swap to rig & pump 95.76 bbls, 9.4 ppg, LSND, 8 bpm, 360 psi. Reduce rate to 6 bpm, 290 psi & continue for a total of 143.8 bbls pumped. Reduce rate to 2 bpm, 197 psi & continue for a total of 159.34 bbls (casing volume plus half of shoe track) pumped without bumping the plug. Total of 49.3 bbls of 11.0 ppg cement returns to surface. Full returns during cement job, no losses. Hold 200 psi 10 minutes & check floats, good. CIP @ 18:40 ms. Casing reciprocated till 128 bbls of displacement with last PU 113K, SO 87K. 7/5/2018 7/5/2018 0.50 SURFAC CEMENT OWFF P Monitor well, static. Fluid level on 0.0 0.0 18:45 19:15 backside dropped 1.7". 7/5/2018 7/5/2018 1.50 SURFAC CEMENT RURD P Rig down casing equipment. Lay down 0.0 0.0 19:15 20:45 landing joint. Flush surface stack & lines with black water. Clear & clean rig floor. 7/5/2018 7/6/2018 3.25 SURFAC CEMENT NUND P Nipple down surface diverter system. 0.0 0.0 20:45 00:00 Nipple down riser, annular, diverter tee, & starting head. Pull diverter line from cellar. Top of cement 2.92' down from landing ring. 7/6/2018 7/6/2018 2.75 SURFAC WHDBOP NUND P Clean hanger & cellar. Nipple up MB- 0.0 0.0 00:00 0245 222A wellhead as per GE Rep. Install caps on conductor outlets. Make up OA casing valve & install 1502 flanges. 7/6/2018 7/6/2018 0.25 SURFAC WHDBOP PRTS P CPAI Rep verify orientation & witness 0.0 0.0 02:45 0300 wellhead / hanger seals test to 2000 psi for 10 minutes. Page 3115 Report Printed: 8/14/2018 Operations Summary (with Timelog Depths) IH -115 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stars Time End Time our (hr) Phase Op Code Adimty Code Time P -T -X Operabon (ftKB) End Depth(ttKB) 7/6/2018 7/6/2018 2.50 SURFAC WHDBOP NUND P Nipple up spacer spool & BOP stack. 0.0 0.0 03:00 0530 Make up choke & kill lines. Install pitcher nipple & riser. 7/6/2018 7/6/2018 0.50 SURFAC WHDBOP RURD P Rig up to test BOPS Install 7" test 0.0 0.0 05:30 0600 joint w/ plug. Make up dart & FOSV. Flood lines & shell test BOPE. 7/6/2018 7/6/2018 0.50 SURFAC CEMENT SVRG P Service & inspect top drive & blocks. 0.0 0.0 06:00 0630 7/6/2018 7/6/2018 1.00 SURFAC CEMENT BHAH P Mobilize BHA 2 to the rig floor. 0.0 0.0 06:30 07:30 SIMOPS perform derrick inspection. 7/6/2018 7/6/2018 5.50 SURFAC WHDBOP BOPE P Tested BOPE w/7", 4.5" and 3.5". 0.0 0.0 07:30 13:00 Witness of test by AOGCC inspector Matt Herrera. Tests performed at 250/3500 psi, charted for 5 minutes each with 3.5", 4.5", & 7" test joints. Tested choke valves 1-14; upper and lower IBOP valves; Kill valves on floor, mez, HCR kill, man kill; HCR & man choke valves; XT43 FOSV and dart; Man/Hyd choke test to 2,500 psi & functioned; lower VBR's tested with w3.5" and 4.5" test jt; upper rams w/ 7" tj; blind rams test. Koomey drawn down test - ISP 3075 psi, after closure 1750 psi, attained 200 psi in 7 sec, full pressure in 55 seconds. 6 btl average of 2383 psi. Test pit level alarms & F/O meter H2S & combustible gas alarms tested. Pits H2S sensor FP, recalibrated & tested good. 7/6/2018 7/6/2018 0.50 SURFAC WHDBOP RURD P Remove test plug & install wear 0.0 0.0 13:00 13:30 bushing OD 13.23", ID 12.25", Length 49.5", 7/6/2018 7/6/2018 2.00 SURFAC CEMENT SLPC P Cut & slip 58' of drill line. 0.0 0.0 13:30 15:30 7/6/2018 7/6/2018 3.00 SURFAC CEMENT SHAH P Make up 8-3/4" production BHA2 as 0.0 366.0 15:30 1830 per SLB DD to 366' MD, PU 57K, SO 59K. 7/6/2018 7/6/2018 1.50 SURFAC CEMENT TRIP P TIH with BHA2 on 4-1/2" DP from 366.0 1,615.0 18:30 20:00 1 1366'-1615' MD, PU 83K, SO 79K. 7/6/2018 7/6/2018 1.00 SURFAC CEMENT PRTS P Rig up test equipment & flood lines to 1,615.0 1,615.0 20:00 21:00 test 10-3/4" surface casing. Pressure up casing to 3150 psi w/ 3.4 bbls. Shut in & record pressure for 30 minutes, charted. Initial shut in pressure 3150 psi, final shut in pressure 3010 psi. Bled back 2.9 bbls. Rig/blow down test equipment. 7/6/2018 7/6/2018 2.75 SURFAC CEMENT COCF P Wash & ream down 1615'-1710' MD, 1,615.0 1,803.0 21:00 2345 tagging up on plugs. Clean out shoe track & drill out to TO 1710'-1803' MD, 500 gpm, 900 psi, 50 rpm, Tq on 3K, off 1K. 7/6/2018 7/7/2018 0.25 SURFAC CEMENT DDRL P Directional drill 8-3/4" production hole 1,803.0 1,823.0 23:45 00:00 f/ 1803'-1823' MD, 1782' TVD, 500 gpm, 925 psi on, 900 psi off, FO 27%, 50 rpm, Tq on 3K, off 1 K, WOB 7-15K, PU 83K, SO 79K, ROT 80K, Max Gas 0. 7/7/2018 7/7/2018 0.75 SURFAC CEMENT CIRC P Circulate & condition mud for FIT f/ 1,823.0 1,796.0 00:00 00:45 1823'-1796' MD, 500 gpm, 911 psi, 50 rpm, Tq 2K, 2760 strokes. Page 4115 Report Printed: 8/14/2018 Operations Summary (with Timelog Depths) IH -115 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time Dur (hr) Phase Op Code AChety code FIT Time P -T -X P Operation Rig up & FIT to an EMW of (ftKB) 1,796.0 End Dept (ftKB) 1,796.0 7/7/2018 7/7/2018 1.00 SURFAC CEMENT perform 00:45 01:45 12.0 ppg at 1758.7' TVD, MW 9.6 ppg. Pressure up with .3 bbl to 220 psi. Shut in & record pressure for 10 minutes with a final pressure of 91 psi. Bled back .1 bbl. Rig down test equipment. 7/712018 7/7/2018 4.25 PRODi DRILL DDRL P Directional drill 8-3/4" production hole 1,796.0 2,217.0 01:45 06:00 550 f/ 1823'-2217' MD, 21550 gpm, 700 psi on, 690 psi off, FO 29%, 100 rpm, Tq on 3-6K, off 2K, WOB 6K, ECD 10.1, PU 90K, SO 85K, ROT 86K, Max Gas 4700, ADT 2.5, BIT 2.5, JARS 2.75, Total Footage 377' MD. SCR @ 1895' MD, 1815' TVD, MW 9 ppg, 03:00 hrs #1) 30 = 100 psi @ 40 = 120 psi #2) 30 = 100 psi @ 40 = 120 psi 7/7/2018 7/7/2018 1.50 PROD1 DRILL SRW T Experience unanticipated drill string 2,217.0 2,217,0 0600 07:30 interference. Perform roll tests & correct survey data to verify down hole location. 7/7/2018 7/7/2018 4.50 PROD1 DRILL DDRL P Directional drill 8-314" production hole 2,217.0 2,870.0 0730 12:00 f/ 2217'-2870' MD, 2421' TVD, 600 gpm, 880 psi on, 885 psi off, FO 28%, 100 rpm, Tq on 3K, off 2K, WOB 3K, ECD 10.2, PU 95K, SO 86 K, ROT 89K, Max Gas 480, ADT 3.06, BIT 5.56, JARS 5.81, Total Footage 653' MD. SCR @ 2277' MD, 2124' TVD, MW 9.0+ ppg, 08:05 hrs #1)30=100 psi @40=130 psi #2) 30 = 100 psi @ 40 = 130 psi 7/7/2018 7/7/2018 6.00 PRODi DRILL DDRL P Directional drill 8-3/4" production hole 2,870.0 3,717.0 1200 18:00 f/ 2870'-3717' MD, 2605' TVD, 650 gpm, 1125 psi on, 1122 psi off, FO 30%, 140 rpm, Tq on 5.5K, off 4.5K, WOB 13K, ECD 10.3, PU 101K, SO 78K, ROT 89K, Max Gas 225, ADT 3.37, BIT 8.93, JARS 9.18, Total Footage 847' MD. 7/7/2018 7/8/2018 6.00 PROD1 DRILL DDRL P Directional drill 8-3/4" production hole 3,717.0 4,763.0 18:00 00:00 f/ 3717'-4763' MD, 2782' TVD, 650 gpm, 1300 psi on, 1278 psi off, FO 30%, 140 rpm, Tq on 7K, off 4.5K, WOB 13K, ECD 10.73, PU 109K, SO 78K, ROT 91 K, Max Gas 30, ADT 3.92, BIT 12.85, JARS 13.91, Total Footage 1046' MD. Kick w/ drilling table top SCR @ 4002 MD, 2652' TVD, MW 9.0+ ppg, 19:45 hrs #1) 30 = 160 psi @ 40 = 200 psi #2) 30 = 160 psi @ 40 = 200 psi 7/8/2018 7/8/2018 6.00 PROD1 DRILL DDRL P Directional drill 8-3/4" production hole 4,763.0 5,431.0 00:00 06:00 f/ 4763'-5431' MD, 2886' TVD, 650 gpm,1370 psi on, 1278 psi off, FO 30% , 140-110 rpm, Tq on 11 K, off 9K, WOB 11K, ECD 10.58, PU 117K, SO 68K, ROT 92K, Max Gas 222, ADT 3.9, BIT 16.75, JARS 17 0, Total Footage 668' MD. Page 5/15 Report Printed: 811 412 01 8 Operations Summary (with Timelog Depths) 1H-115 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth siert Time End Time our thr) Phase Op code Activity Cade Time P4A Operetlon (flKa) End Depth rtKe) 7/8/2018 7/8/2018 6.00 PROD1 DRILL DDRL P Directional drill 8-3/4" production hole 5,431.0 6,284.0 06:00 12:00 f/ 5431'-6284' MD, 3035' TVD, 650 gpm, 1600 psi on, 1600 psi off, FO 32%,150 rpm, Tq on 9K, off 7.51K, WOB 12K, ECD 11.24, PU 126K, SO 65K, ROT 94K, Max Gas 320, ADT 3.82, BIT 20.57, JARS 20.82, Total Footage 853' MD. SCR @ 5522 MD, 2909' TVD, MW 9.0+ ppg, 06:45 hrs #1) 30 = 220 psi @ 40 = 260 psi #2) 30 = 220 psi @ 40 = 260 psi 7/8/2018 7/812018 6.00 PROD1 DRILL DDRL P Directional drill 8-3/4" production hole 6,284.0 7,048.0 12:00 18:00 f/ 6284'-7048' MD, 3160' TVD, 700 gpm, 1990 psi on, 1965 psi off, FO 33%,130 rpm, Tq on 9K, off 9.51K, WOB 16K, ECD 11.23, PU 133K, SO 62K, ROT 95K, Max Gas 320, ADT 3.79, BIT 24.36, JARS 24.61, Total Footage 764' MD. 7/8/2018 719/2018 6.00 PROD1 DRILL DDRL P Directional drill 8-3/4" production hole 7,048.0 7,901.0 18:00 00:00 f/ 7048'-7901' MD, 3338' TVD, 700 gpm, 2130 psi on, 2120 psi off, FO 33%,130 rpm, Tq on 9K, off 8K, WOB 13K, ECD 11.2, PU 135K, SO 62K, ROT 98K, Max Gas 220, ADT 4.12, BIT 28.48, JARS 28.73, Total Footage 853' MD. 7/9/2018 7/9/2018 6.00 PROD1 DRILL DDRL P Directional drill 8-3/4" production hole 7,901.0 8,190.0 0000 06:00 f/ 7901'-8190' MD, 3354' TVD, 700 gpm, 2010 psi on, 2000 psi off, FO 33%, 110 rpm, Tq on 9K, off 7K, WOB 7K, ECD 10.9, PU 138K, SO 63K, ROT 98K, Max Gas 200, ADT 2.83, BIT 31.31, JARS 31.56, Total Footage 289' MD. 7/9/2018 7/912018 6.00 PROD1 DRILL DDRL P Directional drill 8-3/4" production hole 8,190.0 8,671.0 06:00 12:00 f/ 8190'-8671' MD, 3432' TVD, 700 gpm, 2275 psi on, 2260 psi off, FO 30%,120 rpm, Tq on 11.5K, off 9.5K, WOB 16K, ECD 11.2, PU 144K, SO 60K, ROT 101 K, Max Gas 244, ADT 3.71, BIT 35.02, JARS 35.27, Total Footage 481' MD. SCR @ 8281' MD, 3369' TVD, MW 9.1+ ppg, 06:55 hrs #1) 30 = 260 psi @ 40 = 320 psi #2) 30 = 270 psi @ 40 = 320 psi 7/9/2018 7/9/2018 1.25 PROD1 DRILL DDRL P Directional drill 8-3/4" production hole 8,671.0 8,760.0 12:00 13:15 f/ 8671'-8760' MD, 3450' TVD, 700 gpm, 2215 psi on, 2208 psi off, FO 30%, 110 rpm, Tq on IOK, off 8.51K, WOB 5K, ECD 10.99, PU 140K, SO 60K, ROT 101 K, Max Gas 244. Total Footage 89' MD. 7/9/2018 7/912018 0.75 PROD1 DRILL CIRC P Circulate & condition 700 gpm, 2190 8,760.0 8,760.0 13:15 14:00 psi, FO 31%, 80 rpm, Tq 9K. 7/9/2018 7/9/2018 0.50 PROD1 DRILL SVRG P Service top drive. SIMOPS trouble 8,760.0 8,760.0 14:00 14:30 1 shoot soft speed on TD. 7/9/2018 7/9/2018 1.00 PROW DRILL RGRP T Trouble shoot soft start on TD. Reboot 8,760.0 8,760.0 14:30 15:30 system & change out an encoder on top drive with no improvement. Page 6/15 ReportPrinted: 8114/2018 Operations Summary (with Timelog Depths) 1 H-115 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth start Time End Time Dur (hr) Phase Op Cone Activity Core Time P -T -x Operation (fixe) End Depth (itKe) 7/9/2018 7/9/2018 2.50 PROD1 DRILL DDRL P Directional drill 8-3/4" production hole 8,760.0 8,904.0 15:30 18:00 1/8760'-8904' MD, 3471' TVD, 700 gpm, 2150 psi on, 2086 psi off, FO 30%, 100 rpm, Tq on 12K, off 9.51K, WOB 16K, ECD 11.02, PU 144K, SO 60K, ROT 101 K, Max Gas 228, ADT 1.86, BIT 36.88, JARS 37.13, Total Footage 144' MD. 7/9/2018 7/10/2018 6.00 PROD1 DRILL DDRL P Directional drill 8-3/4" production hole 8,904.0 9,380.0 18:00 00:00 f/ 8904'-9380' MD, 3603' TVD, 700 gpm, 2350 psi on, 2086 psi off, FO 30%,120 rpm, Tq on 12K, off 9.5K, WOB 16K, ECD 11.31, PU 140K, SO 65K, ROT 104K, Max Gas 208, ADT 3.64, BIT 40.52, JARS 40.77, Total Footage 476' MD. SCR @ 9041' MD, 3494' TVD, MW 9.1+ ppg, 20:30 hrs #1) 30 = 300 psi @ 40 = 340 psi #2) 30 = 300 psi @ 40 = 360 psi 7/10/2018 7/10/2018 6.00 PROD1 DRILL DDRL P Directional drill 8-3/4" production hole 9,380.0 9,770.0 00:00 06:00 f/ 9380'-9770' MD, 3729' TVD, 700 gpm, 2342 psi on, 2320 psi off, FO 30%, 110 rpm, Tq on 12K, off 9.5K, WOB 14K, ECD 11.25, PU 143K, SO 67K, ROT 105K, Max Gas 220, ADT 3.48, BIT 44.0, JARS 44.25, Total Footage 390' MD. 7/10/2018 7/10/2018 6.00 PRODt DRILL DDRL P Directional drill 8-3/4" production hole 9,770.0 10,193.0 0600 12:00 f/ 9770'-10193' MD, 3949' TVD, 650 gpm, 2230 psi on, 2222 psi off, FO 29%, 120 rpm, Tq on 11.5K, off 10.6K, WOB 7K, ECD 11.07, PU 163K, SO 75K, ROT 115K, Max Gas 227, ADT 3.36, BIT 47.36, JARS 47.61, Total Footage 423' MD. SCR @ 9898' MD, 3797' TVD, MW 9.1+ ppg, 07:45 him #1) 30 = 300 psi @ 40 = 350 psi #2) 30 = 300 psi @ 40 = 360 psi 7/10/2018 7/10/2018 6.75 PROD1 DRILL DDRL P Directional drill 8-3/4" production hole 10,193.0 10,706.0 12:00 18:45 f/ 10193'-10706' MD, 4242' TVD, 700 gpm, 2460 psi on, 2430 psi off, FO 30%,120 rpm, Tq on 13.5K, off 12.4K, WOB 16K, ECD 11.19, PU 175K, SO 75K, ROT 117K, Max Gas 100, ADT 3.89, BIT 51.25, JARS 51.5, Total Footage 513' MD. Spill Drill Table Top Review 7/10/2018 7/10/2018 1.25 PROD1 CASING CIRC P CBU @ 700 gpm, 2500 psi, FO 30%, 10,706.0 10,706.0 1845 2000 115 rpm, Tq 11 K, PU 175K, SO 75K, ROT 117K. Obtain final survey & SCR's. SCR @ 10706' MD, 4205' TVD, MW 9.2+ ppg, 18:55 first #1) 30 = 320 psi @ 40 = 400 psi #2) 30 = 320 psi @ 40 = 400 psi 7/10/2018 7/10/2018 0.50 PROD1 CASING PULD P Lay down 2 joints of DP 10706'-10660' 10,706.0 10,660.0 20:00 2030 1 MD, PU 182K, SO 82K. 7/10/2018 7/10/2018 1.00 PROD1 CASING RGRP T Change out saver sub on top drive. 10,660.0 10,660.0 20:30 21:30 Monitor well, lost 1.5 bbl circulating across the lop of the hole. Page 7/15 ReportPrinted: 8/1412018 ' Operations Summary (with Timelog Depths) 1 H-115 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten �ptn SW Tans EM Time our (hr) Phase Op Code Amdty Code Time PJA OµvaTO (rlKa) El Depth (N(B) 7/10/2018 7/10/2018 2.00 PROD1 CASING BKRM P BROOH f/ 10660'-10473' MD, 700 10,660.0 10,473.0 21:30 23:30 gpm, 2450 psi, 110 rpm, Tq 10-11K, 500600 fph. Back ream each stand up & back down; then pull out of hole racking back the stand. 7/10/2018 7/11/2018 0.50 PROD1 CASING RGRP T Open backup wrench, inspect threads 10,473.0 10,473.0 23:30 00:00 on saver subs & button back up. 7/1112018 7/11/2018 6.00 PRODt CASING BKRM P BROOH f/ 10473'-9700' MD, 650 gpm, 10,473.0 9,700.0 00:00 06:00 2300 psi, 120 rpm, Tq 10K, 500-600 fph. Back ream each stand up & back down; then pull out of hole racking back the stand. 7/11/2018 7/11/2018 6.00 PROD1 CASING BKRM P BROOH f/ 9700'-8760' MD, 657 gpm, 9,700.0 8,760.0 06:00 12:00 2160 psi, FO 29%,120 rpm, Tq 10K, 500-600 fph, PU 155K, SO 59K. Back ream each stand up & back down; then pull out of hole racking back the stand. 7/1112018 7/11/2016 3.00 PROD1 CASING BKRM P BROOH f/ 8760'-8235' MD, 657 gpm, 8,760.0 8,235.0 12:00 15:00 2110 psi, FO 29%,120 rpm, Tq 9.5K, 500600 fph, PU 145K, SO 62K. Back ream each stand up & back down; then pull out of hole racking back the stand. 7/1112018 7/11/2018 0.25 PROD1 CASING SVRG P Reset parameters on the drive 8,235.0 8,235.0 15:00 15:15 controller for the top drive to resolve torque issues with soft speed. Fire Drill CRT 2:15 minutes. 7/11/2018 7/11/2018 2.75 PROD1 CASING BKRM P BROOH f/ 8235'-7238' MD, 657 gpm, 8,235.0 7,238.0 15:15 18:00 1860 psi, FO 28%,120 rpm, Tq 9K, 500600 fph, PU 133K, SO 60K. 7/11/2018 7/12/2018 6.00 PROD1 CASING BKRM P BROOH f/ 7238'-5100' MD, 700 gpm, 7,238.0 5,100.0 18:00 00:00 1550 psi, FO 28%,140 rpm, Tq 9K, 500-700 fph. 7/12/2018 7/12/2018 6.00 PRODt CASING BKRM P BROOH f/ 5100'-3042' MD, 700 gpm, 5,100.0 3,042.0 00:00 06:00 1310 psi, FO 28%,140 rpm, Tq 6K, 500-700 fph. Reduce parameters while pulling through the coal sections. 7/12/2018 7/12/2018 3.75 PROD1 CASING BKRM P BROOH f/ 3042'-1790' MD, 500-700 3,042.0 1,790.0 06:00 09:45 gpm, 1220 psi, FO 28%, 90-120 rpm, Tq 2-41K, 500-700 fph. PU 89K, SO 87K. Reduce parameters while pulling through the coal sections. 7/1212018 7/12/2018 1.00 PROD1 CASING CIRC P CBU till clean & pump dry job f/ 1790; 1,790.0 1,612.0 09:45 10:45 1612' MD, 750 gpm, 1275 psi, FO 29%, 65 rpm, Tq 1 K, 7/12/2018 7/12/2018 0.25 PROW CASING OWFF P Monitor well, static. SIMOPS blow 1,612.0 1,612.0 10:45 11:00 downTD. 7/12/2018 7/12/2018 1.00 PROD1 CASING TRIP P TOH f/ 1612'-366' MD, PU 63K, SO 1,612.0 366.0 11:00 12:00 67K. 7/1212018 7/12/2018 3.00 PROD1 CASING BHAH P Lay down BHA 2 as per SLB DD. 366.0 0.0 12:00 15:00 Bit Grade 2, 4, BT, A, X, I, CT, TO 7/12/2018 7/12/2018 0.75 PROD1 CASING BHAH P Clear & clean rig floor. 0.0 0.0 15:00 15:45 7/12/2018 7/12/2018 0.50 COMPZN CASING W W WH P Make up stack washing tool & flush 0.0 0.0 15:45 16:15 slack. Lay down stack washer. 7/12/2018 7/1212018 0.50 COMPZN CASING RURD P Make up running tool & pull wear 0.0 0.0 16:15 16:45 bushing. Lay down running tool. 7/12/2018 7/1212018 1.25 COMPZN CASING RURD P Change out XT43 saver sub on top 0.0 0.0 16:45 18:00 drive. SIMOPS mobilize GBR rasing running equipment. Page 8/15 Report Printed: 811412018 Operations Summary (with Timelog Depths) 1H-115 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log alert Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) EM Depth (BKS) 7/12/2018 7/12/2018 1.00 COMPZN CASING RURD P Rig up GBR casing handling 0.0 0.0 18:00 19:00 equipment & CRT. PJSM for running 7" production casing with all involved personnel. 7/12/2018 7/12/2018 1.00 COMPZN CASING PUTB P Pick up & make up 7", 26#, L-80 shoe 0.0 195.0 19:00 20:00 track as per casing tally detail to 195' MD. Bakerl-ok connections & torque Hyd 563 to 9,400 ft/lbs; TXP to 17,700 ftllbs. Centralized with 2 centralizer per joint. Check floats, good. 7/12/2018 7/12/2018 2.75 COMPZN CASING PUTB P Continue running 7", 26#, L-80, TXP- 1950. 1.797.0 20:00 22:45 M casing f/ 195'-1797' MD, torque connections to 17,700 ft/lbs, with 8.5" centralizers preinstalled w/ a 3 centralizer configuration per 2 joints. 7/12/2018 7/12/2018 0.75 COMPZN CASING CIRC P Circulate & condition mud at the shoe 1,797.0 1,797.0 22:45 23:30 staging pump up to 6 bpm, 91 psi, PU 87K, SO 88K. 7/12/2018 7/13/2018 0.50 COMPZN CASING PUTS P Continue running 7", 26#, L-80, TXP- 1,797.0 2,152.0 23:30 00:00 M casing f/ 1797'-2152' MD, torque connections to 17,700 ft/lbs, filling pipe on the fly & topping off every 10 joints, with 8.5" centralizers preinstalled w/ a 3 centralizer configuration per 2 joints. 7/13/2018 7/13/2018 5.25 COMPZN CASING PUTB P Continue running 7' 26411 ppf L-80 TAP 2,152.0 4,820.0 00:00 05:15 -M Casing F/ 2,152' MD-T/4,820' MD. Torque connections T/ 17.71K ft.lbs. Filling on the fly, Topping off every 10 joints. 7/13/2018 7/13/2018 0.75 COMPZN CASING CIRC P Circulate bottoms up staging pumps 4,820.0 4,820.0 05:15 06:00 up to 4 BPM 240 psi. 1,320 strokes pumped. Up wt. 139K Dn wt. 85K. Reciprocate pipe F/4,820' MD - 4,780 MD 7/13/2018 7113/2018 1.50 COMPZN CASING PUTB P Continue running 7' 26# ppf L-80 TXP 4,820.0 5,598.0 06:00 07:30 -M Casing F/ 4,820' MD - T/5,598' MD. Torque connections T/ 17.7K ft.lbs. Filling on the fly, Topping off every 10 joints. Monitoring via trip tank 7/13/2018 7/13/2018 1.75 COMPZN CASING CIRC P Circulate hole clean after 500' below 5,598.0 5,598.0 07:30 09:15 majority of coal areas. Staged pump rate up to 7 bpm - 390 psi. 132K up wt. - 66K do wt. Reciprocated F/5,598' MD - T/ 5,558' MD Pumped a total of 4,500 strokes. No visible large pieces of coal across shakers. 7/13/2018 7/13/2018 2.75 COMPZN CASING PUTB P Continue running 7' 26# ppf L-80 TXP 5,598.0 7,725.0 09:15 12:00 -M Casing F/ 5,598' MD - T/7,275' MD. Torque connections T/ 17.7K ft.lbs. Filling on the fly, Topping off every 10 joints. Monitoring via trip tank. Losses for tour 35 bbls. 7/13/2018 7/13/2018 1.50 COMPZN CASING PUTB P Continue running 7' 26# ppf L-80 TXP 7,725.0 8,037.0 12:00 13:30 -M Casing F/ 7,725' MD - T/8,037' MD. Torque connections T/ 17.71K ft.lbs. Filling on the fly, Topping off every 10 joints. Monitoring via trip tank. Page 9/15 Report Printed: 8/14/2018 Operations Summary (with Timelog Depths) a 1 H-115 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time Our (hr) Phase Op Code Ad Ay Code Time P -T -X Operation (aKB) End Depth (MS) 7/13/2018 7/13/2018 1.00 COMPZN CASING CIRC P Circulate bottoms up staging pumps 8,037.0 8,037.0 13:30 14:30 up to 8 bpm - 640 psi. Total strokes pumped 2870. PU 145K, SO 65K, reciprocated pipe 8037'-8000' MD. 7/13/2018 7/13/2018 2.50 COMPZN CASING PUTB P Continue running 7' 26#, L-80 TXP-M 8,037.0 9,195.0 14:30 17:00 Casing F/ 8037'-9195' MD. Torque connections T/ 17.7K ft.lbs. Filling on the fly, Topping off every 10 joints. Monitoring via trip tank. 7/13/2018 7/13/2018 0.75 COMPZN CASING CIRC T Circulate bottoms up staging pumps 9,195.0 9,195.0 1700 17:45 up to 6 bpm - 670 psi. Total strokes pumped 900. PU 210K, SO 60K. Change out GBR Casing hydraulic hose. 7/13/2018 7/13/2018 3.50 COMPZN CASING PUTS P Continue running 7' 26#, L-80 TXP-M 9,195.0 10,695.6 1745 21:15 Casing F/ 8037'-10695.63' MD.Torque connections T/ 17.7K fl.lbs. Filling on the fly, Topping off every 10 joints. Make up XO joint, hanger & landing joint. Land out casing on hanger at 10695.63' MD. Ran a total of 264 joints of 7' 26#, L- 80 TXP-M Casing, 239 - 8.5" centralizers, 4 - 8.25" centralizers, & 486 stop rings. 7/13/2018 7/14/2018 2.75 COMPZN CEMENT CIRC P Circulate & condition for cementing 10,695.6 10,695.6 21:15 00:00 staging up pumps to 6 bpm, 580 psi, 6885 strokes pumped, PU 205K, SO 165K. 7/14/2018 7/14/2018 2.50 COMPZN CEMENT CIRC P Circulate & condition for cement 10,695.6 10,695.6 00:00 02:30 staging up pump to 7 bpm, 730 psi, 16780 strokes pumped, PU 210K, SO 56K. 7/14/2018 7/14/2018 3.00 COMPZN CEMENT CMNT P Pump 5 bbls of H2O & test lines to 10,695.6 10,695.6 02:30 05:30 3500 psi, good. Load #1 plug. Pump 39.9 bbls of 12.5 ppg MP II at 5 bpm, 450 psi. Load #2 plug. Pump 215 bbls of 15.8 ppg Tail slurry cement at 5.8 bpm, 230 psi. Load top plug. Pump 405 bbl, 9.0 ppg KW brine at 6 bpm, ICP 216 psi, FCP 1319 psi to bump top plug. Pressure up 1820 psi & hold for 5 minutes. Bleed off pressure, shut in & observe no pressure increase. Floats good. CIP 05:30 hrs. Note: Reciprocated pipe 15-20' throughout job up until hole got sticky 100 bbls into displacement and then landed off on hanger. 7/14/2018 7/14/2018 0.75 COMPZN CEMENT PRTS P Test 7" production casing to 3500 psi, 10,695.6 10,695.6 05:30 06:15 30 minutes charted. Pressure up casing to 3600 psi with 5.3 bbls. Shut in & observe pressure for 30 minutes. ISP = 3600: FSP = 3500 psi. Bled back 4.6 bbls. Rig down test equipment. 7/14/2018 7/14/2018 1.25 COMPZN CEMENT RURD P Rig down casing handling equipment, 10,695.6 10,695.6 06:15 07:30 CRT, landing joint, clean out valves used for cementing, clear & clean rig floor. Page 10/15 Report Printed: 8/14/2018 Operations Summary (with Timelog Depths) 1 H-115 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Activity Cade Time P -T -X Opemdon (ftKB) EM Depth (dKB) 7/14/2018 7114/2018 1.25 COMPZN W WSP P Set 7" packofi as per GE Rep & 10,695.6 10,695.6 07:30 08:45 RILDS. Test upper & lower seals to 5000 psi for 10 minutes witnessed by L CPAI Rep. Install 9" wear bushing & lay down running tool. SIMOPS spot e -line unit & pick up tools, blow down TD. 7/14/2018 7/14/2018 1.50 COMPZN RURD P Rig up a -line tools, make up tractor, 0.0 0.0 08:45 10:15 test tools on rig floor. 7/14/2018 7114/2018 1.75 COMPZN EVALWB ELOG P RIH w/ a -line logging tools to 1000' 0.0 0.0 10:15 12:00 MD. Pull out of hole wl tools due to loss of communication. Change out tools. SIMOPS housekeeping, maintenance WO, clean suction & discharge screens on MP 1 & 2. 7/14/2018 7/14/2018 11.25 COMPZN EVALWB ELOG P RIH w/ e -line logging tools for CBL to 0.0 0.0 12:00 23:15 10570' ELM on plugs at top of float collar. Log back out & send logs to town. 711412018 7/15/2018 0.75 COMPZN EVALWB RURD P Lay down logging tools & rig down 0.0 0.0 23:15 00:00 equipment. 7/15/2018 7/15/2018 3.25 COMPZN EVALWB FRZP P Flush & freeze protect 10-3/4"X7" 0.0 0.0 00:00 03:15 annulus. Pump at .5 bpm, observe annulus break over at 432 psi w/ 5.4 bbls pumped. Stage up rate to 3 bpm & an injection pressure of 586 psi. Pump 100 bbls total & shut down with 482 static on the well. Line up on LRS & test lines. Freeze protect OA w/ 90 bbls of diesel at 2 bpm, ICP 800 psi, FCP 1100 psi. Shut in w/ 700 psi static. SIMOPS PJSM & begin picking up TCP gun assembly. 7/15/2018 7115/2018 0.50 COMPZN PERF BHAH P Continue picking up TCP assembly to 0.0 512.0 03:15 03:45 571' MD. 7/15/2018 7/15/2018 8.25 COMPZN PERF TRIP P TIH w/ TCP 512'-9260' MD, PU 145K, 512.0 9,260.0 03:45 12:00 SO 65k, fill on the fly & top off every 5 stands. OA 320 psi 7/15/2018 7/1512018 1.50 COMPZN PERF TRIP P TIH w/ TCP 9260'-10373' MD, PU 3,260.0 10,373.0 12:00 13:30 149K, SO 60k, fill on the fly & top off every 5 stands. Set string in tension.SIMOPS PU a -line tools & rig up circulating hoses. 7/15/2018 7/15/2018 1.00 COMPZN PERF ELOG P Rig up a -line w/ tractor & function test 10,373.0 10,373.0 13:30 14:30 tools, good. 7/15/2018 7/1512018 2.00 COMPZN P RIH w/ a -line to 4700' MD. Lose 10,373.0 10,373.0 14:30 16:30 communication w/ tools. 7/15/2018 7/15/2018 1.00 COMPZN ELOG T Pull out of hole w/ a -line 4700'-0' MD. 10,373.0 10,373.0 16:30 17:30 Lost communication w/ tractor. 7/1512018 7/15/2018 1.00 COMPZN rPERFELOG FLOG T SLB checks are good. Well Tech 10,373.0 10,373.0 17:30 18:30 swapped out tractors, checks out good at surface. 7/15/2018 711512018 2.00 COMPZN FLOG P RIH w/ a -line on tractor & start getting 10,373.0 10,373.0 18:30 20:30 errors -2000' ELM. Able to log across upper RA tag. Confer w/ town & decision made to not log to bottom with tools giving telemetry errors. POOH to surface. Rig down a -line. Page 11115 ReportPrinted: 8114/2018 Operations Summary (with Timelog Depths) a 1H-115 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Depth start Time End Time Ow (hr) Phase Op Code Activity Cade Time P -T -X Operaeon (8KB) End De"(Wls) 7/15/2018 7/15/2018 1.00 COMPZN PERF PULD P Space out to set vented bull plug at 10,373.0 10,351.8 20:30 21:30 10351.79' MD ( top shot at 9957' MD) 22.05' up from logging depth. Lay down 1 single of DP & pick up 2 DP pups totaling 20.11'. Set packer as per HES TCP Rep. 7/15/2018 7/15/2018 0.75 COMPZN PERF PERF P Shut in annular & pressure up to 1000 10,351.8 10,351.8 21:30 22:15 psi on the back side, good. Continue to pressure up 3700 & hold for 30 sec. bleed IA to 675 psi. TCP fired @ 22:03 hrs. Observe 775 on DP gauge. Wait for 5 minutes & pick up to open bypass. 7/15/2018 7/15/2018 1.25 COMPZN PERF CIRC P Reverse circulate staging up pump to 10,351.8 10,351.8 2215 23:30 5 bpm, 665 psi, 150 psi back pressure. At 127 bbis pumped observed hydrocarbons & diverted to open top tank, 5 bpm, 920 psi, 250 back pressure. Pumped total of 125 bbls to open top tank for returns to clean up. Continue reversing to the pits pumping 276 bbls total. Shut down & bleed off all pressure. Shut in & observe no pressure increase. Open annular & observe well static. 7/15/2018 7/16/2018 0.50 COMPZN PERF TRIP T Pick up to release packer to 230K, last 10,351.8 10,351.8 23:30 00:00 j PU 169K, SO 63K. Confer with town. 7/16/2018 7/16/2018 0.50 COMPZN PERF PRTS T Confer with town on plan forward. Pick 10,351.8 10,351.8 00:00 00:30 up to 230K 2 times & observe jars fire. Slack off to 50K, shutting the bypass vent valve. Close annular & pressure up to 300 psi & observe pressure decrease 120 psi in 1 minute. Verify packer elements not seal & possibly hanger is free. Indications are that TCP assembly is stuck in pert sand. 7/16/2018 7/16/2018 2.00 COMPZN PERF JAR T Lay down side port sub, FOSV, & pup 10,351.8 10,336.0 00:30 02:30 joint. Pick up working single of 4-1/2" OR Commence jarring operations, last PU 169K, SO 63K. Pick up to 230K w/ 60K over pull firing jars & set down to 50K to reset. With no progress made, start incrementally increasing over pull weight at 1 OK to jar. Begin to see movement with a PU 260K, 90K over pull. Pull free with 3 hit from jarring. 7/16/2018 7/16/2018 1.00 COMPZN PERF TRIP P TOH racking back DP in the derrick f/ 10,336.0 9,457.0 02:30 03:30 10336'-9457' MD, PU 168K. 7/16/2018 7/16/2018 0.25 COMPZN PERF SVRG P Perform post jarring derrick inspection. 9,457.0 9,457.0 03:30 03:45 7/16/2018 7/16/2018 4.75 COMPZN PERF TRIP P TOH racking back DP in the derrick f/ 9,457.0 517.0 03:45 08:30 9457'-517' MD, PU 55K, SO 53K. 7/16/2018 7/16/2018 1.50 COMPZN PERF BHAH P Lay down TCP assembly f/ 517'- 517.0 0.0 08:30 10:00 surface, as per HES Rep. all shots fired. Clear & clean rig floor. 7/16/2018 7/16/2018 2.00 COMPZN PERF BHAH P Mobilize clean out BHA to dg floor, 0.0 0.0 10:00 12:00 load & strap 9 joints of DP in the shed. Pick up BHA as per BOT Rep to 100' MD, PU 46K, SO 52K. OA= 160 psi @ 12:00 hrs 7/16/2018 7/16/2018 4.50 COMPZN PERF TRIP P TIH f/ 100'-9850' MD, PU 164K, SO 100.0 9,850.0 12:00 16:30 77K. Page 12115 ReportPrinted: 811412018 Operations Summary (with Timelog Depths) 1 H-115 e Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log smn Depth Stan Tim Eno Time Dur (ho Phase op Code Activity Code Time P-T-X Opn MKB) End Depth (ftKB) 7/16/2018 7/16/2018 2.50 COMPZN PERF REAM P 1_ Wash & ream fl 9850'-10400' MD, 8 9,850.0 10,400.0 16:30 19:00 bpm, 1680 psi, 70 rpm, Tq 6-11 K, FO 22%, PU 180K, SO 76K, ROT 101 K, max gas 128. 7/16/2018 7/16/2018 1.00 COMPZN PERF CIRC P Circulate & conditions f/ 10400'-10516' 10,400.0 10,516.0 19:00 20:00 MD, pumping a brine Duo-vis sweep surface to surface 8 bpm, 1700 psi, 70 rpm, Tq 1 OK, FO 21 %. 7/16/2018 7/16/2018 0.50 COMPZN PERF PULD P Lay down 2 joints of DP & pick up 1 10,516.0 10,516.0 20:00 20:30 joint from the shed. 7/16/2018 1711612018 0.25 COMPZN PERF WASH P Wash down at 2 bpm, 180 psi, tag up 10,516.0 10,563.0 20:30 20:45 on plugs above float collar at 10570' MD. Pick back up to 10563' MD. 7/1612018 7/16/2018 1.00 COMPZN PERF CIRC P C&C hole pumping Duo-vis sweep 10,563.0 10,480.0 20:45 21:45 surface to surface at 8 bpm, 1700 psi, 70 rpm, Tq 11K, 4337 strokes pumped to clean up shakers. 7/16/2018 7/16/2018 0.50 COMPZN P Monitor well, static. 10,480.0 10,480.021:45 22:157/1612018 7117/2018 1.75 COMPZN PULD P TOH laying down DP 10480'-9402' 10,480.0 9,402.0 22:15 00:00 MD, PU 185K. rPERFOWFF OA = 230 psi @ 24:00 hrs 7/17/2018 7/17/2018 8.00 COMPZN TRIP P Pull out of hole laying down4-1/2" 9,402.0 58.0 00:00 08:00 Drillpipe. F/9,402'MD - T58'MD. 170k -75k up wt. 7/17/2018 7/17/2018 0.50 COMPZN SHAH P PJSM / Lay Down Baker oil tools BHA. 56.0 0.0 08:00 08:30 Clear anbd dean floor 7/1712018 7117/2018 0.50 COMPZN WELLPR CIRC P Flush BOP stack w/875 gpm, 120 psi, 0.0 0.0 08:30 09:00 32% flow out. Blow down top drive, Pull wear bushing. 7/17/2018 7/17/2018 3.00 COMPZN RPCOMP RCST P PJSM/ Rig up to run 3-1/2" 0.0 0.0 09:00 12:00 completion. R/U GBR Equipment, PIU all HES Tec wire tools/Spool, Hang sheave in derrick, Sim-ops Load shed with completion jewelry in order and verify count. Losses for tour 45 bbls. 7/17/2018 7117/2018 6.00 COMPZN RPCOMP RCST P PJSM/ Run 3-112" 9.2 ppf. Tubing 0.0 334.0 12:00 18:00 Completion per running order T/334' MD. Up wt. 48k, Dn wt. 50k. Monitor displacement via trip tank. Install cannon clamps each connection. 7/17/2018 7/18/2018 6.00 COMPZN RPCOMP RCST P PJSMI Run 3-1/2" 9.2 ppf. tubing 334.0 1,100.0 18:00 00:00 Completion per running order F/334' MD - T/1,100' MD . Up wt. 56k, Dn wt. 55k. Monitor displacement via trip tank. Install cannon clamps each connection. 10 bbl. loss tour 7/18/2018 7/18/2018 6.00 COMPZN RPCOMP RCST P PJSM/ Run 3-1/2" 9.2 ppf. tubing 1,100.0 6,516.0 00:00 06:00 Completion per running order F/1,100' MD - T/6,516' MD . Up wt. 82k, on wt. 59k. Monitor displacement via trip lank. Install cannon clamps each connection. 7/18/2018 7/18/2018 5.00 COMPZN RPCOMP RCST P PJSM/ Run 3-1/2" 9.2 ppf. tubing 6,516.0 10,573.0 06:00 11:00 Completion per running order F/6,516' MD - T/10,573' MD . Up wt. 112k, Dn wt. 58k. Tag Float collar W/31k, Monitor displacement via trip tank. Install cannon clamps each connection. Page 13115 Report Printed: 811412018 Operations Summary (with Timelog Depths) 1 H-115 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Deptn Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation MKa) End Depth (RKS) 7/18/2018 7/18/2018 1.00 COMPZN RPCOMP CRIH P UD Joint # 317, Rig up to pump CI 10,573.0 10,573.0 11:00 12:00 Brine, 3 BPM, 133 gpm, 337 psi, 8% flow out, Sim -Ops pick up wireline equipment to floor. Tour lasses = 8.6 bbls. 7/18/2018 7/18/2018 1.75 COMPZN RPCOMP CRIH P Continue to pump Cl brine at 3 bpm, 10,573.0 10,573.0 12:00 13:45 133 gpm, 337psi, 8% flow out. Total strokes pumped - 3,700 7/18/2618 7/18/2018 0.25 COMPZN RPCOMP PULD P Lay dawn Joints 316, 315' Leave joint 10,573.0 10,499.0 13:45 14:00 314 in slips with 3' stick up at 10,499' MD 7/18/2018 7/18/2018 4.50 COMPZN RPCOMP ELOG P Correlate completion depths w/ RA 10,499.0 10,499.0 14:00 18:30 lag, RIH with wireline at 15:45 hrs. at 16:30 hrs. E -Line hung up at 3,270' MD. Attempt to pump E -line down at 3 bpm. 132 gpm, 335 psi, 7% flow out. E -line still hanging up. At 3,350' MD start logging up. 7/18/2018 7/18/2018 0.50 COMPZN RPCOMP ELOG P Rig down SLB E -Line. 10,499.0 10,499.0 18:30 19:00 7/18/2018 7/18/2018 1.50 COMPZN RPCOMP RCST P Lay down 3 joints Hyd 563 # 10,499.0 10,484.0 19:00 20:30 314,313,312. Make up space out pups - 9.78', 9.77'& 7.82'. Make up 3-1/2" - T/ 4-1/2" Hyd 563 X -O, Pick up one joint 4-1/2' Hyd 563 (39.99'). Make up hanger with pup (5.21) Orient production port on hanger with 10:00 box clock. 7/18/2018 7/18/2018 1.00 COMPZN RPCOMP RCST P Land Tubing hanger and run in lock 10,514.8 10,514.8 20:30 21:30 down screws 114k up wt. - 60k do wt. 326 Full cannon clamps and 7 1/2 damps used to secure tech wire. Test hanger seals to 5,000 psi - 15 minutes. 7/18/2018 7/19/2018 2.50 COMPZN RPCOMP PRTS P Drop ball and pump on seat 3 bpm. 10,514.8 10,514.8 21:30 00:00 380 psi. reduced rate at 70 bbls. pumped to 2 bpm. 180 psi. Ball on seat with 81 bbls. pumped. Pressure up to 4,000 psi. WIV Valve closed at 1,200 psi. HES packers start setting at 1,840 psi fully set at 3,500 psi. Maintained 4,000 psi for tubing test 30 min. charted test. Bled down tubing to 2,500 psi pressured up IA to 3,500 psi held for 30 min. test also charted. Losses for tour 2 bbls. 7/19/2018 7/19/2018 0.50 COMPZN RPCOMP PRTS P Completed IA pressure lest to 3500 0.0 00:00 00:30 psi, bleed off tubing pressure and shear SOV. Pump 5 bbls though open SOV @ 2 bpm= 150 psi. 7/19/2018 7/19/2018 1.00 COMPZN WHDBOP SEOP P Pull landing joint and install type H 00:30 01:30 BPV. Pressure test BPV to 2500 psi for 10 min form below, good test. R/D testing lines and equipment. 7/19/2018 7/19/2018 1.50 COMPZN WHDBOP NUND P Remove flow riser, mouse hole and 01:30 03:00 flow boot. Remove choke and kill lines, nipple down BOPE and spacer spool. 7/19/2018 7/19/2018 2.00 COMPZN WHDBOP NUND P Install test dart in hanger, nipple up 03:00 05:00 tree and test void to 5000 psi, good. Test SLB tee wire as per SLB. 7/19/2018 7/19/2018 0.75 COMPZN WHDBOP PRTS P R/U and pressure test tree to 250 psi 05:00 05:45 low and 5000 psi high for 15 min, good. Page 14115 Report Printed: 811412018 Operations Summary (with Timelog Depths) 1H-115 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time Dur (hr) Phase Op Code A&,ty Code Time P-T-K Operation (flKB) End Depth (fiKB) 7/19/2018 7/19/2018 0.25 COMPZN WHDBOP SEQP P Pull BPV as per Vetco rep. 0545 06:00 7/19/2018 7/19/2018 1.00 COMPZN WHDBOP KURD P Rig up to freeze protect well. SIMOPS� 0600 07:00 pull skate rail and secure rig floor. 7/19/2018 7/19/2018 1.00 COMPZN WHDBOP FRZP P Hold PJSM, Freeze protect well. 07.00 08:00 Pump 100 bbls of diesel down IA taking returns up tubing to kill tank @ 2 bpm= 500 psi. R/D LRS and circulating lines. 7/19/2018 7/19/2018 0.25 COMPZN WHDBOP SEQP P Confirm no pressure under hanger 0800 08:15 and set 4" H BPV w/ dry rod. 7/19/2018 7/19/2018 1.75 DEMOB MOVE RURD P Secure cellar. IA= 0 psi, Tubing = 0 08.15 10:00 psi, OA= 130 psi. Released rig from 1H-115 @ 10;00 hours Page 15115 Report Printed: 8/14/2018 NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H-116 1 H-115 ConocoPhillips Definitive Survey Report 13 July, 2018 Final Definitive Survey Verified and Signed -off AM targets and/or weft posklon objectives have been achieved. J yez ❑ No I have checked to the best of my ab#gy that the fopowing data is correct: J Surface Coordinates Declination & Convergence GRS Surrey Corrections _. Survey Tool Codes Brandon Tem�e DigNallysgnedhyBrandonTemple SL8DE: P [Ate: 20180776UJ:18:36-08UT Nick Lehman Dgidlym,nWb,Nickteh.an Client Representative: N� 2318m.1609mS2 0900 Date: 711818 ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well IH -115 Project: Kuparuk River Unit TVD Reference: IH -115 Actual @ 92.96usft (Doyon 142) she: Kupamk 1H Pad MD Reference: 1H-115 Actual @ 92.96usft(Doyon 142) Won: 1H-115 North Reference: True WaNbore: 1H-115 Survey Calculation Method: Minimum Curvature Design: 1H-115 Database: OAKEDMP2 roject Kuparuk River Unit, North Slope Alaska, United States tap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level leo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zane: Alaska Zone 04 Using geodetic scale factor Vail 1H-115 Vell Position +NIS 0.00 usft Northing: 5,980,991.68 usft Latitude: 70° 21'31.8681 +E/ -W 0.00 usft Easting: 549,553.43 usft Longitude: 149° 35'51.062 V billion Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 54.10 usf gellbore IH -115 fagnetics Model Name Sample Date Declination Dip Angle Field Strength 17) (% (nT) BGGM2018 8/1/2018 17.06 80.91 57,450 Design 11-1-115 Audit Notes: Map Map Version: 1.0 Phase: ACTUAL Ire On Depth: 38.86 Vertical Section: Depth From (TVD) +NIS +E14N Direction DLS (usft) (use) Nam P) (usft) 38.86 0.00 0.00 73.00 Survey Program Date 7/13/2018 From To (usft) (waft) Survey (Wellbore) Toot Name 119.52 1,266.60 1H-115 Srvy 1 - SLB _GWD70 (iH-115) GYDGC-SS 1,327.79 1,712.57 IH -115 Srvy 2- SLB _MWD+GMAG It H- MWD+IFR-AK-CAZ-SC 1,811.50 1,811.501H-115 Srvy 3-SLB_MW0.incOny-Fille MWD -INC _ONLY 1,877.99 10,641.81 IH-115Srvy4-SLB_MWD+GMAG(1H- MWD+IFR-AK-CAZ-SC Survey Description Survey Date Gyrociata gyro single shots 7/3/2018 9:37:0 MWD+IFR AK CAZ SCC 7/4/2018 9:38:0 MWD -INC -ONLY -FILLER 7/6/2018 10:131 MWD+IFR AK CAZ SCC 7/6/201810:15:( 7/13/2018 8:11:01AM Page 2 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +WS +E/ -W Northing Seating DLS Section (laid" 11 (') (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (e) Survey Tool Name 38.86 0.00 0.00 38.86 54.10 0.00 0.00 5,980,991.68 549,553.43 0.00 0.00 UNDEFINED 119.52 0.47 284.99 119.52 26.56 0.09 -0.32 5,980,99176 549,553.11 0.58 -0.28 GYDGC-SS(1) 146.37 0.24 101.76 146.37 53.41 0.10 -0.37 5,980,991.78 549,553.06 2.64 4).32 GYDGG-SS(1) 241.21 0.33 300.84 241.21 148.25 0.20 -0.41 5,980,991.88 549,553.02 0.59 -0.33 GYDGC-SS(1) 336.66 0.07 84.86 336.66 243.70 0.35 -0.59 5,980,992.02 549,552.84 0.41 4).46 GYD-GC-SS(1) 427.93 0.70 99.73 427.93 334.97 0.26 0.02 5,980,991.94 549,553.44 0.69 0.09 GYDGC-SS(1) 518.19 1.06 94.95 518.17 425.21 0.09 1.39 5,980,991.78 549,554.82 0.41 1.36 GYD-GC-SS(1) 610.87 2.22 92.84 610.82 517.86 -0.07 404 5,980,991.64 549,557.47 1.25 3.84 GYDGC-SS(1) 699.06 3.39 99.23 698.90 605.94 -0.57 8.32 5,980,991.16 549,561.75 1.37 7.79 GYDGC-SS(1) 790.20 4.36 106.41 789.83 696.87 -1.98 14.30 5,980,989.79 549,567.74 1.19 13.10 GYDGC-SS(1) 886.11 7.21 110.47 885.24 792.28 5.12 23.44 5,980,986.72 649,576.90 3.00 20.92 GYDGG-SS(1) 7/13/2018 8:11:01AM Page 2 COMPASS 5000.14 Build 85 Survey ConocoPhillips Definitive Survey Report Map Company: NADConversion Local Coordinate Reference: Well 1H-115 Project-. Kuparuk River Unit TVD Reference: 1 H-115 Actual (d1 92.96usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1 H-115 Actual @ 92.96usft (Doyon 142) Well: 111-115 North Reference: True Wellbore: 111-115 Survey Calculation Method: Minimum Curvature Design: 111-115 Database: OAKEDMP2 Survey 7113/2018 8:11:01AM Page 3 COMPASS 5000.14 Build 85 Map Map vertical MD Inc Ali TVD 7VDSS +NW3 +EI -W Northing Easting DLS Section (waft) (1) (') (MR) Nam WIN) (MR) (ft) (ft) (°1100.) (ft) Survey Tool Name 981.24 8.60 101.41 979.47 886.51 5.61 36.01 5,980,983.31 549,589.49 1.96 31.91 GYD-GC-SS(1) 1,076.44 10.25 100.79 1,073.38 980.42 -11.61 51.30 5,980,980.41 549,604.80 1.74 45.67 GYD-GC-SS(1) 1,171.34 11.86 102.49 1,166.52 1,073.56 -15.30 69.12 5,98,976.84 549,622.64 1.73 6163 GYD-GC-SS(1) 1,266.50 14.11 102.95 1,259.33 1,166.37 -20.02 90.00 5,980,972.26 549,643.55 2.35 80.21 GYD-GC-SS(1) 1,327.79 15.66 103.35 1,318.47 1,225.51 -23.60 105.30 5,980,968.78 549,65887 2.54 93.80 MWD+IFR-AK-CAZSC(2) 1,422.13 17.64 101.28 1,408.85 1,315.89 -29.33 131.71 5,980,963.22 549,685.32 2.19 117.38 MM+IFR-AK-CAZSC (2) 1,517.35 19.12 101.14 1,499.21 1,406.25 -35.17 161.16 5,980,957.58 549,714.81 1.55 143.84 MWD+IFR-AK-CAZSC(2) 1,612.70 20.15 99.87 1,589.02 1,496.06 41.00 192.65 5,980,951.96 549,746.34 1.17 172.26 MWD+1FR-AK-CAZSC(2) 1712.57 22.63 99.31 1,682.00 1,589.04 47.06 228.58 5,980,94614 54,782.29 2.49 204.83 MWD+IFR-AK-CAZSC(2) 1,811.50 25.39 100.48 1,772.36 1,679.40 -54.00 268.22 5,980,939.46 549,821.98 2.83 240.72 MWD-INC_ONLY (3) 1,877.99 27.05 101.18 1,832.01 1,739.05 59.52 297.07 5,980,934.13 549,850.86 2.54 266.69 MWD+1FR-AK-CAZSC(4) 1,927.09 29.27 101.00 1,875.29 1,782.33 53.98 319.81 5,950,929.83 549,873.63 4.52 287.13 MWD+IFR-AK-GAZSC(4) 2,022.76 33.66 100.28 1,956.88 1,863.92 -73.18 368.88 5,950,920.95 549,922.75 4.61 331.37 MWD+IFR-AK-CAZSC(4) 2,118.64 38.60 102.09 2,034.29 1,941.33 54.19 424.31 5,980,910.31 549,978.25 5.27 381.15 MWD+IFR-AK-CAZSC(4) 2,212.61 44.08 104.37 2,104.82 2,011.86 58.45 484.68 5,98,896.45 550,038.71 6.05 434.72 MWD+IFR-AK-CAZSC(4) 2,308.61 48.01 103.28 2,171.45 2,078.49 -114.94 551.78 5,98,880.40 550,105.91 4.17 494.07 MWD+IFR-AK-CAZSC(4) 2,402.81 51.67 101.89 2,232.19 2,139.23 -130.60 622.03 5,980,865.21 550,176.25 4.05 556.67 MWD+IFR-AK-CAZSC(4) 2,465.92 54.21 101.72 2,270.22 2,177.26 -140.90 671.33 5,980,855.24 550,225.61 4.03 600.80 MWD+IFR-AK-CAZSC(4) 2,510.55 55.92 101.66 2,295.78 2,202.82 -148.31 707.15 5,980,848.07 550,261.48 3.83 632.89 MWD+IFR-AK-CAZSC(4) 2,606.17 60.65 102.62 2,346.03 2,253.07 -165.43 786.65 5,980,831.47 550,341.08 5.02 703.91 MWD+IFR-AK-CAZSC(4) 2,700.82 64.78 100.27 2,389.41 2,296.45 -182.09 869.08 5,980,815.36 550,423.61 4.89 777.86 MWD+IFR-AK-CAZSC(4) 2,796.25 68.40 94.81 2,427.35 2,334.39 -193.51 955.84 5,980,804.51 550,510.44 6.48 857.50 MW0+IFR-AK-CAZSC(4) 2,890.94 70.43 91.61 2,460.64 2,367,68 -198,46 1,044.33 5,980,800.15 550,598.95 3.62 940.67 MWD+IFR-AK-CAZSC(4) 2,986.80 71.91 89.49 2,491.59 2,398.63 -199.32 1,135.05 5,98,799.89 550,689.66 2.60 1,027.17 MWD+IFR-AK-CAZSC(4) 3,081.71 73.94 85.70 2,519.46 2,426.50 -195.50 1,225.67 5,980,804.31 550,780.25 4.38 1,114.95 MWD+IFR-AK-CAZSC(4) 3,176.17 76.68 83.06 2,543.50 2,450.54 -186.54 1,316.56 5,980,813.87 550,871.07 3.89 1,204.49 MWD+IFR-AK-CAZSC(4) 3,271.11 79.41 80.81 2,563.25 2,470.29 -173.51 1,408.49 5,980,827.51 550,962.90 3.78 1,296.22 MWD+FR-AK-CAZSC(4) 3,366.43 81.21 79.44 2,579.29 2,486.33 -157.39 1,501.05 5,980,844.24 551,055.34 2.36 1,389.45 MWD+IFR-AK-CAZSC(4l 3,462.10 80.27 78.26 2,594.69 2,501.73 -139.14 1,593.69 5,950,863.10 551,147.85 1.56 1,483.37 MWD+IFR-AK-CAZSC (4) 3,55681 80.07 78.60 2,610.85 2,517.89 -120.42 1,685.11 5,980,882.42 551,239.14 0.41 1,576.27 MWD+IFR-AK-CAZSC (4) 3,652.14 80.17 78.97 2.627.21 2,534.25 -102.15 1,777.24 5,980,901.30 551,331.13 0.40 1,66071 MWD+IFR-AK-CAZ-SC(4) 3,747.80 80.25 78.68 2,643.48 2,550.52 53.80 1,869.70 5,980,920.26 551,423.46 0.41 1.763.50 MWD+IFR-AK-CAZ-SC (4) 3,841.95 80.54 79.03 2,659.19 2,566.23 55.78 1,960.76 5,980,938.88 551,514.39 0.56 1,855.85 MWD+IFR-AK-CAZ-SC(4) 3,939.51 79.65 78.15 2,675.97 2,583.01 46.77 2,054.97 5,960,958.51 551,608.46 1.27 1,951.50 MWD+IFR-AK-CAZ-SC(4) 4,032.43 80.14 78.27 2,692.27 2,599.31 -28.08 2,144.52 5,980,977.79 551,697.88 0.54 2,042.60 MWD+IFR-AK-CAZ-SC(4) 4,127.34 80.23 77.75 2,708.45 2,615.49 5.65 2,236.00 5,980,997.82 551,789.22 0.55 2,135.76 MW1)+1FR-AK-CAZ-SC(4) 4,222.61 80.22 77.18 2,724.63 2,631.67 11.73 2,327.64 5,981,018.80 551,880.72 0.59 2,229.37 MWD+1FR-AK-CAZ-SC(4) 4,317.73 80.35 76.84 2,740.68 2,647.72 32.80 2,419.00 5,981,040.48 551,971.93 0.38 2,322.89 MWD+IFR-AK-CAZSC(4) 4,412.40 80.13 76.97 2,756.73 2,663.77 63.94 2,509.87 5,981,05222 552,062.65 0.27 2,415.98 MWD+IFR-AK-CAZSC(4) 4,508.46 80.37 77.11 2,772.99 2,680.03 75.17 2,602.14 5,981,08486 552,154.76 0.29 2,510.41 MWD+IFR-AK-CAZSC(4) 7113/2018 8:11:01AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Cotnparly: NADConversion Local Co-ordinate Reference: Well 1 H-115 Project Kuparuk River Unit TVD Reference: 1 H-115 Actual @ 92.96usft (Doyon 142) She: Kuparuk 1H Pad MD Reference: lH-115 Actual @ 92.96usft (Doyon 142) Wen: 111-115 North Reference: True Wellbore: 1H-115 Survey Calculation Method: Minimum Curvature Design: 1H-115 Database: OAKEDMP2 Survey 7113/2018 8:11:O1AM Page 4 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +W.S +E/.W Northing Easting OLS Section (waft) (1) (1) (usft) (usft) (usft) (usm (ft) (ft) (x/100') (ft) Survey Tool Name 4,603.00 8061 77.11 2,788.61 2,695.65 95.97 2,693.03 5,981,105.46 552,24550 0.25 2,60341 MWD+IFR-AK-CAZSC(4) 4,698.14 80.39 78.20 2,804.32 2,711.36 116.03 2,784.69 5,981,126.12 552,337.02 1.15 2,696.94 MWD+IFR-AK-CA7-SC (4) 4,793.74 80.49 78.61 2,820.19 2,727.23 134.98 2,877.04 5.01,145.68 552,429.23 0.44 2,790.79 MWD+IFR-AK-CAZ-SC(4) 4,889.46 80.16 77.77 2,836.28 2,743.32 154.29 2,969.40 5,981,165.60 552,521.45 0.93 2,884.76 MWD+IFR-AK-CAZSC (4) 4,984.43 79.95 77.31 2.852.68 2,759.72 174.48 3,060.74 5,981,186.38 552,612.65 0.53 2,978.01 MWD+IFR-AK-CAZSC (4) 5,079.30 80.53 77.54 2,868.77 2,775.81 194.83 3,151.99 5,981,207.34 552,703.76 0.66 3,071.23 MWD+IFR-AK-CAZ-SC (4) 5,174.26 80.30 76.73 2,884.58 2,791.62 215.68 3,243.28 5,981,228.79 552,794.89 0.68 3,164.62 MWD+IFRAK-CAZSC(4) 5,267.32 80.55 76.38 2,900.06 2,807.10 237.02 3,332.52 5,981,250.71 552,883.99 0.46 3,256.20 MWD+IFR-AK-CAZSC(4) 5,362.23 80.46 77.03 2,915.71 2,822.75 258.54 3,423.62 5,981,272.84 552,974.94 0.68 3,349.62 MWD+IFR-AK-CAZSC(4) 5,458.68 80.33 76.58 2,931.81 2,838.85 280.25 3,516.21 5,981,295.16 553,067.37 0.48 3,444.51 MWD+IFR-AK-CAZSC(4) 5,551.90 80.67 77.34 2,947.19 2,854.23 300.99 3,605.78 5,981,316.49 553,156.79 0.88 3,536.23 MND+IFR-AK-CAZSC(4) 5,647.95 80.57 77.05 2,962.85 2,869.89 322.00 3,698.19 5,981,338.10 553,249.05 0.32 3,630.74 MWD+IFR-AK-CAZSC (4) 5,740.76 80.55 76.77 2,978.07 2,885.11 34273 3,787.36 5,981,359.43 553,338.08 0.30 3,722.08 MWD+IFR.AK-CAZSC(4) 5,835.17 80.45 76.80 2,993.65 2,900.69 364.02 3,878.01 5,981,381.31 553,428.57 0.11 3,814.99 MWD+IFR-AK-CAZSC(4) 5,929.81 80.57 76.92 3,009.26 2,916.30 385.24 3,90.91 5,981,403.13 563,519.32 0.18 3,908.12 MWD+IFR.AK-CAZSC(4) 6,028.64 80.58 77.34 3,025.42 2,932.46 406.93 4,063.85 5,981,425.45 553,614.12 0.42 4,005.27 MWD+IFR-AK-CAZSC(4) 6,121.91 80.15 77.27 3,041.05 2,948.03 427.16 4,153.67 5,981,446.27 553,703.78 0.47 4,097.05 MWD+IFR.AK-CAZSC(4) 6,219.08 80.40 77.74 3,057.46 2,964.50 447.88 4,247.17 5,981,467.61 553,797.13 0.54 4,192.54 MWD+IFR-AK-CAZSC(4) 6,313.55 80.40 77.02 3,073.22 2,980.26 468.23 4,338.07 5,981,488.56 553,887.88 0.75 4,285.41 MWD+IFRAK-CAZSC (4) 6,409.24 80.57 77.24 3,089.04 2,996.08 489.26 4,430.07 5,981,510.18 553,979.74 0.29 4,379.54 MWD+IFRAK-CAZSC(4) 6,504.33 80.58 78.10 3,104.61 3,011.65 509.29 4,521.71 5,981,530.82 554,071.23 0.89 4,473.04 MWD+IFR-AK-CAZSC(4) 6,599.62 80.27 77.98 3,120.46 3,027.50 528.76 4,613.63 5,981,550.90 554,163.02 0.35 4,566.63 MWD+IFRAK-CAZSC(4) 6,694.25 80.77 78.18 3,136.05 3,043.09 54B.04 4,704.96 5,981,570.78 554,254.20 0.57 4,659.61 MWD+IFR-AK-CAZSC(4) 6,789.47 80.63 77.73 3,151.43 3,058.47 567.65 4,796.86 5,981,590.99 554,345.96 0.49 4,753.22 MND+IFRAK-CAZSC(4) 6,884.49 80.48 ]7.51 3,167.03 3,074.07 587.74 4,888.41 5,981,611.69 554,437.37 0.28 4,846.65 MWD+IFRAK-CAZSC(4) 6,979.46 80.33 77.61 3,182.86 3,089.90 607.91 4,979.85 5,981,632.46 554528.67 0.19 4,939.99 MWD+IFRAK-CAZSC(4) 7,074.78 80.42 78.12 3,198.79 3,105.83 627.67 5,071.73 5,981,652.83 554,620.40 0.54 5,033.63 MWD+IFR-AK-CAZSC(4) 7,170.09 80.91 78.89 3,214.25 3,121.29 646.41 5,163.89 5,981,672.17 554,712.43 0.95 5,127.25 MND+IFRAK-CAZSC(4) 7,264.87 80.06 77.92 3,229.92 3,136.96 665.20 5,255.46 5,981,691.56 554,803.86 1.35 5,220.30 MWD+IFRAK-CAZSC (4) 7,359.99 80.26 77.38 3,246.18 3,163.22 685.24 5,347.01 5,981,712.21 554,895.27 0.60 5,313.72 MWD+IFR-AK-CAZ-SC(4) 7,455.90 80.10 77.41 3,262.54 3,169.SB 705.87 5,439.24 5,981,733.44 554,987.35 0.17 5,407.94 MND+IFRAK-CA7-SC (4) 7,550.76 80.44 77.66 3,278.57 3,185.61 726.05 5,530.53 5.01,754.23 555,078.50 0.44 5,501.15 MWD+FR-AK-CAZ-SC (4) 7,646.07 80.38 77.86 3,294.45 3,201.49 745.97 5,622.37 5,981,774.76 555,170.20 0.22 5,594.80 MWD+IFR-AK-CAZ-SC (4) 7,741.27 80.10 77.46 3,310.58 3,217.62 766.02 5,714.02 5,981,795.41 555,261.71 0.51 5,688.31 MWD+IFRAK-W-SC(4) 7,836.35 80.37 77.53 3,326.71 3,233.75 766.31 5,805.50 5,981,816.30 555,353.04 0.29 5,781.73 MWD+IFR-AK-CAZ-SC(4) 7,931.24 79.74 77.51 3,343.10 3,250.14 806.51 5,896.76 5,981,837.10 555,444.15 0.66 5,874.90 MWD+IFRAKCAZ-SC(4) 8,025.61 80.11 77.36 3,359.61 3,266.65 826.72 5,987.45 5,981,857.91 555,534.70 0.42 5,967.54 MWD+IFRAK-CAZ-SC(4) 8,121.19 80.41 77.79 3,375.78 3,282.82 846.99 6,079.44 5,981,878.79 555,626.55 0.54 6,061.44 MWD+IFRAK-CAZSC(4) 8,216.59 80.39 77.99 3,391.69 3,298.73 866.72 6,171.41 5,981,899.13 555,718.38 0.21 6,155.16 MWD+IFRAK-CAZSC(4) 8,310.96 80.66 78.72 3,407.22 3,314.26 885.51 6,262.58 5,981,918.51 555,809.41 0.81 6,247.83 MND+IFRAK-CAZSC (4) 7113/2018 8:11:O1AM Page 4 COMPASS 5000.14 Build 85 Survey ConocoPhillips Definitive Survey Report Map Company: NADConversion Local Co-ordinate Reference: Well 1 H-115 Projsce Kuparuk River Unit TVD Reference: 1H-115 Actual @ 92.96usft (Doyon 142) SNs: Kuparuk 1H Pad MD Reference: IH -115 Actual @ 92.96usft (Doyon 142) Well: 1H-115 North Reference: True Wellbore: 11-1-115 Survey Calculation Method: Minimum Curvature Design: 11-1-115 Database: OAKEDMP2 Survey 7713/2018 8: 11: 01AM Page 5 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +W -S +F/ -W Northing Eating DLS Section (usft) (°) (°) (usft) (usft) (usip (usft) (It) (fry (°/1001 (it) Survey Tool Name 8,406.44 80.90 80.26 3,422.52 3,329.56 902.70 6,355.24 5,981,936.32 555,901.94 1.61 6,341.47 MWD+1FR-AK-CAZSC(4) 8,501.21 80.84 80.16 3,437.56 3,344.60 918.61 6,447.45 5,981,952.83 555,994.03 0.12 6,434.30 MWDAFR-AK-CAZSC(4) 8,596.47 80.48 80.07 3,45302 3,360.06 934.75 6,540.05 5,981,969.58 556,086.52 0.39 6,527.58 MWD+IFR-AK-CA2SC (4) 8,691.23 80.58 80.27 3,468.61 3,375.65 950.71 6,632.15 5,981,985.15 556,178.50 0.23 6,620.31 MWDAFR-AK-CAZ-SC(4) 8,786.24 80.34 80.46 3,484.36 3,391.40 966.39 6,724.52 5,982,002.44 556,270.76 0.32 6,713.24 MWD+IFR-AK-CAZSC(4) 8,881.91 80.45 80.21 3,500.32 3,407.36 982.22 6,817.51 5,982,01B.89 556,363.63 0.28 6,806.79 MWD+IFR-AK-CAZ-SC(4) 8,977.25 79.47 77.66 3,516.94 3,423.98 1,000.24 6,909.64 5,982,037.51 556,455.63 2.83 6,900.16 MWD+IFR-AK-CAZ-SC(4) 9,072.56 77.37 74.82 3,536.08 3,443.12 1,022.43 7,000.32 5,982,060.30 556,546.15 3.66 6,993.37 MWD+IFR-AK-CAZ-SC(4) 9,167.65 75.32 72.77 3,558.53 3,465.57 1,048.21 7,089.04 5,982,085.66 556,634.69 3.01 7,085]5 MWD+1FR-AK-CAZSC(4) 9,262.82 73.24 68.33 3,584.32 3,491.36 1,078.69 7,175.40 5,982,117.71 556,720.84 4.99 7,177.24 MWDAFR-AK-CAZ-SC(4) 9,358.56 70.97 63.15 3,613.76 3,520.80 1,116.08 7,258.43 5,982,155.64 556,803.61 5.67 7,267.68 MWD+IFR-AK-CAZ-SC(4) 9,453.16 69.85 59.34 3,645.49 3,552.53 1,158.99 7,336.55 5,982,199.01 556,881.44 3.97 7,354.82 MWD+IFR-AK-CAZ-SC(4) 9,548.82 67.73 57.48 3,680.09 3,587.13 1,205.64 7,412.51 5,982,246.21 556,957.08 2.86 7,441.12 MWD+IFR-AK-CAZ-SC(4) 9,643.56 65.08 55.44 3,718.02 3,625.06 1,253.59 7,484.87 5,982,294.63 557,029.12 3.42 7,524.33 MWD+IFR-AK-CAZ-SC (4) 9,737.97 63.57 53.54 3,758.92 3,665.96 1,303.00 7,554.14 5,982,344.50 557,098.05 2.42 7,605.02 MWD+1FR-AK-CAZ-SC(4) 9,833.38 60.96 50.84 3,803.33 3,710.37 1,354.74 7,620.85 5,982,396.67 557,164.42 3.71 7,683.95 MWD+IFR-AK-CAZ-SC (4) 9,928.41 60.00 49.04 3,850.15 3,757.19 1,407.95 7,684.15 5,982,450.30 557,227.35 1.93 7,760.03 MWD+IFR-AK-CAZ-SC (4) 10,023.12 59.98 47.49 3,897.52 3,804.55 1,462.54 7,745.34 5,982,505.29 557,288.18 1.42 7,834.51 MWD+IFR-AK-CAZ-SC(4) 10,118.84 60.02 46.19 3,945.39 3,852.43 1,519.24 7,805.81 5,982,562.38 557,348.26 1.18 7,908.92 MWDAFR-AK-CAZ-SC(4) 10,214.94 60.05 45.28 3,993.39 3,900.43 1,577.35 7,8(3503 5,982,620.88 557,407.49 0.82 7,982.92 MWD+IFR-AK-CAZ-SC(4) 10,309.28 60.02 45.46 4,040.51 3,947.55 1,634.77 7,923.59 5,982,678.67 557,465.26 0.17 8,055.33 MWD+IFR-AK-CAZ-SC(4) 10,404.59 60.05 44.71 4,088.11 3,995.15 1,693.07 7,982.06 5,982,737.35 557,523.34 0.68 8,128.29 MWD+IFR-AK-CAZ-SC(4) 10,499.64 59.91 44.23 4,135.67 4,042.71 1,751.80 8,039.72 5,982,796.46 557.580.60 0.46 8,200.60 MWD+IFR-AK-CA7-SC(4) 10,594.20 60.25 43.33 4,182.83 4,089.87 1,810.97 8,096.42 5,982,856.00 557,636.91 0.90 8,272.12 1vlWD+1FR-AK-CAZ-SC(4) 10,641.81 59.98 43.26 4,206.55 4,113.59 1,841.02 8,124.73 5,982,886.23 557,665.01 0.58 8,307.98 MWD+IFR-AK-CAZ-SC(4) 10,706.00 59.98 43.26 4,238.67 4,145.71 1,881.49 8,162.82 5,982,926.95 557,702.83 0.00 8,356.24 PROJECTED WTD 7713/2018 8: 11: 01AM Page 5 COMPASS 5000.14 Build 85 Cement Detail Report IH -115 String: Conductor Job: DRILLING ORIGINAL, 7/3/2018 00:00 Cement Details Description Conductor Cement Cementing Start Date 10/31/2016 20:00 lCementing End DateWellbore 10/31/2016 20:00 Name 1 H-115 Comment 10 yards (5.5 sacks) of aggregate cement poured into backside by AFC. CMT/aggregate ratio of 564/3520 per yard Cement Stages Stage # 1 Description Conductor Cement Objective Top Depth (ftKB) 39.0 Bottom Depth (ftKB) 119.0 Full Return? No Vol Cement... Top Plug? No Elm Plug? No Q Pump Init (bbl/m... Q Pump Final (bbl/... D Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No I Stroke (ft) Rotated? No I Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (c P) Thickening Time (hr) CmPrStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 1/1 ReportPrinted: 8/14/2018 Cement Detail Report 1 H-115 String: Surface Casing Cement Job: DRILLING ORIGINAL, 7/3/2018 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 1715/201816,30 17/5/201818A5 II H-115 Comment Line up on SLB cement unit & pump 5 bbls of CW 100, 4 bpm, 97 psi. Pressure test lines to 3500 psi, good. Pump 35 bbis of CW 100, 4 bpm, 100 psi. Pump 78.2 Wis. 10.5 ppg MP II, 34 bpm, 100 psi. Drop bottom plug. Pump 338.2 bbls of 11.0 ppg DeepCRETE lead cement, 5.5 bpm, 160-225 psi. Pump 59.5 bbls of 12 ppg LiteCRETE tail cement, 4.8 bpm, 215 psi. Drop top plug. Pump 10 bbls of water, 6 bpm, 175 psi. Swap to rig & pump 95.76 bbls, 9.4 ppg, LEND, 8 bpm, 360 psi. Reduce rate to 6 bpm, 290 psi & continue for a total of 143.8 bbls pumped. Reduce rate to 2 bpm, 197 psi & continue for a total of 159.34 bbls (casing volume plus half of shoe track) pumped without bumping the plug. Total of 49.3 bbls of 11.0 ppg cement returns to surface. Full returns during cement job, no losses. Hold 200 psi 10 minutes & check floats, good. CIP @ 18:40 his. Casing reciprocated till 128 bbis of displacement with last PU 113K, SO 87K. Cement Stages Stage # 1 Description Objective Top Depth INKS) Bottom Depth (ftKB) Full Return? Voi Cement... Top Plug? Btm Plug? Surface Casing Cement 43.4 1,803.0 Yes 49.3 Yes Yes Q Pump Inst (bbUm... q Pump Final (6b11...P5'J Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (it) Rotated? Pipe RPM (rpm) 4 2 200.0 Yes 20.00 No Tagged Depth (ftKB) hod Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Line up on SLB cement unit & pump 5 bbls of CW 100, 4 bpm, 97 psi. Pressure test lines to 3500 psi, good. Pump 35 bbis of CW 100, 4 bpm, 100 psi. Pump 78.2 bbls, 10.5 ppg MP II, 3-4 bpm, 100 psi. Drop bottom plug. Pump 338.2 bbls of 11.0 ppg DeepCRETE lead cement, 5.5 bpm, 160-225 psi. Pump 59.5 bbls of 12 ppg LiteCRETE tail cement, 4.8 bpm, 215 psi. Drop top plug. Pump 10 bbis of water, 6 bpm, 175 psi. Swap to rig & pump 95.76 bbls, 9.4 ppg, LSND, 8 bpm, 360 psi. Reduce rate to 6 bpm, 290 psi & continue for a total of 143.8 bbls pumped. Reduce rate to 2 bpm, 197 psi & continue for a total of 159.34 bbls (casing volume plus half of shoe track) pumped without bumping the plug. Total of 49.3 bbls of 11.0 ppg cement returns to surface. Full returns during cement job, no losses. Hold 200 psi 10 minutes & check floats, good. CIP (03 18:40 hrs. Casing reciprocated till 128 bbis of displacement with last PU 113K, SO 87K. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bim (ftKB) Amount (sacks) Class Volume Pumped (bbl) Pre Flush-CW100 I I I 1 1 40.0 Yield (ft /sack) Mix H2O Ratio (gallsa... Free Water (%) Density (lb/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 8.37 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Ban (ftKB) Amount (sacks) Class Volume Pumped (bbl) Spacer-MudPushll I I I 78.2 Yield (ft'Isack) Mix H2O Ratio (gallsa... Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 43.4 1,303.0 994 1 G 338.2 Yield (ft /sack) Mix H2O Ratio (gallsa... Free Water (°k) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr t (psi) 1.91 6.87 1 11.00 59.6 4.58 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Ban (ftKB) Amount (sacks) ClassVolume Pumped (bbl) Tail Cement 1,303.0 1,803.0 202 G 59.5 Yield (ft /sack) Mix H2O Ratio (gallsa... Free Water (h) Density (lb/gai) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.65 5.47 1 12.00 68.7 3.65 Additives Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 8/14/2018 Cement Detail Report 1H-115 String: Production Casing Cement Job: DRILLING ORIGINAL, 7/31201800:00 Cement Details Description Cementing Start Date CementingEnd Date Wellbore Name Production Casing Cement 7/14/2018 03:15 7/14/2018 05:30 1H-1 15 Comment Pump 5 bbls of H2O & test lines to 3500 psi, good. Load #1 plug. Pump 39.9 bbls of 12.5 ppg MP II at 5 bpm, 450 psi. Load #2 plug. Pump 215 bbls of 15.8 ppg Tail slurry cement at 5.8 bpm, 230 psi. Load top plug. Pump 405 bbl, 9.0 ppg KW brine at 6 bpm, ICP 216 psi, FCP 1319 psi to bump top plug. Pressure up 1820 psi & hold for 5 minutes. Bleed off pressure, shut in & observe no pressure increase. Floats good. CIP 05:30 hrs. Note: Reciprocated pipe 15-20'throughout job up until hole got sticky 100 bbls into displacement and then landed off on hanger. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Realm? Vol Cement... Top Plug? Stan Plug? Production Casing 4,750.0 10,706.0 Yes 0.0 Yes Yes Cement Q Pump Init (bbgm... Q Pump Final (bbl/... Q Pump Avg (bb#...P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 4 235 118.0 1,319.0 Yes 20.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 10,570.0 Wireline Comment Pump 5 bbls of H2O & test lines to 3500 psi, good. Load #1 plug. Pump 39.9 bbls of 12.5 ppg MP II at 5 bpm, 450 psi. Load #2 plug. Pump 215 bbls of 15.8 ppg Tail slurry cement at 5.8 bpm, 230 psi. Load top plug. Pump 405 bbl, 9.0 ppg KW brine at 6 bpm, ICP 216 psi, FCP 1319 psi to bump top plug. Pressure up 1820 psi & hold for 5 minutes. Bleed off pressure, shut in & observe no pressure increase. Floats good. CIP 05:30 hrs. Note: Reciprocated pipe 15-20' throughout job up until hole got sticky 100 bbls into displacement and then landed off on hanger. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bum (ftKB) Amount (sacks) Class Volume Pumped (bbl) Spacer 1 3,645.0 4,750.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%I Density (lb/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr t (psi) 12.50 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bum (ftKB) Amount (sacks)Class Volume Pumped (bbl) Tail Cement 4,750.0 10,706.0 1,049 C 215.0 Yield (ft'/sack) Mix H2O Ratio (gages... Free Water (%) Density (/algal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 7 (psi) 1.16 5.07 1 15.80 108.3 3.75 Additives Additive Type Concentration Cone Unit label Page 1/1 ReportPrinted: 8/14/2018 MEMORANDUM To: Jim Regg 6/I P.I. Supervisor I FROM: Brian Bixby Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 14, 2018 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. IH -115 KUPARUK RIV U WSAK IH -I 15 Ste: Inspector Reviewed By: P.I. Sup" J NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 11-1-115 API Well Number 50-029-23605-00-00 Inspector Name: Brian Bixby Permit Number: 218-053-0 Inspection Date: 8/7/2018 Insp Num: miteD6180803094858 Rel Insp Num: Tuesday, August 14, 2018 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ', I1-1-115 Typelnj w TVD 3840 Tubing 1041 10344 1039 - 1039 PTD ',-- _2180530 ' Type Test SPT Test psi 1500 IA 435 1790 1740 1735 - BBL Pumped: 1.2 - BBL Returned: 1.9 OA 3s eo so ws - Interval — NITA1. P/F — Notes: Tuesday, August 14, 2018 Page 1 of 1 Originated: Schlumberger PTS- PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: 'Y AOGCC . ATTN: Natural Resources Technician II J Alaska Oil & Gas Conservation Commision CY 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 LIBU55 29547 2N-339 50.103-20261-00 ORDER DSOS-00149 FIELD NAME DESCRIPTION KUPARUK RIVER SERVICE WL DELIVERABLE DESCRIPTION Caliper DATA I FINAL FIELD Color DATELOGGED Prints 11 -Jul -18 CD's 1 2T-37 50-103.20227-00 DSOS-00151 KUPARUK RIVER WL Caliper FINAL FIELD 13 -Jul -18 1 1H-115 50.029-23605-00 DSOS-00152 KUPARUK RIVER WL CBL-SCMT FINAL FIELD 14 -Jul -18 1 1H-115 50-029-23605-00 DSOS-00152 KUPARUK RIVER WL TCP Correlation FINAL FIELD 15 -Jul -18 1 1H-115 50-029-23605-00 6V4X-00030 KUPARUK RIVER WL TCP Correlation FINAL FIELD 18 -Jul -18 1 1Y-18 50-029-22390-00 DV4X-00031 KUPARUK RIVER WL PPROF FINAL FIELD 19 -Jul -18 1 18-05 50.029-20237.00 DV4X-00032 KUPARUK RIVER WL IPROF FINAL FIELD 20-JUI-18 1 3N-06 50-029-21538-00 DV4X-00033 KUPARUK RIVER WL Perf FINAL FIELD 21 -Jul -18 1 1H-21 50.029-22355.00 DV4X-00034 KUPARUK RIVER WL Caliper FINAL FIELD 22 -Jul -18 1 21.1-13 50-029.21261-00 DV4X-00036 KUPARUK RIVER WL PPROF FINAL FIELD 24 -Jul -18 1 1111 9 7 9018 10 Transmittal Print Name/ / Signature `� Date Please return via courier or sign/scan and email a copy to Schlumberger and OPAL / 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. Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760fax Delivered to: '1 y y/ AOGCC ATTN: Natural Resources Technician II \ J Alaska Oil & Gas Conservation Commision Y \U• 333 W. 7th Ave, Suite 100 —.:. Anchorage, AK 99501 11 8U55 7TTRANSMITTAL DATE �� RANSMITTAL# WELL NAME 2N-339 2T-37 1H-115 1H-115 1H-115 1Y-18 API # 50-103-20261-00 50-103-20227-00 50-029-23605-00 50-029-23605-00 50.029-23605-00 50-029-22390-00 # DSO5-00149 DSOS-00151 DSOS-00152 DSOS-00152 DV4X•00030 DV4X-00031 FIELD NAME DESCRIPTION KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL WL DELIVERABLE DESCRIPTION Caliper Caliper CBL-SCMT TCP Correlation TCP Correlation PPROF DATA FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD DATELOGGED Prints 11 -Jul -18 13 -Jul -18 14 -Jul -18 15 -Jul -18 18 -Jul -18 19 -Jul -18 CD's 1 1 1 1 1 1 1B -OS 3N -O6 1H-21 2U-13 50-029-20237-00 50-029-21538-00 50-029-22355.00 50-029-21261.00 DV4X-00032 DV4X-00033 DV4X-00034 DV4X-00036 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WIL WL WL WL (PROF Perf Caliper PPROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 20 -Jul -18 21 -Jul -18 22 -Jul -18 24 -Jul -18 1 1 1 1 10 Transmittal Signature Date Please return via courier or sign/scan and email a copy to Schlumberger and CPAI. /,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. Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: r7 AOGCC o ATTN. Natural Resources Technician 11 J Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - ,Shh Anchorage, AK 99501 118053 TRANSMITTALDATE TRANSMITTAL# t '' WELLNAME 2N-339 2T-37 1H-115 1H-115 1H-115 1Y-18 1B-05 3N-06 1H-21 2U-13 API # 50-103.20261-00 50-103.20227-00 50.029-23605-00 50-029-23605-00 50-029-23605-00 50-029-22390-00 50-029.20237-00 50-029-21538-00 50.029-22355-00 50.029-21261-00 # USOS-00149 DSOS-00151 DSOS-00152 DSOS-00152 DV4X-00030 6V4X-00031 DV4X-00032 DV4X-00033 DV4X-00034 DV4X-00036 FIELD NAME DESCRIPTION KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL WL WL WL WL WL DELIVERAKE DESCRIPTION Caliper Caliper CBL-SCMT TCP Correlation TCP Correlation PPROF IPROF Perf Caliper PPROF DATA TYPE FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD DATE LOGGED--Prjnts---rD-s,- 11 -Jul -18 13-Jul 14 -Jul -18 15 -Jul -18 18 -Jul -18 19 -Jul -18 20 -Jul -18 21 -Jul -18 22 -Jul -18 24-Ju1-18 1 1 1 1 1 1 1 t 1 1 10 Signature Date return via courier or sign/scan and email a copy to Schlumberger and CPAI. A Transmittal Receipt signature confirms that a package (box, Fenvelope, 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 poi nt. 218053 29535 erger Drilling & Measurements Product Delivery Transmittal #: 18JUL18-SP03 Customer: ConocoPhillips Alaska, Inc. Dispatched To: AOGCC: Natural Resources Tech Well Name: 1H-115 Date Dispatched: 18 -Jul -18 Service Order #: 18AKA0012 Dispatched By: Stephanie Pacillo Product Description Hardcopy Digital Copy Logging Date Color Log Prints: N/A Contents on CD 12 -Jul -18 VISION Resistivit 2" MD x 5" MD x 2" TVD RECEIVED 5" TVD JUL 18218 AOGC , Digital Data N/A Contents on CD LAS/DLIS Data x Surveys N/A Contents on CD Directional Survey Nad27 x Directional Survey Nad83 x Gyrodata Survey 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.Osterkam conoco llios.com AlaskaPTSPrintCenter slb.com Attn: Tom Osterkamp At6 Stephanie Pacillo Received By: 4 Loepp, Victoria T (DOA) From: Sent: To: Subject: Follow Up Flag: Flag Status: Thank you Victoria. Nick Lehman PTD -I 18-o5-3 Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Sunday, July 15, 2018 12:30 AM Loepp, Victoria T (DOA) RE: [EXTERNAL]Re: KRU 11-1-115 (PTD: 218-053) CBL and request for permission to proceed with perforating Follow up Flagged Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick.R.Lehman@ConocoPhiliips.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Sunday, July 15, 2018 12:26 AM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: [EXTERNAL]Re: KRU 1H-115 (PTD: 218-053) CBL and request for permission to proceed with perforating Nick, Approval is granted to proceed with your perforating strategy. Victoria Sent from my iPhone On Jul 14, 2018, at 11:56 PM, Lehman, Nick R <Nick.R.Lehman@conocophillips.com> wrote: Victoria, Please see attached CBL and cement review for 1H-115. We are currently rigging down E -line equipment and are requesting permission to proceed with our perforating strategy as planned. Please let us know if we have permission as soon as possible. Thanks, Nick Lehman Drilling Engineer 1 ConocoPhillips Alaska Office (907)263-4951 I Cell (832)499-6739 Nick.R.Lehman@ConocoPhillips.com <iH-115 7inch Production Cement Report.pdf> <3ft shift SCMT_Log_(_SCMT_VDL_Image_)_14Jull8_234654.pdf> Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Sunday, July 15, 2018 12:26 AM To: Lehman, Nick R Subject: Re: KRU 1H-115 (PTD: 218-053) CBL and request for permission to proceed with perforating Follow Up Flag: Follow up Flag Status: Completed Nick, Approval is granted to proceed with your perforating strategy. Victoria Sent from my iPhone On Jul 14, 2018, at 11:56 PM, Lehman, Nick R <Nick. R.Lehman@conocophillips.com> wrote: Victoria, Please see attached CBL and cement review for 1H-115. We are currently rigging down E -line equipment and are requesting permission to proceed with our perforating strategy as planned. Please let us know if we have permission as soon as possible. Thanks, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Lehman PConocoPhillios. com <1H-115 7inch Production Cement Report.pdf> <3ft shift SCMT_Log_(_SCMT_VDL_Image_)_14Jull8_234654.pdf> A n Wellhead / Tubing Hanger I True 13-3/8" x 4-N" HYD563, 5M Insulated Condudan 20' Casing 3-1/2", 9.2 #, Lr80, Hyd 563 lied Through Ii.ker114: 9912 MD Mule Dmp Gauge Mandrel -- 2812"Canna DS Nipple ---� Upper MMG Lower MMG Fad Through Paeke Jl3: 10,979 MD Multi DmP Gauge Mahal — UpprMMG lanae, MMG Crossomr 6eiow TH : 4-1/2" x 3 V2" Tubing 143/4- 45.5#, L-80 HYD563 Q 1,798 (t MD 1 H-115 Injector Post Drilling & Pre -Completions formation Tops Base of Permafrost: 1,664' MD / 1,637' TVD Ugnu Top: 6,422' MD / 3,092' TVD N Sands: 9,266' MD 13,593' TVD 3-12" MMG with SGV West Sak D: 9,957' MD/ 3,065' TVD West Sak B: 10,104' MD / 3,939' TVD West Sak A: 10,173' MD / 3,973' TVD RA/PIP Tags C• 2.W & 9.751' MD 1! "D" Sand Penoratlons: 9957' - 10046' MD Fad Through Packer42 IQ 190 MD Muni Dhup Gauge Mandol UpprMMG IanverMMG Med Thmugh Packer 41: IQ283"MD Single Omp Gauge MwWml — !all- CameoX Nipple --- Upp" MMG _ 1m er MMG Baker WIV Scnper'Mitgret Awy — I3nmblrnn rruntSna "B" Sand Perforations: 10105'- 10171' MD A4 Sand Perforations: 10204'- 10235' MD A3 Sand Perforations: 10317'- 10350' MD Fes— 7" 26#, L-80, HYD563fFXP qr 10,696'MD 4234' TVD 1 July 14, 2018 1• a • Cement Slurry: • 1041 sacks 15.8 ppg tail cement • Job Comments: • Maintained proper cement mixing density • Good returns throughout job • Reciprocated pipe • Saw good lift pressure • Bumped plugs and floats held. • TOC identified at 4,750' MD / 2,813' TVD • 4,538' MD above pool top • 780' ND above pool top • Pressure tested 7" casing to 3,500 psi for 30 min 1H-115 Pump Chart �ImC •rvr.ary ,4, n.., food li ptessure coment j i ConmcoPhillips T Cement Detail Report IH-115 String: Production Casing Cement Job: DRILLING ORIGINAL, 7/3/2018 00:00 Camert Details Deacriptlan Cemamlug slim Date CemerNrp C-ntl Deb W011 mName Pmdupb00 Casing Cement 7/14201803:15 7/1420180330 iH-115 cemmam Pump 5 Cols o1 H2O & test lines to 35M psi, good. Load Of plug. Pump 39.9 this 0112.5 ppg MP II at 5 bpm. 450 psi. Load W plug. Pump 215 blob of 15.8 ppg Tell slurry cement et 5.8 bpm, 230 pen. Load top plug. Pump 405 W 9.0 ppg KW bine at 8 bpm. ICP 218 psi, FCP 1319 pin to bump top plug, Pressure up 1820 psi 8 hold for 5 minutes. Bleed o8 pressure, shut in & Mearve no pressure increase. Floats good. CIP 05:30 hat. Note: Rhoprocated pipe 15.20' throughoi up until hole got sbny 10001,15 into displacement and Men landed Won hangar. Cement Stages Stage e 1 D siulplba pblapd. Tap Depth (Met aoNom When finial FWI Retumi Vol c.ohno... TW Plua> Btm plua> Produd"Casing 4,750.0 10.706.0 Yea 0.0 Yes Yes Cement Q Ru "p MR (Deym... p Pump Final Dfliv . Q Pump Aya (MW... P Pump Flow (poll p PWp Bump l.D Pedp> Stant, mi,Rolalatli PIpe RPM lam) 4 4 235 118.0 1,319.0 Yes 20.00 No Tr41gFd D.thl"Ill Tag Mamoe Depth Me Dditd Dud To Jose) one put Dlamater(in) 10.570.0 Wilelire Canaan" Pump 5 MIs of H2O & test livres to 3500 psi, good, Load#1 plug. Pump 39.9 MIs of 12.5 ppg MPH at 5 bpm, 450 psi. Load s2 plug. Pump 215 Mb of 15.6 ppg Tail slurrycement et 5 B 0pm. 230 pal Load tap plug. Pump 405 bbl. 9.0 ppg KW brine st 6 bpm, ICP 218 psi, FCP 1319 psi to Dump top plug. Pressure up 1820 M & MId for 5 minutes. Blood o0 pressure, shut In & observe no plassuro increase. Floats good. CIP 05.30 him Note: Reopnooked pipe 1820 throughout job up unlit hole gat sticky 100 phla into dusplacemem and then landed off on hanger Cement Fluids & Additives Fluid Fluid Type Flute Daacdpaoa estimated Top lsKel at Ben (hsBl Amours ne,a) Cie. VoWme Pumped lbM) Yield IIpy.ca) .19 "a Rano (wyMa... Free Water I, OemM db/W9 PMadio Vi.oaltylcPl niskepin Tlu.lhn Cmprelrl(pen Additli es MWI. Ty. CormemaVOn Cuncunoleeel Page 111 Repoil Printed: 71IW2018 Schlumberger, Laboratory Cement Test Report 1H-115 Intermediate Load 1 Field Blend Airslide 0119 s MNn. F1u1d No : PN(191nr Client : CPN Location I Rg : Doyon 142 Date : JuH,M We0 Name :1H-116 Fcld : Ku ruk Daniel Himel D047 0.0209aV Anlifoam BR000D03A0 D0850.300%BWGC D 28 imemm�t GPDP21 D256 0.500%aWOC Ruld Loss PPRM 11 BD20 Rheolcov R1B1 Tem enure 300 I 127.0 80 d F F 127.0 A�.,a,e 127.0 Up 186.0 72 d F Down 188A Averaqe 168.0 200 94.0%A N:q hrmn 95b 120.0 120.0 120.0 100 66.0 81.0 59.569.0 Fluid Loss BBA 69.6 W 39.0 0.0 42b1 46.0 45A 45.5 30 26.0 95.0 30.5 I 28.0 254 26b 6 14.0 U.0 2pb 7.0 8.0 Bb 3 11.0 27.0 1" 1 4.0 4.0 4.0 10 sec GN 47tl -50.165111100112 4-4.171bI110002 10 min Gel 55 d, 58,70101{1002 10 22 _,D17161110 mwo.wmpuletl L Vlewa6y__ 108.335 cP Yieltl Point:20.W 2NI1062 Vism :155.1W.10 Yield Poin1:14.2481V10062 Thickonin Time 0 Ek W:Iq hr:mn SO Bc qA hr:.. ]0 & iM hr:mn 100 ec N:q hrmn Free Fluid 2 hn RAI 4'10 At 80 F aM 45 irid Ssdmenla6an: Nons Fluid Loss API Fluid Lova 38 mL 19 mL in 0 minutes x172 F and 1000 VS1 Comments Tme into blenderf wnex: 12 sed 13 sec Page t STATE OF ALASKA ReviewedBy: OIL AND GAS CONSERVATION COMMISSION P.I. SuprOGZ 7116 BOPE Test Report for: KUPARUK RIV U WSAK 1 H-115 - Comm Contractor/Rig No.: Doyon 142 - PTDN: 2180530 DATE: 7/6/2018 Inspector Matt Herrera - Insp Source Operator: CONOCOPHILLIPS ALASKA, INC. Operator Rep: Rink / Lundale Rig Rep: Newman/ Fritz Inspector Type Operation: DRILL Sundry No: Test Pressures: Inspection No: bopMFHI80707151907 _ Rams: Annular: Valves: MASP: Type Test: INIT 250/3500 " 250/3500" 250/3500" 1412 - Related Insp No: MISC. INSPECTIONS: FLOOR SAFTY VALVES: P/F Location Gen.: _P " Housekeeping: P _ PTD On Location P Standing Order Posted P Well Sign P ' Dirt. Rig P Hazard Sec. _ P Misc NA FLOOR SAFTY VALVES: TEST DATA MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector 112S Gas Detector MS Misc Visual Alarm P " P —P. --P- P__ P - P P P _'_ P P FP NA NA BOPSTACK: ACCUMULATOR SYSTEM: Quantity P/F Upper Kelly I P Lower Kelly I P Ball Type . 1_ P _ Inside BOP 1 P FSV Misc 0 NA TEST DATA MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector 112S Gas Detector MS Misc Visual Alarm P " P —P. --P- P__ P - P P P _'_ P P FP NA NA BOPSTACK: ACCUMULATOR SYSTEM: P/F Time/Pressure P/F System Pressure _ 3075 P Pressure After Closure 1750 P 200 PSI Attained 7 P Full Pressure Attained 55 P Blind Switch Covers: Yes P Nitgn. Bottles (avg): X2383 P ACC Misc 0 NA Quantity Size P/F Stripper 0 -- _NA_ Annular Preventer 1 13 5/8" P " #1 Rams 1 " 7" P 42 Rams 1 - Blinds _ P 93 Rams 1 3 1/2" x 6" P #4 Rams 0 NA #5 Rams _ 0 ___NA_ 46 Rams 0 NA Choke Ln. Valves 1 3 1/8" P ' HCR Valves 2 "31/8" P ' Kill Line Valves 3 - 3 1/8" P Check Valve 0 NA_ BOP Misc 0 NA CHOKE MANIFOLD: Quantity P/F No. Valves _ 14 P - Manual Chokes 1 P ' Hydraulic Chokes 1 P CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F - Inside Reel Valves 0 NA Number of Failures: 1 Test Results Test Time 5.5 Remarks: BOP test using 3 test joint sizes 3 1/2, 4 1/2 and T'. One Fail/Pass on H2S sensor in Pits was changed out and retested good THE STATE °fALASI�A GOVERNOR BILI. WALKER Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 Wesi Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 WWW.aOgcc.alaska. gov Re: Kuparuk River Field, West Sak Oil Pool, KRU 1H-115 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-053 Surface Location: 289' FSL, 786' FEL, SEC. 28, T12N, RI OE, UM Bottomhole Location: 3057' FNL, 3159' FEL, SEC. 26, T12N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for the permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair .k DATED this 3' day of July, 2018. RECEIVED JUL 0 2 2018 STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work:97APP, Well Class: Exploratory - Gas ❑ Service - WAG ✓ • Service - Disp ❑ 1c. Specify if well is proposed for: ❑ ❑Redrill Drill ❑✓ •Late= Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone ❑✓ Coalbed Gas Gas Hydrates ❑ Reentry Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • KRU 1H-115 - 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 10736' TVD: 4266" Kuparak River Field West Sak Oil Pool ' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 289' FSL & 786' FEL, Sec 28, T12N, R10E, UM ADI -025638, ADL025639 8. DNR Approval Number: 13. Approximate Spud Date: Top of Productive Horizon: 3544' FNL, 3647' FEL, Sec 26, T12N, R10E, UM 931695000 80-261 6/30/2018 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 3057' FNL, 3159' FEL, Sec 26, T12N, R10E, UM 2560 acres & 2560 acres 3012' to ADL025637 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 93.1' 15. Distance to Nearest Well Open Surface: x- 549553.43 ' y- 5980991.68 • Zone- 4 GL / BF Elevation above MSL (ft): 54.1' to Same Pool: 789' to 1 H-103 16. Deviated wells: Kickoff depth: 500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 60 degrees Downhole: 1,819 psi • Surface: 1,412 psi - 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling 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 1785' Surf Surf 1824' 1780' 660 sx 11.0 ppg, 193 sx 12.0 ppg 8-3/4" 7" 26# L-80 HYD563/f 10697' Surf Surf 10736' 4266' 1P81rp 15.8 ppg class G 6 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: Properly Plat BOP Sketch Drilling Program Time v. D epth Plot Shallow Hazard Analysise Diverter Sketch ✓ Seabed Report Drilling Fluid Program B B B 20 A AC 25.050 requirements ✓ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be Z7_ �g- deviated from without prior written approval. Contact Name: Scott Brunswick Authorized Name: Chip Alvord Contact Email: sCOtt.a.brunswick CO .Conn Authorized Title: Alaska Drigg Manag25 Contact Phone: 907-263-4249 Date: �-� Authorized Signature: Commission Use Only Permit to Drill fn� {� 1j U3 API Number: Permit Approval ` See cover letter for other requirements. Number: L 50- o� ._�j(p - -[j Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane gas hydrates, or gas contained in shales: Other: Samples req'd: Yes ❑ Now r Mud log req'd: Yes ❑ No L_Iy V 'go A TQ�S %� rd 3S�nPs� HzS measures: as +[� NE] Directional svy req'd: Yes No ❑ �� Spacing exception req'd: Yes ❑ No( Inclination -only svy req'd: Yes ❑� Review, I e w, C31i w/'�� / r) or Post initial /No[v]a injection MIT req'd: Yes 5 n10❑ Q! APPROVED BY 1 1 i, Approved by: V _ COMMISSIONER THE COMMISSION Date: � l Form 10401 Revised 5/2017 This permit is valid fpprov2 C�5;�05(g) � men Duplicate 7z /9�h�I� Application for Pennit to Drill, Well 1 H-115 Saved: 29 -Jun -18 June 28, 2018 Alaska Oil and Gas Conservation Commission 333 West 71 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Update to Approved Permit to Drill Well 111-115 (PTD 218-053), West Sak Sand Injector Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an update to the approved permit to drill (PTD 218-053) of an onshore grassroots injector well from the 1 H pad. The expected spud date for this well is June 30th, 2018. It is planned to use rig / Doyon 142. The main changes to the permit to drill will be the final bottom hole location to accommodate updated / spacing to a producer to be drilled after 1H-115. 1H-115 is planned to be a slant well thru the West Sak sands. The surface section will be drilled with 13-1/2" bit and run 10-3/4" casing to ±1,824' MD / 1,780' TVD. The production section will be drilled with 8-3/4" bit and run 7" casing to ±10,736' MD / 4,266' 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, diver -ter 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 Scott Brunswick at 907-263-4249 (scott.a.brunswick@cop.com) or Chip Alvord at 265-6120. Sincerely, Scott Brunswick Drilling Engineer Application for Permit to Drill Document Kuparuk Well IH -115 Well Name Requirements of 20 AAC 25.005 (fl The well for which this application is submitted will be designated as KRU 1H-115 CarwcoPhillips Location Summary _Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must he accompanied by each of the following items, except for an new already on file with the commission and identified in the application: (2) a plat idemifying the property and the property's owners and shirring (A) the coordinates of the proposed location of the well at the surface, at /lie top of each objective formation. and at total depth referenced to governmental section lines. (R) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Surrey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at nual depth: Location at Surface 289' FSL & 786' FEL, See 28, T12N, R10E UM NGS Coordinates Northings: 5,980,991.68' Eastings: 549,553.43 1Pad I RKB Elevation 93.1' AMSL Elevation 54.1'AMSL ' Location at Top of Productive Interval est Sak D Sand 3544' FNL & 3647' FWL, Sec 26, T12N, RIDE, UM NGS Coordinates Northings: 5,982,494.00' Eastings: 557,238.27' Measured De th, RKB: 9,955' Total Vertical Depth, RKB: 3,876' Total Vertical Depth, SS: 3,783' Location at Total Depth 305T FNL & 3159' FWL Sec 26, T12N R10E, UM NGS Coordinates Northings: 5,982,965.98' Eastings: 557,722.27' MeasuredDe th RKB: 10,736' Total Vertical De th, RKB: 4,266' Total Vertical Depth, SS: 4,173' and (D) other information required by 20 AAC '5.050(6); Requirements of 20 AAC 25.050(b) 1f a irell is to be intentionally deviated. the application for a Permit m Drill (Form 10-401) most (1) include a plat, drmrn to a suitable scale. showing the path of the proposed wellbore. Including all adjacent mellbore.s within 100 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2) for all it ells within 200 feet of the proposed wellbore (A) list the manes of the operators of those wells, to the extent that those names are known or discoverable in public records. and show that each named operator has been Burnished a copy of the application by certified niad: or (R) state that the applicant is the only affected a,vner. 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 for an item already on file with the commission and idem fed in the application: (3) a diagram and description of the blmvout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036. or 20 AAC 25.037, 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 fora Permit to Drill must be accompanied by each of dre follnvhng items. except for an item already i n Ble with the commission and identified in the application: (4) information on drilling haeads. Including (A) the maximi n donwhole pressure that may be encountered, criteria used to dete more it. and weernmmn potential surface pressure based on a methane ,gr adient; The maximum potential surface pressure (MPSP) while drilling 1H-115 is calculated using an estimated maximum reservoir pressure of 1,819 psi (based on 1H-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 4,068' TVD: A Sand Estimated. BHP = 1,819 psi A Sand estimated depth = 4,068' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 407 psi (4,068' TVD * 0.10 psi/ft) MPSP = BHP — gas column =1,412 psi (1,819 psi — 407 psi) (B) data on potential gas _ones: The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole in such as abnormallygeo-pressured strata. lost circulation canes. and zones that love a propensity for differential sticking: See attached 1H-115 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application lin a Permit to Drill must be accompanied by each of the follmving items, except for an item alreadv on file nvith the commission and identified in the application: (5) a description of the procedure for conducting foi motion integri0, tests. as required under 20 AAC 25.0300; A procedure is on file with the commission for performing LOT'S. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) .In applica/ion for a Pe-ndt to Drill most be acemmoonled by each of the follnving items, except for an item already on file mith the commission and identified in the application: (6) a complete proposed casing and cementing pi ogrnn as required by 20 AAC 25.030, and a description of any slotted liner. pre-peforated lineror screen to he installed Casing and Cement Program Casing and ementing Program Csg/Tbg OD Hole Sine Weight Grade Conn. Length Top MD/TVD Bon MD/TVD Cement Program (in) Rbft) (jt) (ft) �j) 20 42 94 H40 Welded 80 Surf 119/119 Existing, cement to surface Cement to Surface with 10-3/4 13-1/2 45.5 L-80 HYD563 1,785 • Surf 1,824 / 1,780 60 sx LiteCRETE Lead 11.0 ppg 93 sx Li CRETE Tail 12.0 ppg 7 8-3/4 26 L-80 HYD563 / 10,736 Surf 1,,736/4,266 VFrI sx Class G at 5.8 ppg TXPw/ , TOC at 8,W' MD 10-3/4" Surface casing run to 1,824' MD/ 1,780' TVD - Cement from 1,824' MD to 1,324'(500' of tail) with 12.0 ppg LiteCRETE, and from 1,324' to surface with 11.0 ppg LiteCRETE. Assume 150% excess annular volume for lead and 50% excess for tail, and 0% excess in 20" conductor. 10-3/4" SURFACE CEMENT CALCS Design: UniSLURRY Class G 15.8 ppg Cement to 250' TVD above Top of Ugnu C Design: 500' of Tail Cmt @ 5099/ excess in OH & Lead Cmt to surface @ 150% excess in OH Tail Cement yield = r 1.65 ft-3/sk I Lead Cement yield =r 1.91 f -3/sk 4933' MD 11.0 ppg LiteCRETE Lead Slurry ' x 0.0383 bbl/ft x 1.0 (0% excess) CONDUCTOR= 119'x 0.2477 bbl/ft x 1.0(0% excess) 29.5bbls Btm of Lead to COND= (1324'-119')x 0.0648 bbl/ft x 2.5(150% excess)l 195.2bbls Total Lead Cement= 1 224.6 bbls I or 1261.2 ftA3 or 6605ks (10736'- 120') x 0.0383 bbl/ft = 406.2 12,0 ppg LiteCRETE Tail Slurry Shoetrack= 50Y 0.0962 bbl/ft x 1.0 (0% excess) I 8.2bbls Shoe to Top of Tail= (1824'-1324')x 0.0648 bbl/ft x 1.5(50`Yexcess) 48.6 bbls Total Tail Cement= 56.8bbls or 31&7ftA3 or 193 sks Displacement= (1824'-85')x0.0962 bbl/ft =1 167.2bbls 7" Production casing run to 10,736' MD / 4,266' TVD Single stage slurry is designed to be placed from TD to 8,340' MD, which is 250' TVD above top of West Salk Pool (base of Ugnu); 35% excess annular volume. 7" Production Cement Calculations Design: UniSLURRY Class G 15.8 ppg Cement to 250' TVD above Top of Ugnu C Cement yield = 1.16 1 ftA3/sk Planned TOC = 4933' MD Shoe Track ' x 0.0383 bbl/ft x 1.0 (0% excess) 4_.§ bbls Shoe to Top of Cement = 712 905> (10736'- A x 0.0268 bbl/ft xT1.35(35% excess) 8 bbls Total Cement Volume = 2 bbls or 12 ftA3r sks Displacement = (10736'- 120') x 0.0383 bbl/ft = 406.2 bbls Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Pernin to Drill most be accompanied by each of 1he Jollmving items, except for an item already og0le with the commission and identified in the application: (7) a diagram and description of the diverter systam as required by 20 AAC 25.035, unless this regnil'ement is waived by the commission under 20 AAC 25.0350,)(2); Please reference diverter schematic attached. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application, for a Permit to Drill most he accompanied by each ofthe olloiring ile ns, except for an iter, alreaQv on file iridr the commission and identified in the application; (8) a drdhng,lhad program. including a diagran, and desenplion ol'the drillingJ(aid syslem, 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 Requirements of 20 AAC 25.005 (c)(13) , In application for a Permit to Drill must be accompanied by each o%the folloivirrg nems, except for an item already on file uah 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 Requirements of 20 AAC 25.005 (c)(13) , In application for a Permit to Drill must be accompanied by each o%the folloivirrg nems, except for an item already on file uah the commission and identified in the application: r 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 surface TD as per directional plan. Run MWD/LWD tools as required for directional monitoring (gamma ray). 3. Run and cement 10.75", 45.59, L80, HYD563 casing to surface. Displace cement with mud and check floats upon bumping plug. Notify AOGCC if top job is required. 4. Remove diverter system and install wellhead. 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 and resistivity). 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' of new hole. Perform leak off test to a minimum of 11.5ppg EMW LOT/FIT, recording results. 7. Displace to 9.0 - 9.2 ppg LSND water-based drilling fluid. 8. Directionally drill to production TD as per directional plan. 18"MD 1 9. Circulate hole clean. POOH. \.r/ 10. Run 7", 264, L80, HYD563/TXP casing to surface. (Top of cement to be / 3)49' TVD which corresponds to 250' TVD above top of the West Sak Pool.) ' 1 l . Install 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 (48.35% of published burst rating) for 30 min. 14. Run CBL on wireline. 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 and test in the direction of flow. 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 applicalion fora Permit to Drill must he accompanied by each of the folloit ing items, except for an item alreadh on file with the commission and identified in the application: (1 a) a general description of hou the operator plans to dispose of drilling nmd and cuttings and a statement of i, hether the operator intends to request authorisation under 20 AAC 25.O80for 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 II disposal well (DS I B CRI) or Prudhoe DS -4. All 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. Attachments: Attachment 1 AOR Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic Attachment 5 Diverter Layout Diagram Attachment 6 BOP Configuration Attachment 1 AOR An Area of Review plot is shown below of the IH -1 15 planned wellpath and offset wells. The included table identifies any of the offset wellbores within (or approximate to) the '/a -mile review. 1H-115wp22 Quarter Mile View AC Wells Only a•, n TOC Determine Reservoir ?goal Isolation ,n 71ozuz Name (MD /TVD) TVD) d By Status Summary 1H -I15 Proposed 10,180' / Planned: 8,340 / CBL Not Yet Column of cement to be Well does not exist yet Injector 3,852' 3,439' Drilled 250' TVD above pool top. Proposed Cement top planned to be Drilling rig Laterals are open hole w/ Pumped 1,210 sks Class I H-103 Producer 6,837' MD / more than 250' above pool 450 liner hung off at J (Currently 3,806' TVD top. well. +'eln Sap eno 3W0 Drilling) Production from Laterals. 1Mn�ll 3990 3800 p'S �Nn Intersects Pumped 770 sks Class Active 9,704'/ X000 CBL WestSak Column of cement is 804' 3900 JB00 P ? N 2,819' -... 1H.rl%.uQ O� I OG1 TVD above pool top. planned. Saw good lift J d�OPY JSO SSa O(ry $ O P$$o 1 �O O 4 50O - 1900 L 0 al Z Q .,3900---� __..maaa L 3 900 U) ' $ a$ 1 $ oP -150 I i g -300 0 1500 3000 4500 6000 7500 9000 10500 12000 __ Status Top of West Sak D Sand a•, n TOC Determine Reservoir ?goal Isolation Cement Operations Name (MD /TVD) TVD) d By Status Summary 1H -I15 Proposed 10,180' / Planned: 8,340 / CBL Not Yet Column of cement to be Well does not exist yet Injector 3,852' 3,439' Drilled 250' TVD above pool top. Proposed Cement top planned to be Drilling rig Laterals are open hole w/ Pumped 1,210 sks Class I H-103 Producer 6,837' MD / more than 250' above pool cureon liner hung off at J (Currently 3,806' TVD top. well. +'eln Sap eno � s Drilling) Production from Laterals. 1Mn�ll 3990 pressures. Intersects Pumped 770 sks Class Active 9,704'/ 5,395'/ CBL WestSak Column of cement is 804' 3900 JB00 P ? 'S 2,819' -... 1H.rl%.uQ O� I OG1 TVD above pool top. planned. Saw good lift d�OPY JSO SSa O(ry $ O P$$o 1 �O 4 - _ ' $ a$ 1 $ oP I i g Well Status Top of West Sak D Sand TOC (MD / TOC Determine Reservoir ?goal Isolation Cement Operations Name (MD /TVD) TVD) d By Status Summary 1H -I15 Proposed 10,180' / Planned: 8,340 / CBL Not Yet Column of cement to be Well does not exist yet Injector 3,852' 3,439' Drilled 250' TVD above pool top. Proposed Cement top planned to be Drilling rig Laterals are open hole w/ Pumped 1,210 sks Class I H-103 Producer 6,837' MD / more than 250' above pool cureon liner hung off at G. Cementjob wen[ as (Currently 3,806' TVD top. well. +'eln intermediate casing. planned. Saw good lift Drilling) Production from Laterals. pressures. Intersects Pumped 770 sks Class Active 9,704'/ 5,395'/ CBL WestSak Column of cement is 804' G. Cement job went pas I H-113 Injector 3,808' 2,819' sands: A, B, TVD above pool top. planned. Saw good lift C, & D pressures. 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. June 292018 1 H-115wp22 20" x 42" 10-3/4" x 13-1/2" Measured Depth 7" x 8-34' , 1000 Plan: 54.1+39 @ 93.10usft (Doyon 142) so > N i � � OD 'I 0 1500 3000 4500 6000 7500 20" x 42" 10-3/4" x 13-1/2" horizontal Departure 7" x 6-3/4" 0 55 y `a a 28 U 0 IH -11 111 11 111 it -L iH-1 1H-1 13 { 111-11 Equivalent Magnetic Distance Inc 39 390 +N/ -S IH-It4 ro0 - 1uo -� Annotation sso - aro 7. __ 111 -its aro 1060 - - 1030 1240 0.00 0 1500 3000 4500 6000 7500 9000 10500 Oeplh From Depth To SamwlRan Tool 39.00 13W.D0 IM115wpa2 tPlen: 111-115) 610-66SS 1307.07 182500 I P -115w1'/22 (Pan: 1 H-1151 MWD 130000 182500 1H115xp22 (Plan: 1H-1151 IAWO+IFRAK W K 1825 C0 Mzsco 114115wpa2 Plan: 1H-1151 MWO 1825.0010735.84 1H-115wpa2Pan: 111-115) MWD IFR -AK -CA -SC 240 North / Y: East / X: 210 Pad Elevation: 54.1 D Plan Summ 0 ,H-I,B Inc 39 390 +N/ -S IH-It4 ro0 - 1uo 30 Annotation sso - aro 7. __ 111 -its aro 1060 - - 1030 1240 0.00 0.00 1240 - 1430 60 1430 - 1310 0.00 500.00 13m IBYJ 0.00 0.00 0.00 1630 - 2180 3 700.00 2180 2350 699.96 -0.90 200 - said 105.00 2.96 gid 2919 - 3963 4 1001.33 t i 3300 3650 i 3380 4050 4450 4050 4430 4839 -5.00 25.96 9890 - 5540 .•Z'` 120 5540 - 62e0 -38.96 193.13 saw 7030 Stan 1.02 hold at 1619.43 MD 09 70M n70 6 1728.45 tel -n3 n7o 8510 150 235.72 8510 mo Start DLS 3.00TFO-15.00 9250 9990 MD Name 180 9990 - 10738 10 118.10 20" x 4T 1.10 1824.35 10-3/4" x 13-1/z' Magnetic Model & Date: BGGM2018 01 -Aug -18 i.80 10735.84 Tx 8-3/4" Magnetic North is 17.06° East of True North (Magnetic Declination) Magnetic Dip & Field Strength: 80.91 ° 57449nT Sec MD Inc Azi TVD +N/ -S +E/ -W clog Va. VSect Target Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 LBhology Column 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.00 3 700.00 2.00 105.00 699.96 -0.90 3.37 1.00 105.00 2.96 Stan CLS 2.00 TRO .5.00 4 1001.33 8.02 101.24 1000.00 -6.37 29.09 2.00 -5.00 25.96 Stan Build 2.50 �SBase 5 1619.43 23.47 101.24 1593.10 -38.96 193.13 2.50 0.00 173.29 Stan 1.02 hold at 1619.43 MD 09 Pfrost 6 1728.45 23.47 101.24 1693 .10 -47.43 235.72 0.00 0.00 211.55 Start DLS 3.00TFO-15.00 4 7 1824.35 26.26 99.56 1780.10 -54.68 275.38 3.00 -15.00 247.36 Start 20.00 hold at 1824.35 MD 8 1844.35 2626 99.56 1798.04 -56.15 284.11 0.00 0.00 25528 Start Build 450 T-3 9 2705.19 65.00 99.56 238BW -156.39 879.45 4.5D 0.00 795.30 Start DLS 4.00 TFO-56.94 ! 10 3347.19 80.41 77.95 2580.97 -138.29 1486.06 4.00 -56.94 1380.69 Start 5607,07 hold at 3347.19 MD 11 8954.25 80.41 77.95 3515.15 1016.34 6892.84 0.0 0.00 6888+81 Stan DL5400 TFO-129.07 12 9855.46 59.97 45.10 3826.06 1392.13 7073.01 4.00 -129.07 7706.51 Stan 100.00 hold at 9855.46 MD 13 9955.46 59.97 46.10 3876.10 1452.17 7695.39 0.00 0.00 7783.71 1 H 115 T01 062818 RP Stan 259.77 hold at 9955.46 MD 1410215.23 59.97 46.10 4W6.10 1078.12 7857.44 0.00 0.00 7984.27 1H-115 T02 M2818 RP Start DLS 025 TFO-1.05 1510259.73 60.08 46.09 4028.33 11K14.85 7885.21 0.25 -1.05 8018.65 Stan 476.11 hold at 10259.73 MD K-15 1610735.84 60.08 46.09 4265.80 1921.02 8182.53 0.00 0.00 8386.65 1 H-115 T03 062818 RP TD at 10735.84 I acknowledge that I have been informed of all risks, checked Nat the data is correct, ensured its and all surrou a ing wells are assignetl to the proper position, and I approve Ole scan and collision as set out in the audit pack.) approve it as the basis for the final well plan and wellsite drawings. I also at unless notified otheaOse all targets have a 100 feet lateral tolerance. B. Temple I I V. Osara I I E. Stork Approved by: DE 9oP! UG -C AUG -B UG -A Na 1 H-115wp22 39.00 To 10735.84 Spider Easing (1000 usfUin) 1 H-115wp22 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 3800- 11H-115 H-115 T03 BdF 2850- 1 H-115 T02 062818 P 1 H-115 T01 062818 P 1900 w �O� 7", x 8-3/4" o z 950 0 d o o � c° o 0 0 0 0 0 0 N a O O d o 0 0 20" x 42" 10-3/4" x 13-1/2" -9501 _1900- 0 950 1900 2850 3800 4750 5700 6650 7600 West( -)/East(+) 1 H-115wp22 IC 20" x 42' 0° 700- 000 Base Pfrost T-3 K-15 1400 a '° 0 --\INWI11�1 o2100- - ° UG -C UG -A WS WS WS WS > 10-3/4" q x 13-1/2" o o UG -B Na -D VS_C -B -A3 WS A4 WS A2 oo - - ~2800 LO Coll b O` O i O CO 3500 - ------------ - - --- - ------------- - - '---_- - ---- _.. . ---- ---- --- --------------------------------------..-___ -----------------._ ____ _.. _______ _.... ___..______ ____ ______ ------- __------------------- ------ _ _i 'o ^ 4200 0 1000 2000 3000 4000 5000 6000 —7"x8-3/4"--- 7000 8000 ^ Vertical Section at 73.000 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: IH -115 50029xxxxx00 Plan: IH -115 Plan: 1 H-115wp22 Standard Proposal Report 29 June, 2018 ConocoPhillips ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-115 Wellbore: Plan: 1H-115 Design: 1H-115wp22 Local Co-ordinate Reference: TVD Reference: MO Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: 1H-115 Plan: 54.1+39 @ 93.1 gush (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-115 Well Position +N/ -S 1,020.63 usft Northing: Latitude: +E/ -W 362.96 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: 54.10 usft Wellbore Plan: 11-1-115 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1°I (°) (nT) BGGM2018 8/1/2018 17.06 80.91 57,449 Design 1H-115wp22 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +NbS +E/ -W Direction (usft) (usft) (usft) (I 39.00 0.00 0.00 73.00 Plan Survey Tool Program Date 612&2018 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 3900 1,300.00 1 H-115wp22 (Plan: 1 H-115) GYD-GC-SS Gyrodata gyro single shots 2 1,300.00 1,825.00 1H-115wp22(Plan: 111-115) MWD MWD - Standard 3 1,300.00 1,825.00 1H-115wp22(Plan:1H-115) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 1,825.00 3,325.00 1H-115wp22(Plan: 111-115) MWD MWD- Standard 5 1,825.00 10,735.84 1H-115wp22(Plan: 1H-115) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 629/2018 9: 10:48AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kupawk 1 H Pad Well: Plan: 1H-115 Wellbore: Plan: 1H-115 Design: 1H-115wp22 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: 1 H-115 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth -NIS +El -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) just) (°1100usft) (°1100usft) (°/100usft) (°) Target 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 2.00 105.00 699.96 -0.90 3.37 1.00 1.00 0.00 105.00 1,001.33 8.02 101.24 1,000.00 -6.37 29.09 2.00 2.00 -1.25 -5.00 1,619.43 23.47 101.24 1,593.10 -38.96 193.13 2.50 2.50 0.00 0.00 1,728.45 23.47 101.24 1,693.10 -47.43 235.72 0.00 0.00 0.00 0.00 1,824.35 26.26 99.56 1,780.10 -54.68 275.38 3.00 2.91 -1.75 -15.00 1,844.35 26.26 99.56 1,798.04 -56.15 284.11 0.00 0.00 0.00 0.00 2,705.19 65.00 99.56 2,388.60 -156.39 879.45 4.50 4.50 0.00 0.00 3,347.19 80.41 77.95 2,580.97 -138.29 1,486.06 4.00 2.40 -3.37 -56.94 8,954.25 80.41 77.95 3,515.16 1,016.34 6,692.84 0.00 0.00 0.00 0.00 9,855.46 59.97 46.10 3,826.06 1,392.13 7,633.02 4.00 -2.27 -3.53 -129.07 9,955.46 59.97 46.10 3,876.10 1,452.17 7,695.39 0.00 0.00 0.00 0.00 1H-115 T01 062818 F 10,215.23 59.97 46.10 4,006.10 1,608.12 7,857.44 0.00 0.00 0.00 0.001H-115 T02062818F 10,259.73 60.08 46.09 4,028.33 1,634.85 7,685.21 0.25 0.25 -0.01 -1.05 10,735.84 60.08 46.09 4,265.80 1,921.02 8,182.53 0.00 0.00 0.00 0.001H-115 T03062818F 6/292018 9: 10,48AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: OAKEDMP2 ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kupamk 1 H Pad Plan: 111-115 Plan: 1H-115 1H-115wp22 -Kupl Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Plan: 1 H-115 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93. t Ousft (Doyon 142) True , Minimum Curvature ' 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) ('/100usft) 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 0.00 200.00 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 0.00 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 1.00 105.00 599.99 -0.23 0.84 0.74 1.00 1.00 0.00 700.00 2.00 105.00 699.96 -0.90 3.37 2.96 1.00 1.00 0.00 800.00 4.00 102.50 799.82 -2.11 8.46 7.47 2.00 2.00 -2.50 900.00 5.99 101.66 899.43 -3.92 16.98 15.09 2.00 2.00 -0.84 1,000.00 7.99 101.24 998.68 -6.33 28.91 25.80 2.00 2.00 -0.42 1,001.33 8.02 101.24 1,000.00 -6.37 29.09 25.96 2.00 2.00 -0.31 1,100.00 10.49 101.24 1,097.38 -9.46 44.66 39.94 2.50 2.50 0.00 1,200.00 12.99 101.24 1,195.28 -13.42 64.61 57.86 2.50 2.50 0.00 1,300.00 15.49 101.24 1,292.20 -18.22 88.73 79.52 2.50 2.50 0.00 1,400.00 17.99 101.24 1,387.96 -23.83 116.97 104.89 2.50 2.50 0.00 1,500.00 20.49 101.24 1,482.36 -30.25 149.29 133.92 2.50 2.50 0.00 1,600.00 22.99 101.24 1,575.25 -37.47 185.61 166.54 2.50 2.50 0.00 1,619.43 23.47 101.24 1,593.10 -38.96 193.13 173.29 2.50 2.50 0.00 1,700.00 23.47 101.24 1,667.00 45.22 224.60 201.57 0.00 0.00 0.00 1,728.45 23.47 101.24 1,893.10 47.43 235.72 211.55 0.00 0.00 0.00 1,800.00 25.55 99.95 1,758.20 -52.87 264.90 237.86 3.00 2.91 -1.80 1,824.35 26.26 99.56 1,780.10 -54.68 275.36 247.36 3.00 2.92 -1.62 1,844.35 26.26 99.56 1,798.04 -56.15 284.11 255.28 0.00 0.00 0.00 1,900.00 28.77 99.56 1,847.39 -60.41 309.46 278.27 4.50 4.50 0.00 2,000.00 33.27 99.56 1,933.07 -68.97 360.26 324.35 4.50 4.50 0.00 2,100.00 37.77 99.56 2,014.44 -78.61 417.53 376.30 4.50 4.50 0.00 2,200.00 42.27 99.56 2,091.01 -89.28 480.92 433.80 4.50 4.50 0.00 2,300.00 46.77 99.56 2,162.29 -100.92 550.04 496.50 4.50 4.50 0.00 2,400.00 51.27 99.56 2,227.86 -113.45 624.47 564.01 4.50 4.50 0.00 2,500.00 55.77 99.56 2,287.30 -126.80 703.73 635.91 4.50 4.50 0.00 2,600.00 60.27 99.56 2,340.26 -140.88 787.35 711.76 4.50 4.50 0.00 2,700.00 64.77 99.56 2,386.40 -155.61 874.81 791.09 4.50 4.50 0.00 2,705.19 65.00 99.56 2,388.60 -156.39 879.45 795.30 4.50 4.50 0.00 2,800.00 67.11 96.11 2,427.09 -168.17 965.27 873.92 4.00 2.22 -3.64 2,900.00 69.41 92.59 2,464.14 -175.19 1,057.87 960.42 4.00 2.30 -3.52 3,000.00 71.78 89.17 2,497.37 -176.61 1,152.15 1,050.17 4.00 2.37 -3.42 3,100.00 74.21 85.85 2,526.61 -172.44 1,247.67 1,142.73 4.00 2.43 -3.32 3,200.00 76.69 82.60 2,551.74 -162.68 1,343.95 1,237.66 4.00 2.48 -3.24 3,300.00 79.21 79.43 2,572.62 -147.40 1,440.52 1,334.48 4.00 2.52 -3.18 3,347.19 80.41 77.95 2,580.97 -138.29 1,486.06 1,380.69 4.00 2.54 -3.14 3,400.00 80.41 77.95 2,589.77 -127.41 1,536.98 1,432.57 0.00 0.00 0.00 3,500.00 80.41 77.95 2,606.43 -106.82 1,633.41 1,530.81 0.00 0.00 0.00 3,600.00 80.41 77.95 2,623.09 -86.23 1,729.84 1,629.04 0.00 0.00 0.00 3,700.00 80.41 77.95 2,639.75 -65.63 1,826.27 1,727.28 0.00 0.00 0.00 3,800.00 80.41 77.95 2,656.41 -45.04 1,922.69 1,825.51 0.00 0.00 0.00 3,900.00 80.41 77.95 2,673.07 -24.45 2,019.12 1,923.75 0.00 0.00 0.00 4,000.00 80.41 77.95 2,689.74 -3.86 2,115.55 2,021.98 0.00 0.00 0.00 4,100.00 80.41 77.95 2,706.40 16.74 2,211.98 2,120.22 0.00 0.00 0.00 4,200.00 80.41 77.95 2,723.06 37.33 2,308.41 2,218.45 0.00 0.00 0.00 4,300.00 80.41 77.95 2,739.72 57.92 2,404.83 2,316.69 0.00 0.00 0.00 4,400.00 80.41 77.95 2,756.38 78.51 2,501.26 2,414.92 0.00 0.00 0.00 4,500.00 80.41 77.95 2,773.04 99.10 2,597.69 2,513.16 0.00 0.00 0.00 4,600.00 80.41 77.95 2,789.70 119.70 2,694.12 2,611.39 0.00 0.00 0.00 61292018 9: f0:48AM Page 4 COMPASS 5000.14 Build 85 f ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan: 1H-115 Company: ConocoPhillips (Alaska) Inc. -Kupt TVD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54.1+39 dal, 93.10usft (Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan: 1H-115 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-115 Azimuth Depth Design: 1H-115wp22 Section Rate Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) 0 (1 (usft) lush) (usft) (usft) (°/100usft) (°/100usft) (°1100usft) 4,700.00 60.41 77.95 2,806.36 140.29 2,790.55 2,709.63 0.00 0.00 0.00 4,800.00 80.41 77.95 2,823.02 160.88 2,886.98 2,807.87 0.00 0.00 0.00 4,900.00 80.41 77.95 2,839.68 181.47 2,983.40 2,906.10 0.00 0.00 0.00 5,000.00 80.41 77.95 2,856.34 202.07 3,079.83 3,004.34 0.00 0.00 0.00 5,100.00 80.41 77.95 2,873.00 222.66 3,176.26 3,102.57 0.00 0.00 0.00 5,200.00 80.41 77.95 2,889.67 243.25 3,272.69 3,200.81 0.00 0.00 0.00 5,300.00 80.41 77.95 2,906.33 263.84 3,369.12 3,299.04 0.00 0.00 0.00 5,400.00 80.41 77.95 2,922.99 284.43 3,465.54 3,397.28 0.00 0.00 0.00 5,500.00 80.41 77.95 2,939.65 305.03 3,561.97 3,495.51 0.00 0.00 0.00 5,600.00 80.41 77.95 2,956.31 325.62 3,658.40 3,593.75 0.00 0.00 0.00 5,700.00 80.41 77.95 2,972.97 346.21 3,754.83 3,691.98 0.00 0.00 0.00 5,800.00 80.41 77.95 2,989.63 366.80 - 3,851.26 3,790.22 0.00 0.00 0.00 5,900.00 80.41 77.95 3,006.29 387.40 3,947.68 3,888.45 0.00 0.00 0.00 6,000.00 80.41 77.95 3,022.95 407.99 4,044.11 3,986.69 0.00 0.00 0.00 6,100.00 80.41 77.95 3,039.61 428.58 4,140.54 4,084.92 0.00 0.00 0.00 6,200.00 80.41 77.95 3,056.27 449.17 4,236.97 4,183.16 0.00 0.00 0.00 6,300.00 80.41 77.95 3,072.93 469.77 4,333.40 4,281.39 0.00 0.00 0.00 6,400.00 80.41 77.95 3,089.60 490.36 4,429.82 4,379.63 0.00 0.00 0.00 6,500.00 80.41 77.95 3,106.26 510.95 4,526.25 4,477.86 0.00 0.00 0.00 6,600.00 80.41 77.95 3,122.92 531.54 4,622.68 4,576.10 0.00 0.00 0.00 6,700.00 80.41 77.95 3,139.58 552.13 4,719.11 4,674.33 0.00 0.00 0.00 6,800.00 80.41 77.95 3,156.24 572.73 4,815.54 4,772.57 0.00 0.00 0.00 6,900.00 80.41 77.95 3,172.90 593.32 4,911.97 4,870.81 0.00 0.00 0.00 7,000.00 80.41 77.95 3,189.56 613.91 5,008.39 4,969.04 0.00 0.00 0.00 7,100.00 80.41 77.95 3,206.22 634.50 5,104.82 5,067.28 0.00 0.00 0.00 7,200.00 80.41 77.95 3,222.88 655.10 5,201.25 5,165.51 0.00 0.00 0.00 7,300.00 80.41 77.95 3,239.54 675.69 5,297.68 5,263.75 0.00 0.00 0.00 7,400.00 80.41 77.95 3,256.20 696.28 5,394.11 5,361.98 0.00 0.00 0.00 7,500.00 80.41 77.95 3,272.86 716.87 5,490.53 5,460.22 0.00 0.00 0.00 7,600.00 80.41 77.95 3,289.53 737.46 5,586.96 5,558.45 0.00 0.00 0.00 7,700.00 80.41 77.95 3,306.19 758.06 5,683.39 5,656.69 0.00 0.00 0.00 7,800.00 80.41 77.95 3,322.85 778.65 5,779.82 5,754.92 0.00 0.00 0.00 7,900.00 80.41 77.95 3,339.51 799.24 5,876.25 5,853.16 0.00 0.00 0.00 8,000.00 80.41 77.95 3,356.17 819.83 5,972.67 5,951.39 0.00 0.00 0.00 6,100.00 80.41 77.95 3,372.83 840.43 6,069.10 6,049.63 0.00 0.00 0.00 8,200.00 80.41 77.95 3,389.49 861.02 6,165.53 6,147.86 0.00 0.00 0.00 8,300.00 80.41 77.95 3,406.15 881.61 6,261.96 6,246.10 0.00 0.00 0.00 8,400.00 80.41 77.95 3,422.81 902.20 6,356.39 6,344.33 0.00 0.00 0.00 8,500.00 80.41 77.95 3,439.47 922.80 6,454.61 6,442.57 0.00 0.00 0.00 8,600.00 80.41 77.95 3,456.13 943.39 6,551.24 6,540.80 0.00 0.00 0.00 8,700.00 80.41 77.95 3,472.79 963.98 6,647.67 6,639.04 0.00 0.00 0.00 8,800.00 80.41 77.95 3,489.46 984.57 6,744.10 6,737.27 0.00 0.00 0.00 8,900.00 80.41 77.95 3,506.12 1,005.16 6,840.53 6,835.51 0.00 0.00 0.00 8,954.25 80.41 77.95 3,515.16 1,016.34 6,892.84 6,888.81 0.00 0.00 0.00 9,000.00 79.26 76.50 3,523.23 1,026.29 6,936.75 6,933.71 4.00 -2.51 -3.16 9,100.00 76.77 73.30 3,544.00 1,051.76 7,031.18 7,031.45 4.00 -2.49 -3.20 9,200.00 74.32 70.03 3,568.97 1,082.20 7,123.08 7,128.24 4.00 -2.45 -3.27 9,300.00 71.92 66.69 3,598.01 1,117.46 7,212.01 7,223.60 4.00 -2.40 -3.34 9,400.00 69.58 63.25 3,630.99 1,157.37 7,297.54 7,317.06 4.00 -2.34 -3.44 9,500.00 67.31 59.71 3,667.73 1,201.75 7,379.25 7,408.17 4.00 -2.27 -3.54 9,600.00 65.12 56.05 3,708.08 1,250.36 7,456.75 7,496.49 4.00 -2.19 -3.66 9,700.00 63.02 52.27 3,751.82 1,302.98 7,529.64 7,581.59 4.00 -2.10 -3.79 9,800.00 61.03 48.34 3,798.74 1,359.35 7,597.59 7,663.05 4.00 -1.99 -3.93 9,855.46 59.97 46.10 3,826.06 1392.13 7,633.02 7,706.51 4.00 -1.90 -4.04 6292018 9.10.48AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan: 1H-115 Company: Hole ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Project: (usft) Kuparuk River Unit Name (11) MD Reference: 118.10 Plan: 54.1+39 @ 93.10usft (Doyon 142) Site: 20 Kuparuk 1H Pad 1,824.35 1,780.10 North Reference: 10-3/4 True 10,735.84 4,265.80 Well: 7 Plan: 1H-115 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-115 Design: 1H-115wp22 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +EI -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°1100usft) (°1100usft) 9,900.00 59.97 46.10 3,848.34 1,418.87 7,660.80 7,740.89 0.00 0.00 0.00 9,955.46 59.97 46.10 3,876.10 1,452.17 7,695.39 7,783.71 0.00 0.00 0.00 10,000.00 59.97 46.10 3,898.39 1,478.90 7,723.18 7,818.10 0.00 0.00 0.00 10,100.00 59.97 46.10 3,948.43 1,538.94 7,785.56 7,895.31 0.00 0.00 0.00 10,200.00 59.97 46.10 3,998.48 1,596.98 7,847.94 7,972.52 0.00 0.00 0.00 10,215.23 59.97 46.10 4,006.10 1,608.12 7,857.44 7,984.27 0.00 0.00 0.00 10,259.73 60.08 46.09 4,028.33 1,634.85 7,885.21 8,018.65 0.25 0.25 -0.01 10,300.00 60.06 46.09 4,048.42 1,659.06 7,910.36 8,049.78 0.00 0.00 0.00 10,400.00 60.08 46.09 4,098.29 1,719.16 7,972.81 8,127.07 0.00 0.00 0.00 10,500.00 60.08 46.09 4,148.17 1,779.27 8,035.25 8,204.36 0.00 0.00 0.00 10,600.00 60.08 46.09 4,198.05 1,839.37 8,097.70 8,281.65 0.00 0.00 0.00 10,700.00 60.08 46.09 4,247.92 1,899.48 8,160.15 8,358.94 0.00 0.00 0.00 10,735.84 60.06 46.09 4,265.80 • 1,921.02 8,182.53 8,386.65 0.00 0.00 0.00 Design Targets Target Name -hitimiss target Dip Angle Dip Dir. TVD -Shape C) (°) (usft) 1 H-115 Tot 062818 RP 000 0.00 3,876.10 - plan hits target center - Circle (radius 100.00) 1H-115 T02062818 RP 0.00 0.00 4,006.10 - plan hits target center - Circle (radius 100.00) 1 H-115 T03 062818 RP 0.00 0.00 4,265.80 - plan hits target center - Circle (radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (11) ( ) 118.10 118.10 20"x42" 20 42 1,824.35 1,780.10 10-3/4"x13-1/2" 10-3/4 13-1/2 10,735.84 4,265.80 7" x 8-3/4" 7 8-3/4 6/292018 9: 10.48AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-115 Wellbore: Plan: 1H-115 Design: 1H-115wp22 Formations Measured Vertical Depth Depth Measured (usft) (usft) 1,673.94 1,643.10 Base Pfrost 1,86345 1,815.10 T-3 2,149.67 2,053.10 K-15 6,361.02 3,083.10 UG -C 8,041.60 3,363.10 UG -B 8,785.87 3,487.10 UG -A 9,571.20 3,696.10 Na 9,955.46 3,876.10 WS_D 10,065.36 3,931.10 WS_C 10,101.33 3,949.10 WS -B 10,179.26 3,988.10 WS -A4 10,239.23 4,018.10 WS -A3 10,409.64 4,103.10 WS -A2 10,590.08 4,193.10 WS --A1 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 1H-115 ND Reference: Plan: 54.1+39 @ 93.10usft(Doyon 142) MD Reference: Plan: 54.1+39 @ 93, 10ush (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Plan Annotations Measured Vertical Local Coordinates Depth Depth +N! -S +E/ -W (usft) (usft) (usft) (usft) Comment 500.00 500.00 0.00 0.00 Start Build 1.00 700.00 699.96 -0.90 3.37 Start DLS 2.00 TFO -5.00 1,001.33 1,000.00 -6.37 29.09 Start Build 2.50 1,619.43 1,593.10 -38.96 193.13 Start 109.02 hold at 1619.43 MD 1,728.45 1,693.10 47.43 235.72 Start DLS 3.00 TFO -15.00 1,824.35 1,780.10 -54.68 275.38 Start 20.00 hold at 1824.35 MD 1,844.35 1,798.04 -56.15 284.11 Start Build 4.50 2,705.19 2,388.60 -156.39 879.45 Start DLS 4.00 TFO -55.94 3,347.19 2,580.97 -138.29 1,486.06 Start 5607.07 hold at 3347.19 MD 8,954.25 3,515.16 1,016.34 6,892.84 Start DLS 4.00 TFO-129.07 9,855.46 3,826.06 1,392.13 7,633.02 Start 100.00 hold at 9855.46 MD 9,955.46 3,876.10 1,452.17 7,695.39 Start 259.77 hold at 9955.46 MD 10,215.23 4,006.10 1,608.12 7,857.44 Start DLS 0.25 TFO -1.05 10,259.73 4,028.33 1,634.85 7,885.21 Start 476.11 hold at 10259.73 MD 10,735.84 4,265.80 1,921.02 8,182.53 TD at 10735.84 6/29/2018 9: f0:48AM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-115 Plan: 1H-115 50029xxxxx00 1 H-115wp22 ConocoPhillips Clearance Summary Anticollision Report 29 June, 2018 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad -Plan: 1H -115 -Plan: 1H-115-1H-115wp22 Well Coordinates: Datum Height: Plan: 54.1+39 @ 93,10usft (Doyon 142) Scan Range: 0.00 to 1D,735.84 usft. Measured Depth. Scan Radius is 1,269.66 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85 Scan Type: GLOBAL FILTER APPLIEDAll wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips `' ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup] Kuparuk River Unit Anticollision Report for Plan: 1 H-116- I H-115wp22 2,421.58 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) 43.65 Reference Design: Kuparuk 1H Pad - Plan: 1H -116 -Plan: 1H-115-1H-115wp22 2,575.00 Scan Range: 0.00 to 10,735.84 usft. Measured Depth. Clearance Factor Scan Radius is 1,269.68 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Major Risk 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) (usfn usft 43.65 Kuparuk 1H Pad 1H -05 -1H -05-1H-05 2,421.56 104.36 2,421.58 43.65 2,575.00 1.719 Clearance Factor Pass - Major Risk 1H -05 -1H -05-1H-05 2,438.59 102.12 2,436.59 43.65 2,600.00 1.747 Centre Distance Pass - Major Risk 1H -05 -1H -105-1H-105 2,460.04 82.04 2,460.04 27.85 2,625.00 1.514 Clearance Factor Pass - Major Risk 1H -05 -1H -105-1H-105 2,478.08 81.44 2,478.08 29.57 2,650.00 1.570 Centre Distance Pass - Major Risk 1 H-1 02 - 1 H-1 02LI - 1 H-1 0211 100.48 329.97 100.48 327.01 100.00 111.630 Centre Distance Pass - Major Risk 1H -102 -1H -102L1 -1H-10211 275.47 331.21 275.47 326.45 275.00 69.564 Clearance Factor Pass - Major Risk 1H -102 -1H -1021.2 -1H -102L2 100.48 329.97 100.48 327.01 100.00 111.630 Centre Distance Pass - Major Risk 1H -102 -1H -10212 -1H -102L2 275.47 331.21 275.47 326.45 275.00 69.564 Clearance Factor Pass - Major Risk 1H -102 -1H -102L3 -1H-10213 100.48 329.97 100.48 327.01 100.00 111.630 Centre Distance Pass - Major Risk 1H -102 -1H -102L3 -1H-1021-3 275.47 331.21 275.47 326.45 275.00 59.564 Clearance Factor Pass - Major Risk 1H -1D2 -1H -102L4 -1H-1021-4 100.48 329.97 100.48 327.01 100.00 111.630 Centre Distance Pass - Major Risk 1H -102 -1H -102L4 -1H-1021.4 275.47 331.21 275.47 326.45 275.00 69.564 Clearance Factor Pass - Major Risk 1H -103 -1H -103-1H-103 50.07 269.69 50.07 267.13 50.00 97.958 Centre Distance Pass - Major Risk 1H -103 -1H -103-1H-103 275.06 270.78 275.06 265.12 275.00 47.813 Clearance Factor Pass - Major Risk 1H -103 -1H -1031-1-1H-1031-1 50.07 269.89 50.07 267.65 50.00 120.512 Centre Distance Pass - Major Risk 1H -103 -1H -1031-1-1H-1031-1 275.06 270.78 275.06 265.25 275.00 48.939 Clearance Factor Pass - Major Risk 1H -103 -1H -103L2 -1H -103L2 50.07 269.89 50.07 267.65 50.00 120.512 Centre Distance Pass - Major Risk 1H -103 -1H -1031.2 -1H -103L2 275.06 270.78 275.06 265.25 275.00 48.939 Clearance Factor Pass - Major Risk 1H -103 -1H -10313 -1H -103L3 50.07 269.69 50.D7 267.65 50.00 120.512 Centre Distance Pass - Major Risk 1H -103 -1H -1031-3-1H-10313 8,884.12 386.78 8,884.12 257.27 10,700.0D 2.986 Clearance Factor Pass - Major Risk 1H -103 -1H -1031-4-1H-10314 50.07 269.89 50.07 267.65 50.00 120.512 Centre Distance Pass - Major Risk 1H -103 -1H -103L4 -1H-1031-4 8,668.48 346.76 8,668.48 213.82 10,375.00 2.6D8 Clearance Factor Pass - Major Risk 1H -109 -1H -109-1H-109 50.10 179.98 50.10 177.61 50.00 75.946 Centre Distance Pass - Major Risk 1H -109 -1H -109-1H-109 4D0.07 181.55 400.07 173.24 400.00 21.841 Clearance Factor Pass - Major Risk 1H -110 -1H -110-1H-110 50.22 149.89 50.22 147.54 50.00 63.703 Centre Distance Pass - Major Risk IH -110 - 11-1-110 - 1 H-110 350.18 151.49 350.18 145.31 350.00 24.500 Clearance Factor Pass - Major Risk 1H -110 -1H -110-1H-110 50.22 149.89 50.22 147.54 50.00 63.703 Centre Distance Pass - Major Risk 1H -110 -1H -110-1H-110 350.18 151.49 350.18 145.31 350.00 24.500 Clearance Factor Pass - Major Risk 29 June, 2018 - 9:07 Page 2 of 6 COMPASS ConocoPhillips Anticollision Report for Plan: 1H-115 -1 H-115wp22 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk1H Pad -Plan: 1H -115 -Plan: 1H-115.114.115wp22 Scan Range: 0.00 to 10,735.84 usR Measured Depth. Scan Radius is 1,269.68 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips (Alaska) inc. -Kupl Kuparuk River Unit 29 June, 2018 - 9:07 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 1 H-111 - 1 H-111 - 1 H-111 550.70 119.93 550.70 110.80 550.00 13.124 Centre Distance Pass - Major Risk 1H -111 -1H -111-1H-111 3,302.20 152.74 3,302.20 69.69 3,175.00 1.839 Clearance Factor Pass - Major Risk 1 H-113 - IH -113 - 1 H-113 50.06 59.85 50.06 57.28 50.00 23.297 Centre Distance Pass - Major Risk 1 H-113 - 1 H-113 - 1 H-113 349.96 61.41 349.96 55.24 350.00 9.941 Clearance Factor Pass - Major Risk IH -114 - 114-114 - 1 H-114 725.60 24.34 725.60 12.33 725.00 2.027 Centre Distance Pass - Major Risk 1H -114 -1H -114-1H-114 826.00 24.86 826.00 11.51 825.00 1.863 Clearance Factor Pass - Major Risk IH -116 - 1H-116 - 1 H-116 424.87 28.24 424.87 19.58 425.00 3.256 Centre Distance Pass - Major Risk IH -116 - 1H-116 - 1 H-116 524.78 29.03 524.78 18.31 525.00 2.707 Clearance Factor Pass - Major Risk 114-117 - 114-117 - 1 H-117 699.44 54.87 699.44 43.44 700.00 4.799 Centre Distance Pass - Major Risk 1H -117 -1H -117-1H-117 1,548.12 64.50 1,54B.12 39.30 1,550.00 2.560 Clearance Factor Pass - Major Risk 114 -118 -1H -118-1H-118 50.25 89.79 50.25 87.05 50.00 32.792 Centre Distance Pass - Major Risk 1H -118 -1H -118-1H-118 848.62 97.37 848.62 83.02 850.00 6.781 Clearance Factor Pass - Major Risk 1H -119 -1H -119-1H-119 50.04 120.09 50.04 117.74 50.00 51.099 Centre Distance Pass - Major Risk 1 H-119 - 1 H-119 - 1 H-119 424.91 123.46 424.91 115.97 425.00 16.469 Clearance Factor Pass - Major Risk 1H-401(UGNU)-1H-401-1H401 1,625.60 113.01 1,625.60 69.91 1,850.00 2.622 Clearance Factor Pass - Major Risk Rig: 1H -108 -IH -108-1H-108 125.11 239.74 125.11 237.50 125.00 106.918 Centre Distance Pass - Major Risk Rig: 1H -108 -IH -108-1H-108 425.10 241.16 425.10 233.83 425.00 32.919 Clearance Factor Pass - Major Risk Rig: 1H-108-iH-108A-1H-1GSA wp01 125.11 239.74 125.11 237.50 125.00 106.918 Centre Distance Pass - Major Risk Rig: 1H -108 -1H -108A -1H -108A wp01 425.10 241.16 425.1D 233.83 425.00 32.919 Clearance Factor Pass - Major Risk Rig: 1H-10B-iH-1GSA -1H-108A 125.11 239.74 125.11 237.39 125.00 101.720 Centre Distance Pass - Major Risk Rig: 1H-108-1H-108A-iH-108A 425.1D 241.16 425.10 233.72 425.00 32.412 Clearance Factor Pass - Major Risk 29 June, 2018 - 9:07 Page 3 of 6 COMPASS ConocoPhillips AnticolIision Report for Plan: 11-1-115 - 1 H-115wp22 Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 39.00 1,300.00 1 H-115wp22 GYD-GC-SS 1,300.00 1,825.00 1 H-115wp22 MWD 1,300.00 1,825.00 1 H-115wp22 MWD+IFR-AK-CAZ-SC 1,825.00 3,325.00 1H-115wp22 MWD 1,825.00 10,735.84 IH-115wp22 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie -on 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. ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit 29 June, 2018 - 9:07 Page 4 of 6 COMPASS 9:12, Jure 2920tH 1 H-115wp22 Ladder View 300 G 0 � I W m ,,150 — U � 0 � 0 l l 0 3000 4500 6000 7500 9000 10,, Measured Depth SURVEY PROGRAM A L Depth From Depth To Survey/Plan Tool TVD MD Name 39.00300.00 1H-115wp22(Plan:1HGYP-GC-SS 118.10118.10 20"x42" 1300.00825.00 1H-115wp22 (Plan: 1H-115) MWD 1780.11924.II53/4" x 13-1/2" 1300.00825.00 1H-115wp22(Plan:1HMV6P+IFR-AK-CAZ-SC 4269.8835.84 7"x8-3/4" 1825.006325.00 1H-115wp22 (Plan: IHMWP 1825.00735.84 1H-115wp22 (Plan: 1HMWffip+IFR-AK-CAZ-SC s z 60 0 m n 030 U 0 N Equivalent Magnetic Distance N U 0 0 300 600 900 1200 1500 Partial Measured Depth I= MO so M To Tool1825.00 39.06300.00 GYD-GC-SS 1300.00 1825.00 MWD 1300.00 1825.00 MWD.IFR-AK-CA7-SC 5.00 MWD ' .From 735.84 MWD+IFR-AK-CAZ-SC �eiynmtlmr_aR� TVD MD Name 18.10 118.10 2T :0 39 500 1 500-690 � 70 � � 6FI s � � • �� '•Iilinn • 1 1060 1060— 1240 �s`Yad s.�'.�•T'�1.4'�O :• �I � • 1 1 iMUWO sp i tiff �1 �� 1 ¢�O �'•il;rf p.a�, ere:. :1 1 •pp"P�l�d!�l�yd; 1 di'jV; • , RJ Irilicle 1 I�f �� ✓ �AIhg� ® 1 1 8510 9250 1 ..,�� 9250 9990 10731t rIM4,Fv9990 •! •`!f.' I! fii 111 `� {� }.10 1 . 1 Ii�W -IL :1 1 H-115wp22 39.00 To 10735.84 I oT Easting (1000 usftlin) ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-115 50029xxxxx00 Plan: 111-1-115 Plan: 1 H-115wp22 Error Ellipse Survey Report 29 June, 2018 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk I Pad Well: Plan: 1H-115 Wellbore: Plan: IH -115 Design: 1H-115WP22 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: Well Plan: 1H-115 TVD Reference: Plan: 54.1+39 @ 93.1 Oust: (Doyon 142) MD Reference: Plan: 54.1+39 @ 93, 10usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: OAKEDMP2 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 Kupamk 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: IH -115 MWD MWD -Standard Audit Notes: Well Position +N/S 0.00 usit Northing: Latitude: PLAN +E/ -W 0.00 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: 54.10 usft Wellbore Plan: 1H-115 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (') C) (nn BGGM2018 8/1/2018 17.06 80.91 57,449 Design IH-115wp22 Gyrodata gyro single shots MWD MWD -Standard Audit Notes: MWD+IFRAKCAZSCC MWD MWD -Standard Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (ND) +N/ -S +E/ -W Direction (usft) (usft) lush) (') 39.00 0.00 0.00 7300 Survey Tool Program Date 6/28/2018 From To (usft) (usft) Survey(Wellbone) 39.00 1,300.00 1H-115wp22 (Plan: 1H-115) 1,300.00 1,825.00 1H-115wp22(Plan: 1H-115) 1,300.00 1,825.00 1 H-115wp22 (Plan: 1H-115) 1,825.00 3,325.00 1H-115wp22(Plan: 1H-115) 1,825.00 10,735.84 1 H-115wp22 (Plan: IH -115) Tool Name Description GYD-GC-SS Gyrodata gyro single shots MWD MWD -Standard MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC MWD MWD -Standard MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 612912018 9: 11 22A Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well Plan: 1H-115 Project: Kuparuk River Unit ND Reference: Plan: 54.1+39 @ 93.1 Oust (Doyon 142) Site: Kuparuk 1H Pad MD Reference: Plan: 54.1+39 @ 93.1 Ousit (Doyon 142) Well: Plan: 1H-115 Norm Reference: True Wellbore: Plan: 11-1-115 Survey Calculation Method: Minimum Curvature Design: 1H-115wp22 Output errors are at 1.00 sigma Database: OAKEDMP2 Plan Survey Tool Program Data 6/28/2018 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.00 1,300.001H-115wp22(Plan: 11-1-115) GYD-GC-SS Gyrodata gyro single shots 2 1,300.00 1,825.001H-115wp22(Plan: 1 H-115) MWD MWD - Standard 3 1,300.00 1,825.001H-115wp22(Plan: 11-1-115) MWD+IFR-AK-CAZ-SC Inclination AaYnum Vedicel MWD+IFR AK CAZ SCC 4 1,825.00 3,325.00 1H-115wp22 (Plan: 11-1-115) MWD Semiamjar 8eml+ninor MWD - Standard 5 1,825.00 10,735.841H-115wp22(Plan: 11-1-115) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Position uncertainty and bias at survey station Measu Inclination AaYnum Vedicel HigBside LIMm1 Vertical Magnaum Semiamjar 8eml+ninor Minh Oeam Error ales Error BMs Error Bias Mei.. Error Emor ArimuN Tod (usft) (y (1) (usft) (usft) (usn) (usft) (usft) (usft) (usft) (usn) (usft) (usft) V) 3900 000 0.00 39.00 0.00 0.DD 000 000 000 000 0.00 0.00 0.00 0.00 UNDEFINED 100.00 0.00 000 100.00 004 000 004 0.00 1AS 000 000 0.04 0.04 0.00 GYD-GC S(1, 1) 20000 0.00 0.00 200.00 0.19 0.00 0.19 0.00 1.15 000 0.00 0.19 0.18 0.00 GYD-GC-SS(1, 1) 30000 0.0D 0.00 300.00 033 0.00 0.33 0.00 1.15 0.01 001 033 0.33 0.00 GYD-GG-63(1,1) 40000 0.00 0.00 400.00 048 0.00 0.48 0.00 1.15 0.01 0.01 0.48 0.40 0.00 GYD-GC-SS(1, 1) 500.00 000 0.00 50000 062 0.00 0.82 000 1.15 0.02 0.02 0.62 082 0.00 GYD-G0-SS(1. 1) 600.00 100 10500 599.99 013 0.00 013 0.00 1.15 003 003 0.73 013 45.00 GYD-GC-SS(1, 1) 700.00 200 10500 899,96 0.81 000 0.81 0.00 1.16 0.05 0.05 0.81 0.81 45.00 GYD-GCSS(1, 1) 80000 400 102.50 799.82 0.90 000 0.91 000 1.16 0.07 0.07 0.91 0.91 1458 GYD-GC-SS(1, 1) 900.00 509 10188 89843 1.01 -0.01 1.02 0.00 1.18 0,09 009 1.02 1.02 1341 GYD-GC4IS(1, 1) 1.000.00 7.99 10124 998.68 1.13 901 1.15 0.00 1.16 0.11 0.11 1.15 1.15 98.47 GYD-GO-6s n. 1) 1,00133 8.02 101,24 1.000.00 1.13 901 1.15 0.00 1.16 0.11 0.11 1.15 1.15 98.72 GYD-GC-SS(1, 1) 1,10000 1049 101.24 1,087.30 1.25 -0.01 1.29 0.00 1.16 0.13 0.14 1,29 1.28 10026 GYD-GC-SS(1. 1) 1.20000 12.99 10124 1,195.28 1.38 -0.02 1,44 O.00 1.16 0.16 0.16 144 1.42 10041 GYD-GC-SS(1. 1) 1,30000 1549 101.24 1,292.20 1.52 -0.03 182 000 116 0.19 0.19 1.62 1.56 100.53 GYD-GC-SS(1, 1) 1,400.00 1]99 101.24 1,307.96 1.50 -004 1.72 003 1.15 022 0.23 112 165 100.86 MM (1. 2) 150000 2049 101.24 1,48236 1.58 -0.05 1,87 0.09 1.15 0.26 0.28 1.87 187 10175 MM (1. 2) 1,600.00 2289 10124 1.575.25 1.60 -006 2.19 0.17 114 029 034 2.19 111 102.00 MWD (1, 2) 1,619.43 2347 10124 11593.10 1m -006 2.27 0.19 1.13 030 038 2.27 1.73 10202 MWD(1.2) 1,70000 2347 101.24 1,667.00 1.65 -000 261 0.26 1.15 0.33 0.42 2.64 117 102.04 MWD (1, 2) 1128.45 23.47 101.24 1,693.10 1.07 906 219 0.29 1.15 0.34 045 278 118 10204 MWD(1, 2) 1,800.00 25.55 99.95 1,758.20 111 -008 3.18 0.35 1.16 0.37 0.52 3.18 1.83 101.94 MM (1, 2) 1.82435 28.28 99.58 11780.10 1.73 -009 332 0.30 1.16 0.38 0.54 3.33 Ise 10189 MWD(1, 2) 1,84435 26.26 99.56 1,79804 163 -008 2.14 001 1.13 0.38 040 2.15 119 105.89 MWD(2.3) 1,90000 M.7r 99.56 1,047.39 1.61 .0.10 2.28 008 1.13 0.41 0.43 2.20 1.80 104.29 MM (2.3) 2.000.00 3327 9956 193307 1.60 -0.13 2.74 0.23 1.12 0.44 052 2.75 1.85 102.15 MM (2, 3) 2,100.00 3777 9956 2,014.44 1.61 .0.17 347 043 1.11 048 ON 347 1.91 101.13 AM (2. 3) 2,200.00 4227 98.56 2,091.01 1.65 -0.21 4.41 066 1.13 052 086 4.41 2.00 100.64 MM (2. 3) 2,300.00 46.77 9958 2,18229 1.74 -0.25 5.52 0.94 1.19 0.55 1.12 552 210 100.38 MM (2. 3) 2,400.00 51.27 9953 2,227.85 1.86 929 816 127 120 0.58 142 6.76 221 10023 MWD(2,3) 2,50000 5577 9956 2,287.30 2.02 -034 8.12 1.64 1.43 061 1.77 8.12 233 100.12 MWD(2,3) 6/29/2018 9:11:22AM Page 3 COMPASS 5000.14 Build 85 I Company: ConomPhillips (Alaska) Inc. -Kupl project: Kupamk River Unit Site: Kuparuk 1H Pad Well: Plan: 11-1-115 Wellbore: Plan: 1H-115 Design: 1H-115wp22 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1 H-115 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Measured Inclination Azimuth vertical Iighaide t4fit., V mcal W,hRude Semlmalor SemiminOr Depth Depth ERor Elae Ermr Blas Error Bias as. Ertor Ertor Arlhuth TOM (usft) 1°1 1'1 Iron) loan) hues loss (Daft) (usft) (Daft) (usft) Will (Deft) P) 2,600.00 60.2] 99.58 2,340.25 2.20 -0.38 9.57 2.05 1.63 0.64 2.17 9.57 2.44 100.04 MWD (2,3) 2.700.00 64.77 99.% 2,30640 2.61 -043 11.09 2.50 1.86 088 261 11.09 2.55 9998 mm (2. 3) 2,705.19 8500 99.55 2.388.60 2.42 -0,44 11.17 2.52 1.88 068 263 11.17 2.58 saw PAM (2, 3) 2,800.00 67.11 98.11 2427.09 269 -0.52 12.06 299 2.13 0.60 3.08 1259 2.65 99]5 MWD(2, 3) 2,900.00 8941 92.59 2.464.14 3.06 -0.61 13.97 349 242 0.69 3.56 14.08 234 99,17 MM (2, 3) 3.000.00 71.78 $9.17 2.497.37 3,32 -0]0 15.35 3.98 213 0.71 4.04 15.55 283 98.35 MM (2,3) 3,100.00 74.21 95.85 2,526.61 383 -077 16.72 4.46 305 On 4.53 17.05 2.92 97.34 MWD(2.3) 3,200.00 7889 82.60 2,551]4 392 -am 18.05 4.94 3.38 073 5.02 18.55 300 98.21 MWD(2.3) 3,300.00 79.21 79.43 2.572.62 4.19 -0.87 19.34 5.40 3.72 0.74 550 20.05 3.09 94.98 MWD(2, 3) 3,347.19 8041 77.95 2,58097 2.33 -063 7.68 0.19 2.08 0,74 0.99 806 244 96.36 MWD+IFR-AK-CA-SC(3,3) 3,400.00 80.41 77.95 2,589.77 2.41 -0.63 796 019 217 0.75 1.00 8.32 2.46 9587 1JWD+1FA-AK-CP-SO(3,3) 3,50000 8041 77.95 2.606.43 2.58 -0.63 8.51 0.19 233 0.76 1.03 884 2.49 9445 MWD+IFR-AKCA-SC(3,3) 3,600.00 80.41 77.95 2,623.09 274 -0.63 906 0.19 2.50 D.76 1.07 9.37 2.52 9338 MWDAFR-AKCA-SC(3,3) 3,700.00 80.41 77.95 2,639.75 2.90 -em 962 0.19 2.88 077 1.10 9.91 2.55 9243 MWD+IFR-AKCA-SC(3.3) 3,80000 6041 77.95 2,656.41 3.07 -0.63 10.18 0.19 283 Us 1.13 1045 257 91.58 MWD+1FR-AK-CA-W(3,3) 3,90000 8041 77.95 2163.07 3.24 -063 10.74 0.19 3.00 O.78 1.17 11.00 260 90.82 MWD+IFRAK-CA-SC(3,3) 4,000.00 80.41 77.95 2.689.74 3.41 -063 11.31 0.19 3.17 0,79 120 11.56 2.63 90.14 MWD+1FR-N(-QA -5C(3, 3) 4,10000 80.41 77.95 2,70640 3.50 -0.63 11.88 0.19 334 0.60 1.24 12.11 2.85 $9.52 MWD+IFR-AK-CAZSC(3, 3) 4.200.00 8041 77,95 2,72308 3.75 7763 1245 0.19 3.51 0.81 1.28 1267 268 88.96 MWD+IFR-N(-CA -SC (3, 3) 4,30000 80.41 77.95 2.739.72 392 -0.63 13.02 0.19 3.00 081 132 13.24 271 $845 MWD+1FRAK-CPSC(3,3) 4,400.00 80.41 7795 2,756.38 4,09 -am 13.60 0.19 3.05 0.82 1.36 13.80 2.73 87.99 MWD4IFR-MKC -SC (3,3) 4.500.00 80.41 77.95 2.773.04 4.27 -063 14.17 0.19 4.02 0.83 1.40 14.37 2.76 87.57 MWD+1FR-AKCA2.80(3.3) 4,800.00 80.41 77,95 2.789.70 4.44 -Oso U.76 0.19 420 084 1.44 14.94 2.78 87.17 MWD+IFRAKCAZSO(3.3) 4,700.00 8041 77.95 2.806.36 4.61 -0.63 15.33 0.19 4.37 084 148 1551 281 88.81 MIND+IFR-AK-CA.SC(3,3) 4,800.00 80.41 77.95 2,82302 4.79 -0.63 1591 019 454 0.85 1.52 16.08 2.83 88.48 MWD+1FR-AK-CA-W(3,3) 4,900.00 80.41 77.95 2.83968 4.96 -0.63 16.49 0.19 4.71 0.08 1.58 16.65 2.85 86.17 MWD+IFR-AK-CA-SC(3, 3) 5,000.00 00.41 77.95 2,856.34 5.13 4,63 1707 0.19 489 087 1.61 17.23 2.09 85.88 MWDHFR-N(-CA -SC (3. 3) 5,100.00 00.41 77.95 2,873.00 5.31 -0.63 17,65 0.19 5.08 087 185 17.80 291 8562 MWD+IFRAK-CP-$C(3, 3) 5,200.00 80.41 77.95 2.88967 548 -0.63 18.23 D.19 5.23 0.88 1.70 1838 294 85.37 MWD+IFR-AK-CA-SC(3,3) 5.300.00 8041 77.95 2,906.33 Sea -0.63 18.81 0.19 5.41 089 174 18.96 2.96 85.13 MWD+IFR-AK-CMSO(3.3) 5,600.00 8041 77.95 2.922.99 5.83 -0,63 19.40 DAD 558 090 i79 1954 2.99 84.91 MW041FR-AK-CASC(3, 3) 5,500.00 90.41 77.95 2,93965 801 -063 19.98 0.19 5.75 0.91 1.83 20.12 302 84.71 MWD+IFR-AK-CA-SC(3,3) 5.80000 80.41 77.95 2,956.31 6.18 463 2058 0.19 593 0.92 1.88 20.70 3.04 04.51 MWD+1FR-AK-CA.80(3,3) 5,70000 DOM 77.95 2.97297 6.36 -0.63 21.15 0.19 6.10 092 1.93 2128 3.07 84.33 MVJD4IFR-AK-CA-SC(3, 3) 5,800.00 8041 77.95 2,98983 853 4),63 21.73 0.19 6.28 0.93 1.98 21.88 3.10 84.16 MWD+1FR-AK.CM-SC(3, 3) 5,900.00 80.41 77.95 3,00629 6.71 -0.63 22.32 019 845 094 2.03 22.44 3.12 8399 MWD+1FR-AK.CM-SC(3, 3) 6,000.97 811.41 77.95 3.022.95 6.89 -O63 Mao 0.19 862 0.95 2.08 2302 315 8384 MWDHFR-AK-CA-S (3, 3) 6,100.110 WA1 77.95 3,03861 7.06 -083 23.49 0.19 6sD 0.96 2.13 23.60 3.18 8369 MWD+IFR-AK-CA -SC (3, 3) 6,200.00 8(141 77.95 3,058.27 7.24 -O.63 24.07 0.19 897 097 2.18 24.18 321 83.55 MWMIFR-AK-CPZ-$C(3. 3) 6,300.00 8041 7795 3,072.93 742 -063 24.66 0.19 7.15 0.90 2.23 24.77 3.23 0342 MWLAIFR-AR-CMSC(3,3) 6400.00 8041 77.95 3,089.60 7.59 -063 2524 0.19 732 0.99 2.28 25.35 3.26 8329 MWD+IFR-AK-CPZ C(3,3) 6,50000 80.41 77,95 3.106.26 7.77 -063 2583 0.19 7.50 1.00 2.33 2593 329 83.17 MWD+IFR-MKC -SC (3,3) 61600.00 9041 77.95 3,122.92 7.94 463 2841 0.19 7.67 1.00 2.30 26.52 3.32 83.06 MWD+1FR-AKCM2 C(3,3) 070000 8041 77.95 3.139.58 8.12 -D.63 27.00 0.19 ]a5 101 244 27.10 3.34 62.95 MWO+IFR-A-SC (3.3) 6800.00 8041 7795 3,15524 830 -063 27.59 0.19 8.02 1.02 249 27.69 3.37 82.84 MWD+1FR-AK-CA-SC(3,3) 6,900.00 00.41 77.95 3.17290 8.47 -O.0 28.17 0.19 820 1.03 2.55 2827 3.40 8274 1AW0+1FR-AK-CA-SC(3.3) 7.000:00 80.41 77,95 3,189,55 1185 -063 28.76 0.19 0.37 1.04 260 2888 343 8265 MWD+1FR-AK-CA-SC(3, 3) 7,100.00 80.41 77.95 3,206.22 SM -0.63 2935 0.19 8.54 1.05 2.66 29.44 3.46 8256 MWD+1FR-AKCALSC(3,3) 7,20000 0041 77.95 3.222.80 9.00 -063 29.94 0.19 872 1.08 271 30.03 349 82.47 MWDHFR-AK-CA-SC(3. 3) 7,30000 80.41 77,95 3,239.% 9.18 -063 30.52 0.19 8.89 1.6 217 30.61 352 82.38 MWD+1FRAK-CA-S0 (3,3) 7,60000 8041 77.95 3,256.20 9.98 -083 31.11 0.19 9.97 1m 2.82 31.20 3.54 82.30~+ IFR-AKCA-SC(3,3) 7,50000 80.41 77.95 3,27286 9.54 -0.63 31.70 0.19 924 1.09 2s8 31.79 3.57 82.22 MM+IFR-AK-CA-SC(3, 3) 7.600.00 8041 77.95 3,289.53 971 4.63 32.29 0.19 9.42 1.10 2.94 32.37 3.60 82.15 MW IFR-AK-CMSC(3, 3) 7,700.00 8041 77.95 3306.19 9.89 -0.63 32.87 0.19 9.59 1.11 300 32.96 3.63 82.07 MWO+IFR-AK-CA-$013,3) 6292018 9: 11: 22AM Page 4 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Plan: 1H-115 Wellbore: Plan: 1H-115 Design: 1H-115wp22 Position uncertainty and blas at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output emors are at Database: Well Plan: IH -115 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Measured IMOnatim ANmulh VMioal Righside lateral -hitimiss target Dip Angle Vedical Ma9ndudo Semimajer Semlmirer Depth 1 H-115 T01 062818 RP 0,00 0.00 D PO Error Bus Enor alas Ertor Bias of Bias Ertor Error A Mh Tool (usn) (It V) (uss) (pan) (uaft) iusn) lush) lust) (Iran) (usn) (ush) (-M P) 7.800.00 90.41 77,95 3,322.85 10.07 -0.63 33.46 0.19 977 1.12 306 33.56 3E6 8200.MWD+IFR-AK-CAZ-GC(3,3) 7,90000 80.41 77.95 3,33951 10.24 41.63 34.05 0.19 994 1.13 3.12 34.13 3.69 81.94 IMD+IFR-AK-CA-SC(3,3) 8,00000 8041 77.95 3,358.9 1042 4,63 34.64 0.19 10.12 1.14 3.18 3472 372 81,07 MWD+IFR-AK-CA -SC (3. 3) 8,100.00 80.41 7195 3.372.03 1060 -0.63 3523 0.19 1029 1.15 3.24 3530 3.75 81.81 MWD+IFR-AK-CA-SC (3.3) 8.200.00 80.41 7795 3,388.49 10.78 -0.63 35.81 0.19 10,47 1.16 3.30 35.89 378 81.75 MWD+IFR-AK-CA -SC (3,3) 8,300.00 8041 77.95 3,406.15 10.95 483 38.40 0.19 10.64 1.17 3.30 38.40 381 0169 MWD+IFR-AK-CAZSC(3, 3) 8,400.00 80.41 77.95 3.422.81 11.13 4).63 36.99 0.19 10.02 1.18 342 37.07 3.84 8163 NIM+IFR-AKAAZ-SC(3, 3) 8150000 80.41 77.95 3,439.47 1131 463 37.58 0.19 10.99 1.19 348 3165 387 81.57 MWDNFR-AKCAZ-SC(3,3) 8,800.00 8041 77.95 3,456.13 1149 -083 38.17 0.19 11.17 120 355 38.24 3.90 81.52 h1WD+IFR-AK-0A2-W(3,3) 0,700.00 8041 7195 3,472.79 11.65 463 3878 0.19 1135 121 3 I 3883 3.93 81.47 MWD+1FR-AK-CAZ-W(3,3) 8,000.00 8041 77.95 348846 11.84 -0.63 39.30 0.19 11.52 1.22 367 39.42 3.96 81.42 MWD+IFR-AK-CP-SG(3,3) 9,90000 80.41 77.95 3,506.12 12.02 -083 39.93 0.19 11.70 1.24 374 4000 399 01.37 MWWIFR-AK-OAZ-SC(3,3) 8,954.25 90.41 77.95 3,515.16 12.11 -0.63 4025 019 11.79 1.24 3.77 40.32 401 Bt35 MWD+1FR-AK-CAZ-SC(3, 3) 9,000.00 79.26 76.50 3.52323 1224 5.56 40.42 028 1187 1.25 3.80 40.56 002 81.32 MWD+IFR-AK-CA-SC(3,3) 9110000 76.T 73.30 3,544.00 1253 -040 4062 0.48 12.04 1.26 3.87 41.01 4.08 8128 MWD+IFR-AK-CA-W(3,3) 9,200.00 74.32 7003 3.560.97 12.07 -024 4087 069 12.21 1.28 395 41.45 4.09 81.16 MWD+1FR-AK-CA-SC(3.3) 9.30000 71A2 88,89 3,598.01 13.30 -0.09 40.58 0.91 12.38 1.30 4.03 41.87 4.13 81.04 MWD+IFR-AK-CAZ-SC(3,3) 940000 69.50 63.25 3,630.99 1384 005 40.31 1.13 12.55 1.33 4.11 42.27 4.18 Was MWD+IFR-AK-CP-SG (3,3) 9,500.00 67.31 59.71 3,667.73 14.53 0.18 3985 136 12.71 1.37 4.2D 42.66 4.24 80.71 MWD+IFR-AK-CA -$C (3, 3) 9,80000 65.12 56.05 3,70808 15.40 0.29 39.19 1.60 12.86 1.41 4.30 43.01 4.31 W52 MWD+IFR-N(-CA -SC (3, 3) 9,700.00 83.02 52.27 3,751.82 1644 039 3831 1,84 1301 1.45 4.39 43.35 4.39 80.31 MWD+1FR-AR-CAZ-SC(3,3) 9.800.00 61.03 49.34 3,788.74 1167 046 37.19 2.10 1316 151 4,49 4365 4.50 8008 MWDAFR-AR-CAZ-SC(3,3) 9.855.46 5997 48.10 382808 18.42 049 36.46 2.24 1324 1.54 4.54 43.80 4.56 79.95 MWDNFR-MC -SC (3,3) 9,900.00 5897 46.10 3.8,18.34 1848 049 38.64 2.24 13.30 1.56 4.59 4395 4.59 7883 MMAFR-AK-0.4-50(3.3) 9,955./6 Saar 48.10 3,876.10 19.55 0.49 38.89 2.24 13.38 160 465 44.16 462 79.65 MWD+1FR-AK-CA-SC (3.3) 10,07000 59.97 46.10 3,89839 18.61 049 3109 224 13.44 1.62 4.69 44.33 4.65 7951 MWD+IFR-AK-0A-50(3,3) 10,100.00 59.97 48.10 3,94843 1873 0.49 37.55 224 13.58 168 479 4472 470 7920 MWD+IFR-AK-CAZSC(3, 3) 10,20000 59.97 46.10 3,990.48 18.86 049 3801 224 13]2 1.74 4.90 45.11 4.77 7889 MWWIFR-AK-CAZSC(3,3) 10,215.23 59.97 48.10 4,OD6.10 18.00 049 3808 224 1374 1.75 4.92 45.17 478 78.05 MW IFR-AK-CAZSC(3,3) 10,259]3 60.08 4809 4,028.33 18.91 048 38.28 224 13.81 178 496 45.35 4.81 78,71 MM+IFR-N(-CAZ-SC(3,3) 10,30000 60.08 46.09 4,001.42 1897 048 3847 2.24 13.86 1.00 5.01 45.51 4.83 70.59 MWD+IFR-MK- -SC (3.3) 10.4011.00 60.08 48.09 4,098.29 19.09 048 38.93 224 14.01 1.06 5.12 45.90 4.90 78.29 MWD+1FR-AK-CAZ-SC(3,3) 10500.00 60.00 '16.09 4,149.17 1922 0.48 39.40 2.24 14.15 1.92 523 46.30 4.98 77.99 MWD+1FR-AK-CAZ-W(3,3) 10,60o00 60.00 46.09 4.19805 AM 048 3887 224 14.29 1.98 5.34 4870 508 77]0 MWD+IFR-AK-GP-SC (3,3) 10,70000 MOB 4809 4,247.92 19.48 048 4033 224 14.43 205 5.45 47.11 5.14 77.41 MWD+IFR-AK-CAZ-SC(3,3) 10,735.84 60.08 46.09 4,265.80 19.53 0.48 4050 2.24 1448 207 549 47.25 5.17 77.31 UNDEFINED Design Targets Target Name -hitimiss target Dip Angle Dip Dir. TVD -Shape (9 (1) lush) 1 H-115 T01 062818 RP 0,00 0.00 3,876.10 - plan hits target center - Circle (radius 100.00) 1 H-115 T02 062818 RP 0.00 0.00 4,0013.10 - plan hits target center - Circle (radius 100.00) iH-115 T03 062818 RP 0.00 0.00 4,265.80 - plan hits target center - Circle (radius 100.00) 6292018 9: 11: 22AM Page 5 COMPASS 6000 14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kupawk River Unit Site: Kuparuk 1H Pad Well: Plan: 114-115 Wellbore: Plan: 1H-115 Design: 1H-115wp22 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-115 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Casing Points Vertical Dip Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name Base Pfrost (usft) 118.10 118.10 20"x42" 20 42 1,824.35 1,780.10 10-3/4" x 13-1/2" 10-3/4 13-1/2 10,735.84 4,265.80 7" x 8-3/4" 7 B-3/4 Formations Measured Vertical Dip Depth Depth Vertical Dip Direction (usft) (usft) Name Lithology (1) ( ) 1,673.94 1,643.10 Base Pfrost (usft) 1,863.45 1,815.10 T-3 500.00 2,149.67 2,053.10 K-15 Start Build 1.00 6,361.02 3,083.10 UG -C 0.00 8,041.60 3,363.10 UG -B 0.00 8,785.87 3,487.10 UG -A 0.00 9,571.20 3,696.10 Na 0.00 9,955.46 3,876.10 WS -D 0.00 10,065.36 3,931.10 WS_C 0.00 10,101.33 3,949.10 WS_B 0.00 10,179.26 3,988.10 WS A4 0.00 10,239.23 4,018.10 WS -A3 0.00 10,409.64 4,103.10 WS -A2 0.00 10,590.08 4,193.10 WS -Al 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 500.00 500.00 0.00 0.00 Start Build 1.00 700.00 699.96 -0.90 3.37 Start DLS 2.00 TFO -5.00 1,001.33 1,000.00 -6.37 29.09 Start Build 2.50 1,619.43 1,593.10 -38.96 193.13 Start 109.02 hold at 1619.43 MD 1,728.45 1,693.10 -47.43 235.72 Start DLS 3.00 TFO -15.00 1,824.35 1,780.10 -54.68 275.38 Start 20.00 hold at 1824.35 MD 1,844.35 1,798.04 -56.15 284.11 Start Build 4.50 2,705.19 2,388.60 -156.39 879.45 Start DLS 4.00 TFO -56.94 3,347.19 2,580.97 -138.29 1,486.06 Start 5607.07 hold at 3347.19 MD 8,954.25 3,515.16 1,016.34 6,892.84 Start DLS 4.00 TFO-129.07 9,855.46 3,826.06 1,392.13 7,633.02 Start 100.00 hold at 9855.46 MD 9,955.46 3,876.10 1,452.17 7,695.39 Start 259.77 hold at 9955.46 MD 10,215.23 4,006.10 1,608.12 7,857.44 Start DLS 0.25 TFO-1.05 10,259.73 4,028.33 1,634.85 7,885.21 Start 476.11 hold at 10259.73 MD 10,735.84 4,265.80 1,921.02 8,182.53 TD at 10735.84 Checked By: Approved By: Date: 6292018 9:11:22AM Page 6 COMPASS 5000.14 Build 85 Pool Report 0 0 O Vi O Ln O ^yam Q �¢p C) a�i36 . __._ ........ �........ O ��$ O 0) o 00 3 9A°O O VV Ln II p�O Stix 1H1108A �!f0G _ h N.11O H -111 O 900 A,O 800 O O _--.. ........ CD 9 000° 1200 00 (O goo 000 J n!� N ' gOO b N lEOJ� = H I o O O O ar o M n 0 O Ln 000 m 0 0 008E 6 900 PC ° -� ai a oo M Ln C ^3 O O Ln L p�M r V R 0 0 0 0 0 0 0 LO 0 0 O Ln 0 Ln 0 o �!/pn ooST) (+)4laoN/(-)u]noS T ch 9:39, JUne 29 2016 1 H-115wp22 QuarterMile View MIR 3 E TARGET DETAILS 111 ND K 115701062018 RP 3BM.10 ;H 1H�115 702062618 RP 9406.10 IH-115 TO 062818 RP 426580 (MAP COORDINATES) W.00) Ud.lR..' .1320.00) Lvtle �flal'WS', I]200R) C.d. (RMIUA 1320.00) All Wells IH 2O 14.1 02L2 A H 1q .1H--1102L1, 4500 1H-118 4000 IH-16 3900 3800 9, g m 1N.10 Op 19 IH 7 00 —q N000 4i . 0. 800 _ _ > 44200 100 800... 1H-114 4000 40004100 3888 0 a0 4000 ^ „ P ^o 1 3 3800 i y Lo J 500 g �� 'r IH-1�0._... _ 4000 7% } -19AL2 6 X94 j70 0000 00 00000 Bp00 40-109 z800 00 N `y z O O O I 3000 aeo0 3800 (n 0b 0000000 > > O10 -1500 90, Mflso o _o o $ Oo $o�QD bb� oo� ® 2153 -3000 tg011u D VY O ♦�'�^ w 0 1500 3000 4500 6000 7500 9000 10500 12000 X000 �gg4100 *00 Z3 385 O J 500- + 00 ± O z 0 r' E Op -1500 r 40 01 p -p -30 WELLBORE TARGET DETAILS MAP Cq ORMNATES) Name ND She IH-0STO1 082818 RP 3078.10 CIM(Red :1320,0) IH-115TW 002818 RP 4008.10 Cide MWa :1320.00) IH -115T03 W2018 RP 428580 C de lRe :1320,0) All Wells - QM iH-102L2 f 1 � Otis ^� w 1H-102L7,>� •� ry p ^'! 900 Z i 4000 c iOp o0 00 Op O 6'3 3900 3800 wow. opo - 3900 00000 ? oFr'+1 8000 p0000 �Z 0800 3800 3, 1H r rol �oo oo.- 110 110 M00�NS Y 'ISS r'1M RCR�- y0 OO pO Op O D hment CIC-15VC-As? j10-153 _.r.i50 \ 1500 3000 4500 6000 7500 9000 10500 12000 1H-118 4000 3900 400019 3800 /900 3800 1H-114 4100 4000 3900 11{_1 asoo 94 'PSOpo " 134000 Opp% 900 3800 1H-109 4000 )SAP 800 3900 900 Z i 4000 c iOp o0 00 Op O 6'3 3900 3800 wow. opo - 3900 00000 ? oFr'+1 8000 p0000 �Z 0800 3800 3, 1H r rol �oo oo.- 110 110 M00�NS Y 'ISS r'1M RCR�- y0 OO pO Op O D hment CIC-15VC-As? j10-153 _.r.i50 \ 1500 3000 4500 6000 7500 9000 10500 12000 I �. I ,i, 1H-115wp22 Surface Location n. CPAS Coordinate Con. wtzr :-- l —" E I 1 From: ----- Datum: NAD83 Region: alaska f' Latitude/Longitude Decimal Degrees r UTM Zonal— r– South 6 State Plane Zonal" J Units: us7ft t" Legal Description (NAD27 only) Starting Coordinates: X 1669585.05 Y: 5980743.49 To Datum: iAp27 Region: alaska C' Latitude/Longitude IDecimalDegiees * UTM Zone: True r South C•' Stale Plane Zane: IQ units: usfl (i r Legal Description (NAD27 only) Ending Coordinates: ---- X Y: ........................................................... Transform 1H-115wp22 Surface Location 549553.428073663 598899167622377 Quit I Help M CPASCoordinate Ccn.tr.er 66. � = I'c I From: -- :-To:--- Datum: INAD83 Region: lalaska r Latitude/Longitude jDecimalDegiees, * UTM Zone: I — r- South j G State Plane Zone:Units: usft C- L' II`�jYtl J Datum NAD27 Rection: alaska . r Latitude/Longitude IDecimalDegrees T UTM Zone True r– South T State Plane Zone: F4 ----- Units: r Legal Description (NAD27 only) Starting Coordinates:--, 689585.05 -Legal X. Y: 5980743.49 I Description— Township: 012 I"J Rangy 010 FE Meridian: Section:2o FNL 4991.1885 FEL . 705.76969 11 Transform _ Quit Help 1H-115wp22 Surface Casing Q CPA° Coordinate Cen:erter ML 1, 12 1sr�+s7 From: ------- Datum: NAD83 Region: alaska . C Latitude/Longitude jDacimalDegreas C' UTM Zone: r— r South (•' State Plane Zane: F-7-:1 Units: us -ft !' Legal Descdplicn (NAD27 only) To: Datum: NAD27 Region: alaska + (' Latitude/Longitude IDecimalDegrees f UTM Zone: True r South r State Plane Zone: F --J] Units: us -ft r Legal Description (NAD27 ordy) r Staling Coordinates: - Ending Coordnates: - - X: 1689860.76 X: 549829.13355178 Y: 5980650.63 Y: 5980938.8122525 _-.-_.Transform .................: Quit J Help 1H-115wp22 Surface Casing ®. CPA[ Coordinate Converter From: - - --..- Datum: NAD83 Region: alaska !' Latitude/Longitude IDecimal Degrees i r UTM Zone: F— r South ¢" State Plane Zone: Units: us$ T o: Datum: NA027 Region: alaska f Latitude/Longitude Decimal Degrees r UTM Zone: True r South r State Plane Zone: F--':-] Units: us{t + G Legal Descripticn(NAD27 only) Starting Coordinates:--- -- i- Legal Description - X: 1689860.76 Township: 012 Range: 010 Y: 5980690.63 �� Meridian: I" _1 Section:20 FL• 5045.8852 FEL 510.52020 �ansform,. ,� Quit Hell 1H-115wp22 Production Horizon From: - -. Datum: INAD83 Region alaska . 0 LatitudeAongitude IDecimalDegrees, C UTM Zone: r South r State Plane Zone: I4J Units: w tt C Legal Description (NAD27 only) X: 1697270.00 Y. 5982246.00 To Datum: NADP? Region. alaska . C Latitude/Longitude IDecimalDegrees C UTM Zone: True r South fi State Plane Zone: I4 J Units: us[t C Legal Description (NAD27 only) Ending Coordinates: - - X: 557238.273263082 Y: F5982494.00486596 L- .Translorm Quit I Help 1 H-115wp22 Production Horizon M CPA[ Coordinate Converter From -__ -_ To: Datum: NAD83] Region: alaska Datum NAD27 Region: alaska !. C Latitude/Longitude IDecirnal Degrees C Latitude/Longitude jDacimal Degrees C UTM Zone: f— r South C UTM Zone: True r South Stale Plane Zone: r4--_-3Urals: us Ft r' Slate Plane Zone:f q -3 Units: us.[t C Lei.i Legal Description(NAD27 only) i I r Starting Coordinates:------ - -- - - Legal Description- - i x: x16997270-00 1 Township: 012 fN--,] Range: 010 E I Y: 5902246.00 Mer 2F364-7 FNLrd�-n 354 FEL�in: .2020 Quit Help 1 H-115wp22 TD M CPAICoordinate Ccnve I o a From: _. _. To: Datum: [NA -D83 Region: alaska Datum NAD27 Region: alaska r Latitude/Longitude IDecirnalDegfees t Latitude/Longitude JDecimaIDegfees r UTM Zone: r— r South f UTM Zone: True r South f: State Plane Zone: rq -D- Units: us.R . R State Plane Zone:lq � Units: u, -Ft i f Legal Description (NAD27 only) i C' Legal Description (NAD27 only) Starting Coordinates: ----- Erding Coordinates:-- -------------, X: 1697754.00 X: 557722.26962649 Y: 5982718.00 Y: 5982965.98440029 i ( ...............Transform.......,.,_,....., 4ui1 Help 1 H-115wp22 TD M CPAI From:. Datum: NAD83 Region: alaska f LatitudelLongitude IDecimaiDegrees —� C UTM Zone: r- r South f: Stale Plane Zone. i" J Units: us -ft . Starting Coordinates:-- X Pi Tc. Datum:NAD27 Region: alaska C Latitude/Longitude IDecimalDegmes f UTM Zane: True r South f•State Plane Zane: 14 j Units: uslt G Legal Description (NAD27 only) Legal Description._ 169775400 Township: 012 I"-1 Range. 010 5982718.00 --__J Meridian Sedion:�— FNL 3075.2642 FF --J 3159.0025 Qul Help Translorm p Tollerable Collision Risk Worksheet As -built DS1H •UGNU 01 •14 •5 ZEVI DATE IBYJ CK IAPPI DESCRIPTION IREVI DATE I Y I CKAPP •11 1 2/05/0 MRT I CC I Rev. Per K05014ACS 2 02/01/1A JAH I LGM •6 N •21 25 30 29 •1 •9 •2 1G •3 •18 36 31 CS 32 T11r 6 5 0120 1A ASP GRID NORTH 0119 12 0118 8 0117 Ir 0116 01159 7 0114 0113 LEGEND 0112 it 0 AS—BUILT CONDUCTOR 0111 za 19 20 0110 V • EXISTING CONDUCTOR 0109 SCALE: 0104 0108 0103 alvi 0102 0106 0101 DS1H •UGNU 01 •4 SEE SHEET 2 & 3 FOR COORDINATE TABLE AREA: IH Rev. Per K170005ACS 10 � 4'O 16 75 14 i �e 1D 2 21 2 23 1" = 2 MILES I 28 127 33 34 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 L16-35, L16-40, L17-02 & L17-03. 6. ALL DISTANCES SHOWN ARE GROUND. GRAPHIC SCALE 0 100 200 400 1 inch = 200 ft. LOUNSBURY & PMOCU7W. INC. SURVEYORS ENGINEERS PUNNERS ConocoPhilli„S DS1H M WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FILE N0. I DRAWING N0.PART: REV: LK6108d31 2/05/05 CEA—D1HX-6108D31 1 of 3 2 •14 •5 •20 •12 •19 •11 •22 •10 •17 •6 •16 •21 e15 •13 •1 •9 •2 •7 •3 •18 •8 •4 SEE SHEET 2 & 3 FOR COORDINATE TABLE AREA: IH Rev. Per K170005ACS 10 � 4'O 16 75 14 i �e 1D 2 21 2 23 1" = 2 MILES I 28 127 33 34 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 L16-35, L16-40, L17-02 & L17-03. 6. ALL DISTANCES SHOWN ARE GROUND. GRAPHIC SCALE 0 100 200 400 1 inch = 200 ft. LOUNSBURY & PMOCU7W. INC. SURVEYORS ENGINEERS PUNNERS ConocoPhilli„S DS1H M WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FILE N0. I DRAWING N0.PART: REV: LK6108d31 2/05/05 CEA—D1HX-6108D31 1 of 3 2 11 102/01/11 JAH I LGM I (Create Per K170005ACS I I I I I I I C CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28, T. 12 N., R. 10 E., UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geociraphic 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" 438' 795' 48.0' 54.1' * CONDUCTOR ASBUILT THIS SURVEY 0 ♦♦ SURVEYOR'S CERTIFICATE 49th W% I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND ,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,� LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY """"""""""""" "'0DONE BY ME OR UNDER MY DIRECT SUPERVISION AND -MIAH F. CORNELJ &I THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION LS -12663 I. 1W 4w ARE CORRECT AS OF JANUARY 31, 2017. a"••".��.� Il LOUNSBURY �FfSSIONA�- /I\I B ASSOCIATES, INC. `�� sUB DRS BNGINRRR9 PL,NNBRA ConocoPhillips Alaska. Inc. /:�N7/:lfiil DS1H WELL CONDUCTOR uAuu riL IYu. UNANNU NU. LK6108d31 12/27/16 CEA-DIHX-6108D31 PART., OF 3 REV 1 QA.L,99Zi7GW 9EL`Oi @ dX.L/£99(lAH `08-'I `#9Z ..L OW ,OSSO1 - ,99Z01 :SuoilelolJad PUBS £V OW ,SZZO1 -,68101 :SuoileJolJad PUBS 17V ❑W ,65101 -,11101 :suoileloPed PUBS „8„ aW ,99001 - ,5966 :SuogeJoPad PUBS 01;ewaL108 aaogllaM Old u61SOO IIaM a0400(ul 56 6 -HL aogsolnw uon gwnt) Sssy iou5uyWndeio8 AIM ia3leg _ DW7nl lamoll ()"IN ioddll alddiN X oo-3 „£18Z laipueW a`dnuo dojG alPmS QW. ,O"Z", L# 10310M g8nonl.L Paad ow W iam0 -1 HW W 'adds lwpueW aJnerJ d.KG g1nW G �bG[`OI :Z#�a>toed 4 8nonl,l, Paad AOS gl!m OWW QW ,058`6 V,000`£ � s2B.L dldN-d aw 8 va,I £99GAH MIN iamol HW W iaddn — lajpueW a8nuo dolQ g1nW QW .080`01 :£# JWtOvd g8nonll Paad OWN lamo-1 9 rJWW iaddn alddlN SCI o -uD..ZI8'Z lajp=W aBnuD dojG lllnW 8ulgn,L,.Z/1-£ x „Z/1 -y : Hl moloq IOAOSS01D W5 `W.L91 1.5/rb X „8/£-£1 as{L / ja8uuH tulgnl / pgagllaM 4W .Sb66 :b# 1013ed g5nonly Paad £95 P,(H `08-I `# Z'6 `nZ/I-£ 3ulSeO „OZ aolonpuoD palelnsul a ►0 u 0 a V C A r I0IW 13N1b' :AE NIMV' Cl H GIIS HIM Remark: AOGCC PTD No. 218-053 - Coordinate Check 2 July 2018 INPUT Geographic, NAD27 OUTPUT State Plane, NAD27 5004 -Alaska 4. U.S. Feet KRU IH -115 1/1 Latitude: 70 21 31.8702 Northing/Y; 5980991.857 Longitude: 149 35 51.0786 Easting/X: 549552.848 Convergence: 0 22 44.62034 Scale Factor: 0.999902789 Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Development V/ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: la "-POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50 - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 davs after com letion, sus ension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 _ _ - Well Name: KUPARU_K RIV U WSAK 1H-1.15 Program SER _.. - Well bore seg ❑ PTD#: 2180530 Company GONOCOPHILLIPS ALASKA,Imo_ _ Initial Class/Type SER, /WA JIN GeoArea $80_ - Unit 11160 On/Off Shore On.- Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31 05. 030(11 A) (t.2 A -D) NA Appr SFD 1 2 3 4 5 6 7 8 9 10 Date 11 7/2/2018 12 13 14 15 16 18 Engineering 19 20 21 22 23 24 25 Appr Date MGR 7/2/2018 Geology 36 Appr Date 37 SFD 7/2/2018 38 M Permit. fee attached ... . - .. - NA Lease number appropriate - - _ - - - - .. - _ _ Yes Surface Location lies within ADL0025639; Top Prod Int & TO lie within ADL0025638. _ Unique well name and number _ - _ _ - _ - - - - _ Yes Well located in a. defined -pool - - - ...... - - - - Yes Kuparuk River. West. Sak Oil Pool - 490150, governed by CO 406G - Well located proper distance from drilling unit boundary... Yes .... CO 406C, Rule 3: no restrictions as to well spacing except that no pay shall be opened in a. well closer Well located proper distance from other wells. - - - - - - - - ... Yes - - - than 500 feet to. an external. property line where ownership or landownership changes... - - - - Sufficient acreage available in drilling unit, _ - _ _ _ _ _ _ - Yes Well is more than 500 feet from an external property line. - - If deviated, is wellbore plat. included .... - - .... - - .... - Yes Operator only affected party. - - - - - - ..... Yes Operator has appropriate bond in force - ... - - _ - _ _ _ _ _ Yes - - - - - Permit can be issued without conservation order- - - _ - _ _ Yes - - ... - - ... . . . . ....... - Permit can be issued without adminislrative.approval - ... - Yes Can permit be approved before 15 -day wait- _ - _ - - - ..... - Yes .. Well located within area and. strata authorized by Injection Order # (put 10# in comments). (For. Yes .. - - Area Injection.Order No.. 2B _ _ _ _ _ _ _ _ _ _ _ _ ..... - - _ _ . _ - _ _ _ . All wells.within 1/4 mile area -of review identified (For service well only) ...... - Yes - - - KRU 1H-103, KRU 1H -103L1, KRU 1H -103L2, KRU 1H -103L3 KRU 1H-103L4,.KRU.1H-113_ - - - - - Pre -produced injector: duration of pre production less than 3 months. (For service well only) - No. - .. Operator, Well will not be pre -produced... .. . . ..... . . . . . . . .... - - Conductor string provided ____ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ Yes - - 89 conductor set.... - Surface casing protects all -known USDWs - _ - - - - - - ..... . . . . . . .. . Yes Surface shoe at 1824' MD_ CMT vol adequate to circulate. on conductor & surf csg . - - _ - ....... - Yes - 138%. excess cement planned - - - - ...... CMT vol adequate to tie-in long string to surf csg--- - - - - - - - --- - - - - - - - - ---- No CMT will cover all known productive horizons . . . . . . . ........ . Yes - _ Productive_ interval will.be completed with perforated production casing - Casing designs adequate for C, -T, B&.permafrost . . .... . . . . ......... . . Yes Adequate tankage or reserve pit - .. -,- _ - - - .. - - ....... - Yes - - Rig has steel tanks; all waste to approved disposal wells If.a. re -drill, has -a 10-403 for abandonment been approved - - - - - - - - - - NA Adequate wellbore separation proposed.. - ... - Yes - - - Anti -collision analysis complete; no major risk failures If diverter required, does it meet regulations - - .. - - _ - Yes - _ - _ Diverter size and route meets regulation- Orilling fluid program schematic & equip list adequate.. - - - _ _ _ _ _ _ Yes - - _ - Max formation pressure is 1819 psig(8.6 ppg EMW); will drill w/ 8.8-10.0 ppg -EMW , _ - - BOPEs,.do they meet regulation - - - - - - - - ----- - - - - - - - - - - Yes BOPE-press rating appropriate; test to -(put psig in comments)......... - Yes - .. MPSP is 1412 psig; will test BOPS. to 3500.psig. - - ......... . . . . . . . .... . . . . . Choke manifold complies w/API- RP -53 (May 84) . .... . .... . . . . - - Yes .....- . Work will occur without operation shutdown . . . . .. . . . . . . . . . ..... . . YesIs presence-. of H2S gas probable ............................ ..... Yes.---.....----------........------...-------..........--------.......------ Mechanical.condition of wells within AOR verified (For service well only) - - - - - - -- - - - - - Yes - .... 1 H-103, 11-1-115 and 1H-113 proposed mechanical condition verified -- Permit can be issued w/o hydrogen sulfide measures . . . ... . . . . . ........ . . No ... H2S measures required, Well 1H -102 -measured 20 ppm H2S on. November 20, 2017... .. Data.presented on potential overpressure zones _ .... Yes - Expected reservoirpressure is 8.4-28,6. ppg EMW; will -be drilled with 8.8 - 10.0 ppg mud...Seismic analysis of shallow gas -zones- - - - - - - ---- - - - .... - - - - - - NA... Seabed condition survey (if off -shore) - - - - - - - - - - - -- - - - - - - NA Contact name/phone for weekly. progress reports [exploratory only] NA Geologic Engineering Eublic Commissioner: �/9a3 Commissioner: Date o sio Da�e3 �tQ. DT 5/30/2018 J 5/30/2018 THE STATE °f1.1 --- GOVERNOR BILL WALKER Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1H-115 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-053 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Surface Location: 289' FSL, 786' FEL, SEC. 28, TI 2N, RI OE, UM Bottomhole Location: 2550' FNL, 2454' FWL, SEC. 26, T12N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for the permit to drill the above referenced service 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 '�O day of May, 2018. STATE OF ALASKA A' ` ,KA OIL AND GAS CONSERVATION COMMISc, - I PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory -Gas Service -WAG 4 • Service - Disp ❑ to. Specify if well is proposed for: Drill ❑+ . Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service- Winj ❑ Single Zone ❑� • Coalbed Gas ❑'.. Gas Hydrates.-,❑ Redrill ❑ Reentry ❑ Exploratory -Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑' Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 KRU 1 H-115 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11,118. TVD: 4,252 Kuparak River Field West Salk Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 289' FSL & 786' FEL, Sec 28, TI 2N, RI OE, UM ADL025638, ADLO25639 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 2199' FSL & 1792' FWL, Sec 26, T12N, R10E, UM 931695000 80-261 6/11/2018 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 2550' FNL & 2454' FW L, Sec 26, T12N, R1 OE, UM 2560 acres & 2560 acres 2550' to ADLO25637 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 93.1' 15. Distance to Nearest Well Open Surface: x- 549553.43 - y- 5980991.68 - Zone- 4 GL / BF Elevation above MSL (ft): 54.1' to Same Pool: 1413' to 1 H-113 16. Deviated wells: Kickoff depth: 500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 80 degrees Downhole: 1,819 psi - Surface: 1,412 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94# H-40 Welded 80' Surf Sud 119' 119' Existing, cement to surface 13-1/2" 10-3/4" 45.5# L-80 HYD563 1785' Surf Surf 1824' 1780' 660 sx 11.0 ppg, 193 sx 12.0 ppg 8-3/4" 7" 26# L-80 HYD563/FX 11079' Surf Surf 11118' - 4252' 508 sx 15.8 ppg Class G 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Ent(y 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 El No ❑� 20. Attachments: Property Plat ❑ BOP Sketch ❑' Drilling Program ❑' Time v. Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements0 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: Nick Lehman Authorized Name: Chip Alvord Contact Email: DICk.r.lehman CO .COm Authorized Title: Alaska Drilling Manager Contact Phone: 907-263-4951 Authorized Signature: '� - Q Date: `�' 3 1L a ('5 Commission Use Only Permit to Drill /Q� Z( API Number: Permit Approval See cover letter for other Number. (/'� 50- .-�3 ,S-i�"r�d Dale: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methan , gas hydrates, or gas contained in shales: ,�/ Other: B� P fiC,S f fG .35-00 r 5' q f6 Z 5- 1-b �ySa�mmyples req'd: Yes ❑ No7 Yes Nog/ Mud log req'd: Yes❑ oU Directional Yes[�No❑ f}nh r� ri/ a r 1J r'r ✓ r n 7f ✓ /•1tS 1"""z J"easures: Q svy req'd: Spacing exception req'd: Yes ❑ NOLO Inclination -only svy req'd: VeC]No[Vr Post initial injection MIT req'd: YesR No❑ W1 ,i)''�%L7 CG �I'/O✓ iv 12 e- fp /e �'r "✓+9 , %r\ � 6 APPROVEDBY 7 f 3eI1 L°i ,Approved by: COMMISSIONER THE COMMISSION Date: Via, ORIGINAL Form 10-401 Revised 5/2017 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Submit Form and Aaachments in Duplicate Application for Permit to Drill, Well 1 H-115 Saved: 3 -May -18 May 3, 2018 Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Well IH -115, a West Sak Sand Injector Dear Commissioner ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots injector well from the 1H pad. The expected spud date for this well is June I I1h, 2018. It is planned to use rig Doyon 142. 1H-115 is planned to be a slant well thin the West Sak sands. The surface section will be drilled with 13-1/2" bit and run 10-3/4" casing to ±1,824' MD / 1,780' TVD. The production section will be drilled with 8-3/4" bit and run 7" casing to ±11,118' MD / 4,252' TVD. The upper completion will be run with 3-I/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 Nick Lehman at 907-263-4951 (nick.r.lehman@cop.com) or Chip Alvord at 265-6120. Sincerely, A-c.n-�_ Chip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well IH -115 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as KRU 1H-115 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item alreadv on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A) the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at ental depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface. referenced to the state plane coordinate system for this state as maintained by the National Geodetic Sumey in the National Oceanic and Atmospheric Administration: (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 289' FSL & 786' FEL, Sec 28, T12N, R10E, UM NGS Coordinates Northings: 5,980,991.68' Easlings: 549,553.43 RKBElevation 93.1'AMSL Pad Elevation 54.1'AMSL Location at Top of Productive Interval West Sak D Sand) 2199' FSL & 1792' FWL, Sec 26, T12N, RIOE, UM NGS Coordinates Northings: 5,982,957.99' Eastings: 557,393.27' Measured De th, RKB: 10,180' Total Vertical De th, RKB: 3,852' Total Vertical Depth, SS: 3,759' Location at Total De th 2550' FNL & 2454' FWL, Sec 26, T12N, R10E, UM NGS Coordinates Northings: 5,983,493.97' Eastings: 558,050.27' Measured De th, RKB: 11,118' Total Vertical De th, KB. 4,252' Total Vertical De th, SS: 4,159' and (D) otherinformation required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) if well is to be intentionally deviated, the application for a Permit to Drill (Farm 10-401) must (I) include a plat. d? an to it sortable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200feet ofany portion of the proposed well; Please see Attachment: Directional Plan And (2) for all ucells within 200 feet of the proposed wellbore (A) list the names of the operators ol'those wells, to the extent that those names are known or discorerable in public records, and shot that each named operator las been firntished a copy of the application by certified mail; or (B) state that the applicant is the only affected ocher. 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 nual be accompanied by each of the fiWowing items, except for an item already on file with the commission and identified in the application: (3) a diagran and description of the blovanr prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, 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 for a Permit to Drill must be accompanied by each of the following items, eccept for a n item already on file with the commission and identified in the application: (4) information on drilling hazards. including (A) the maxinam downhole pressure that mor, he encountered, criteria used to determine it, and inacinamn potential surface pressure based on a methane gradient. The maximum potential surface pressure (MPSP) while drilling 1H-115 is calculated using an estimated maximum reservoir pressure of 1,819 psi (based on 1H-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 4,068' TVD: A Sand Estimated. BHP = 1,819 psi A Sand estimated depth = 4,068' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 407 psi (4,068' TVD * 0.10 psi/ft) MPSP = BHP — gas column =1,412 psi (1,819 psi — 407 psi) tj (B) data on potential gas sones; The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones. and zones that have a propensity for differential sticking; See attached 1H-115 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill most be accompanied by each of the folloving items, except for an hem already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integr'in, 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 fora Permit to Drill must be accompanied by each of the follon'ing items, except for an ileo already on file with the canunission and identified in the application: (6) a complete proposed casing and cementing progrmn as required by 20 AAC 25.030, and a description of anv.slotted liner� pre-perf hated liner, or screen to be installed Casing and Cement Program Casing and ementing Program Csg/Pbg OD Hole Sine Weight Grade Conn. Length Top MD/ND Ban MD/I'VD Cement Program (in) (lb/ft) (ft) (ft) (ft) 20 42 94 H-40 Welded 80 Surf 1191119 Existing, cement to surface Cement to Surface with 10-3/4 13-1/2 45.5 L-80 HYD563 1,785 Surf 1,824 / 1,780 660 sx LiteCRETE Lead 11.0 ppg 193 sx LiteCRETE Tail 12.0 ppg 7 8-3/4 26 L-80 HYD563 / 11,079 Surf 11,118/4,252 508 sx Class G at 15.8 ppg Txp w/TOC at 8,340'MD 10-3/4" Surface casing run to 1,824' MD / 1,780' TVD Cement from 1,824' MD to 1,324'(500' of tail) with 12.0 ppg LiteCRETE, and from 1,324' to surface with 11.0 ppg LiteCRETE. Assume 150% excess annular volume for lead and 50% excess for tail, and 0% excess in 20" conductor. 10-3/4" SURFACE CEMENT CALCS Design: UniSLURRY Class G 15.8 ppg Cement to 250' TVD above Top of N Sand Design: SW of Tail Cmt @50% excess in Off & Lead Cmt to surface @ 150% excess in Off Tail Cement yield= r 1.65ft^3/sk I Lead Cement yield= r 1.91ft^3/sk 8340'MD 11.0 ppg LiteCRETE Lead Slurry 12U x 0.0383 bbl/ft x 1.0 (0% excess) CON DUCrOR= 119'x0.2477bbl/ftx 1.0(0% excess) 29.5 bbls Btm of Lead to COND= 1324'- 119') x 0.0648 bbl/ft x 2.5 (150% exceLsl 95.26b15 Total Lead Cement= 224.6 bbis I or 1261.2ft^3 or 660 sks (11118'- 129) x 0.0383 bbl/ft = 420.8 bbis 12.0 ppg LiteCRETE Tail Slurry Shoetrack= SW x 0.0962 bbl/ft x 1.00% excess) 8.2bbls Shoe to Top of Tail= (1824'-1324')x 0.0648 bbl/ft x 1.5(5096 excess) 48.666Is Total Tail Cement=I 56.8bbls I or 31&7ft^3 1 or 1193 sks Displacement= 1 (1824'- 85') x 0.0962 bbl/ft =1 167.2bbls 7" Production casing run to 11.118' MD / 4,252' TVD Single stage slurry is designed to be placed from TD to 8,340' MD, which is 250' TVD above top of West Sak Pool (base of Ugnu); 35% excess annular volume. 7" Production Cement Calculations Design: UniSLURRY Class G 15.8 ppg Cement to 250' TVD above Top of N Sand Cement yie Id= 1.16ft^3/sk I Planned TOC= 8340'MD Shoe Track 12U x 0.0383 bbl/ft x 1.0 (0% excess) 4.6 bbls Shoe to Top of Cement= (11118'-8340')x0.0268 bbl/ft x 1.35(3551 excess) 100.4 bbls Total Cement Volume= 305bbls I or 589.6 ftA3 or 508sks Displacement= (11118'- 129) x 0.0383 bbl/ft = 420.8 bbis Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application fora Permit to Drill must be accompanied by each of the following items, except formr item alread_c on file ivhh the cmnunission and identified in the application: (7) a diagram and description ofthe divener system as required by 20 AAC 25.035. unless this requirement is unfired by the eonunission under 20 AAC 25.035(d)(2); Please reference diverter schematic attached. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An _ ,.it to Aill rmi st be accompanied by each of the following items, except far un item already on file with the carnn'ission and id"a'j" l ni I", ,qi, 111, kion: (S) a drilling fuid program, including a diagram and description ofthe drilling fluid system, as required by 20 AAC25.033; 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 strati graphic 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 Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill nmst be accompanied by each o(the following itenu. except for an item aheodi on file with the commission and identified in the application: Surface 13-1/2" Hole 10-3/4" Casing Production 8-3/4" Hole T' Casing Mud System Spud (WBM)M) LSND 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 strati graphic 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 Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill nmst be accompanied by each o(the following itenu. except for an item aheodi 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 surface TD as per directional plan. Run MWD/LWD tools as required for directional monitoring (gamma ray). 3. Run and cement 10.75", 45.5#, L80, HYD563 casing to surface. Displace cement with mud and check floats upon bumping plug. Notify AOGCC if top job is required. 4. Remove diverter system and install wellhead. 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 Ins before test. 5. PU 8.75" bit and 6.75" drilling assembly, with MWD/LWD (gamma ray and resistivity). 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' of new hole. Perform leak off test to a minimum of 11.5ppg EMW LOT/FIT, recording results. 7. Displace to 9.0 - 9.2 ppg LSND water-based drilling fluid. 8. Directionally drill to production TD as per directional plan. 9. Circulate hole clean. POOH. 10. Run 7", 26#, L80, HYD563/TXP casing to surface. (Top of cement to be 8,340' MD / 3,439' TVD which corresponds to 250' TVD above top of the West Sak Pool.) 11. Install 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 (48.35% of published burst rating) for 30 min. 14. Run CBL on wireline. ✓ 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 and test in the direction of flow. 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 Perrot to Drill must he accompanied by each of the following items, escept.lor an item oh'eady on file with the conunission and identified in she application: (14) a general description of how the operator planus to dispose of drilling mud mrd cuttings and a statement of whether the operator intends to request authoriurdon wider 20 AAC 25.080,for 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 11 disposal well (DS 1B CRI) or Prudhoe DS -4. All 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. Attachments: Attachment 1 AOR Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic Attachment 5 Diverter Layout Diagram Attachment 6 BOP Configuration Attachment 1 AOR An Area of Review plot is shown below of the 1H-115 planned wellpath and offset wells. The included table identifies any of the offset wellbores within (or approximate to) the 1/4 -mile review. ":3I Ma a,zala 1 H-115wp21 e TOC TOC Reservoir Quarter Mile View »nima,"aowuw "A0°i-a x; Name Status Sak D Sand (MD/ +s9 Status Zonal Isolation Summary (MD/TVD) TVD) 6000 A 0 't L10x w Proposed 10,180' / Planned: 8,340/ CBL Not Yet 1X @L1_ ^ Injector 3,852' 3,439' Drilled 250' TVD above pool top. o q Cement top planned to be I Laterals are open hole w/ Pumped 1,210 sks Class 1H-103 Producer 6,837 MD / more than 250' above pool currently on hrmediate off at G. Cementjob went as (Currently t 4500 top. well. 9 planned. Saw good lift Drilling) Production from Laterals. pressures. ✓ `� Intersects Pumped 770 sks Class 1H-] 13 Active C 5,395'/ CBL WestSak Column of cement is 804' G. Cement job went pas Injector 3,808' 2,819' sands: A, B, TVD above pool top. planned. Saw good lift �3e C, & D pressures. h i i 1N.111 _ I � p 000 I I � 1N.1q i r Sit wo I Z L 0 O � 0 -1500 -1500 0 1500 3000 4500 6000 7500 9000 10500 West( -)/East(+) (1500 usft/in) Well e TOC TOC Reservoir Cement Operations Name Status Sak D Sand (MD/ +s9 Status Zonal Isolation Summary (MD/TVD) TVD) I ^ A 0 't L10x w Proposed 10,180' / Planned: 8,340/ CBL Not Yet 1X @L1_ ^ Injector 3,852' 3,439' Drilled 250' TVD above pool top. o q Cement top planned to be I Laterals are open hole w/ Pumped 1,210 sks Class 1H-103 Producer 6,837 MD / more than 250' above pool currently on hrmediate off at G. Cementjob went as (Currently t 3,806' TVD top. well. 9 planned. Saw good lift Drilling) Production from Laterals. pressures. ✓ `� Intersects Pumped 770 sks Class 1H-] 13 Active 9,704' / 5,395'/ CBL WestSak Column of cement is 804' G. Cement job went pas Injector 3,808' 2,819' sands: A, B, TVD above pool top. planned. Saw good lift �3e C, & D pressures. i i 1N.111 _ I � I I � 1N.1q i r I I Well Top of West TOC TOC Reservoir Cement Operations Name Status Sak D Sand (MD/ Determine Status Zonal Isolation Summary (MD/TVD) TVD) it By IH -115 Proposed 10,180' / Planned: 8,340/ CBL Not Yet Column of cement ro be Well does not exist yet Injector 3,852' 3,439' Drilled 250' TVD above pool top. Proposed Cement top planned to be Drilling rig Laterals are open hole w/ Pumped 1,210 sks Class 1H-103 Producer 6,837 MD / more than 250' above pool currently on hrmediate off at G. Cementjob went as (Currently t 3,806' TVD top. well. intermediate casing. planned. Saw good lift Drilling) Production from Laterals. pressures. ✓ `� Intersects Pumped 770 sks Class 1H-] 13 Active 9,704' / 5,395'/ CBL WestSak Column of cement is 804' G. Cement job went pas Injector 3,808' 2,819' sands: A, B, TVD above pool top. planned. Saw good lift C, & D pressures. 10:32, May 012018 DD 1H-115wp21 D1$ Plan Summar K-15 'v 5 BaseMndst a�I IIN y `1' v T 3 o I l p VNtc 49 I UG -C UG -I UG -A .. V WS Base 0 21 x 42' 4500 6750 9000 10-3/4" x 13-1/2 Measured Depth 7000 Plan: 54.1+39 @ 93.10usft (Doyon 142) til' o M 0 I a 0 0 voi o o o 0 0 o NI > 41 I O I ((C ^O m 1 FO 7 H-177wp26.1 0 _ _ 1 H-118 39 500 Soo - 600 20" 42' z ^o,T - 10-3/4" 13-1/2 3000 4500 6000 7500 6 J011. _ _ - x E 30 690 870 Horizontal Departure T'x8-3/4' 15330 H-10 7H-114 370-IWO ,030 1240 0 1H-113 -� I' IH -111240 - 1430 300 'fy0 14M 1310 w 60 - 180i0 y H -OS �ilgt iH-116 21W8ID 300 - z1 W _ 2190 2580 2530 MO m 30 c 270 --- , 90 293o - 3350 1H-117wp26.i ( $350 - 3740 x740 - 4120 ` r 'c 0 ,1° ^E}II ' 41M 4510 4510 4900 49M - 5630 `400 0 800 1200 1600 2000 2400 2800 "f ./ie 240 P g:>%; 120 5330 - 5650 Equivalent Magnetic Distance Measured Depth t r ;0 210 150 1 H-113 8650 - 7230 7230 0010 0010 8790 0790 9500 SURVEY PROGRAM Pad Elevation: 54.10 Depth From Depth To su.,Wlm Taal 39.00 1200.00 1H-115wp21 (Plan: iH-115) GY0.GCSa 9560 10340 1200.00 1824.35 1H-it5wp21'(Pt: 1H-115) MWD iH-112Wp21 180 ame 1200.00 1826.35 1H-;I'l (Plein iH-115) MWDNFR-AKCAZSD 10340 11118 182035 3324.35 1H-115wp21(Pla 1H-115) MWD 118.10 118.10 20"x42" Magnetic Model & Date: BGGM2017 12 -Jun -78 1824,35 1111827 ,H-nswpz, rylan: ,H -ns) MwD«lFR-AK-cAz-W 42 51 99111 8.00 OJ/47"xa-a�a•' Magnetic North is 17.06° East of True North (Magnetic Declination) Magnetic Dip & Field Strength: 80.93° 57466nT SECTION DETAILS Lithology Column Sec MD Inc An TVD +N/ -S +E/ -W Oleg TFace VSeo1 Target Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 KOP: Start 1°/100' DLS, 105° TF, for 200' 3 700.00 2.00 105.00 699.96 -0.90 3.37 1.00 105.00 2.96 Start 2°/100' DLS, -5' TF, for 301.33' a 41001,33 8.02 101.24 1000.00-6.37 29.09 2.00 -5.00 25.96 Start2.5°/100' DLS, 0° TF, for 618.1' Base Pfrost 5 1619.43 23A7 101.24 1593.10 -38.96 193.13 2.50 0.00 173.29 Hold for 109.02' 4 6 1728.45 23.47 101.24 1693.10 -47.43 235.72 0.00 0.00 211.55 Start3°/100' DLS, -15° TF, for 95.9' T-3 7 1824.35 26.26 99.56 1780.10 -54.68 275.38 3.00 -1500 247.36 Hold for 20' 8 1844.35 28.26 99.56 1798.04-56.15 284.11 0.00 0.00 255.28 Start 4.5°/700' DLS, 0° TF, for 860.84' 9 2705.19 65.00 99.56 2388.60 -156.39 879A5 4.50 0.00 795.30 Start4°/100' DLS, -63.29° TF, far 732.94' 103436.13 80.27 73.21 2610.27 -106.11 1567.86 4.00 b3.291468.33 Hold for 60563' 11 9494.42 80.27 73.21 3633.86 1617.94 728264 0.00 0.00 743T46 Start 4°/100 DLS, A31.99° TF, for 671.21' 1210165.64 63.35 51.15 3845.00 1906.93 7843.21 4.00 .131.99 8058M Hold for 1471' 1310180.35 63.35 51.15 3851.60 1915.18 7853.45 0.00 0.00 8070.24 111-115 TOt-D 042018 RP Adjust TF to 0°, for 141.56' 140321 91 63.35 51.15 3915.10 1994.55 7951.99 0.00 0.00 8187.67 1 H-115 TOM 042018 RP Start 0.5°/100' DLS, 0.65° TF, for 450.22' K-15 1510772.13 65.60 51.18 4109.10 2249.30 8268.43 0.50 0.65 8564.77 HOW for 346.14' 101118.27 65.60 51.18 4252.10 2446.91 8514.02 000 0.008857.41 1H-115 T03 -Base 042018 RP TD: 11118.27' MD, 4252.1' TVD avow UG -C cUG-B M UG -A Na t Pack 1 R tl SA2 us §_-ase 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 the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.) Orientation approve it as the basis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all tar ets have a 100 feet lateral tolerance. Prepared by� Checked by: ccepted by. Approved by: V. Osara Huy Bui Anh Erik Stark Spider View 1 H-115wp21 Plan View While dililing production section stay within target polygon laterally of plan, unless notified otherwise. 3800- [1 —H- 115 T03 -Base 042018 P Sri 2850 7" x 8-3/4" - = c 1900 foo 0 0) °' 1 H-115 T01 -D 042018 0950- 1 H-115 T02 -B 042018 z w o 0 �° N 0 -a 1. 20" x 42" 10-3/4" x 13-1/2" _950- 0 950 1900 2850 3800 4750 5700 6650 7600 8550 West( -)/East(+) (950 usft/in) 1 H-115wp21 Plan View While drilling production section stay within tar of polygon lateralIV of plan, unless notified otherwise. 3800 1 H-115 T03 -Base 042018 P `sem 2850 acs, 7„ x 8-3/4" y 1900 rn °o o Ln - ; m 1 H-115 T01 -D 042018 + I I `0950 1H-115 T02 -B 042018 z � 0 0 o 0 0 0 0 0- 2 20" x 42" 10-3/4" x 13-1/2" -950- 0 950 1900 2850 3800 4750 5700 6650 7600 8550 West( -)/East(+) (950 usft/in) 1 H.115wp21 Section View -1000,; 0 — 20" x 42" 0° c 1000 INC) N 7 O o �� ,e _ - _ _ - - 10-3/4" x 13-1 /2" r 2000; n 0 0 o 0 � M O � O O U UJ N 3000 a) 40001 5000- 0 O O o O O CO N O O 0 0 rn o0 7" x 8-3, 0 0 1 H-115 T01 -D 042018 P 1 H-115 T02 -B 042018 P Q 1 H-115 T03 -Base 042018 P Z 1000 2000 3000 4000 5000 6000 Vertical Section at 73.00° (1000 usft/in) 7000 8000 9000 1 H-115wp21 Section View -1000 0 _ 20"x42" 0° c 1000-{ 1000 w 0 10-3/4" x 13-1/2" L 2000 aCLi I 0 0 o 0 p m o d h 1H-115 T02 -B 042218AP o0 0 0 3000) � o r-115 T01 -D 042018 R CO o' mo T x 8-3/4' o Iio 4000-- 1 H-115 T03 -Base 042018 P 5000 i ... _ Z 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Vertical Section at 73.00° (1000 usft/in) ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 11-1-115 50029xxxxx00 Plan: IH -115 Plan: 1 H-115wp21 Standard Proposal Report 01 May, 2018 ConocoJhillipss ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Plan: 111-115 Wellbore: Plan: iH-115 Design: 1H-115wp21 Schlumberger Standard Proposal Report Local Co-ordinate Reference: Well Plan: 11H-115 TVD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) MD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Project Kupawk River LIM, 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 Site Kuparuk 1H Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.37 ° Well Plan: 1H-115 Audit Notes: Well Position +N/S 1,020.63 usft Northing: Latitude: Phase: +E1 -W 362.96 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: 54.10 usft Wellbore Plan: 111-115 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) 1°I (nn BGGM2017 6/12/2018 17.06 80.93 57,466 Design 1H-115wp21 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (ND) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 73.00 Plan Survey Tool Program Data 5/1/2018 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.00 1,200.00 111-115wp21 (Plan: 11-1-115) GYD-GC-SS Gyrodata gyro single shots 2 1,200.00 1,824.35 1H-115wp21 (Plan: 1H-115) MWD MWD - Standard 3 1,200.00 1,824.35 1H-115wp21 (Plan: 111-115) MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 4 1,824.35 3,324.35 111-115wp21 (Plan: 1H-115) MWD MWD - Standard 5 1,824.35 11,118.27 1H-115wp21 (Plan: 1H-115) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/12018 10:17:50AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk I Pao Well: Plan: 1H-115 Wellbore: Plan: 1H-115 Design: 1H-115wp21 Plan Sections Build Turn Measured Rate Rate Depth Inclination Azimuth (usft) 0.00 0.00 39.00 0.00 0.00 500.00 0.00 0.00 700.00 2.00 105.00 1,001.33 8.02 101.24 1,619.43 23.47 101.24 1,728.45 23.47 101.24 1,824.35 26.26 99.56 1,844.35 26.26 99.56 2,705.19 65.00 99.56 3,438.13 80.27 73.21 9,494.42 80.27 73.21 10,165.64 63.35 51.15 10,180.35 63.35 51.15 10,321.91 63.35 51.15 10,772.13 65.60 51.18 11,118.27 65.60 51.18 Vertical Depth lush) 39.00 500.00 699.96 1,000.00 1,593.10 1,693.10 1,780.10 1,798.04 2,388.60 2,610.27 3,633.86 3,845.00 3,851.60 3,915.10 4,109.10 4,252.10 +NI -S (usft) 0.00 0.00 -0.90 -6.37 -38.96 -47.43 -54.68 -56.15 -156.39 -106.11 1,617.94 1,906.93 1,915.18 1,994.55 2,249.30 2,446.91 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: +E1 -W (usft) 0.00 0.00 3.37 29.09 193.13 235.72 275.38 284.11 879.45 1,567.86 7,282.64 7,843.21 7,853.45 7,951.99 8,268.43 8,514.02 Schlumberger Standard Proposal Report Well Plan: 1 H-115 Plan: 54.1+39 @ 93, 10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Dogleg Build Turn Rate Rate Rate (-M00usft) (°1100us@) (°1100usft) 0.00 0.00 0.00 0.00 0.00 0.00 1.00 1.00 0.00 2.00 2.00 -1.25 2.50 2.50 0.00 0.00 0.00 0.00 3.00 2.91 -1.75 0.00 0.00 0.00 4.50 4.50 0.00 4.00 2.08 -3.59 0.00 0.00 0.00 4.00 -2.52 -3.29 0.00 0.00 0.00 0.00 0.00 0.00 0.50 0.50 0.01 0.00 0.00 0.00 TFO (°) Target 0.00 0.00 105.00 -5.00 0.00 0.00 -15.00 0.00 0.00 -63.29 0.00 -131.99 0.00 11-1-115 T01 -D 04201E 0.00 11-4-115 T02 -B 04201E 0.65 0.00 11-1-115 T03 -Base 04, 5112018 10:1750AM Page 3 COMPASS 5000.14 Boild 85 ConocoPhillips Schlumberger Standard Proposal Report Database: OAKEDMP2 Local Coordinate Reference: Well Plan: 1H-115 Company: ConocoPhillips (Alaska) Inc. -Kupl 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 1 H Pad North Reference: True Well: Plan: 1H-115 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-115 Design: 1H-115wp21 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100usft) (°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 0.00 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 KOP: Start 1°/100' DLS, 105° TF, for 200' 600.00 1.00 105.00 599.99 -0.23 0.84 0.74 1.00 1.00 0.00 700.00 2.00 105.00 699.96 -0.90 3.37 2.96 1.00 1.00 0.00 Start 2°/100' DLS, -5- TF, for 301.33' 800.00 4.00 102.50 799.82 -2.11 8.46 7.47 2.00 2.00 -2.50 900.00 5.99 101.66 899.43 -3.92 16.98 15.09 2.00 2.00 -0.84 1,000.00 7.99 101.24 998.68 -6.33 28.91 25.60 2.00 2.00 -0.42 1,001.33 8.02 101.24 1,000.00 -6.37 29.09 25.96 2.00 2.00 -0.31 Start 2.5°/100' DLS, 0° TF, for 618.1' 1,100.00 10.49 101.24 1,097.38 -9.46 44.66 39.94 2.50 2.50 0.00 1,200.00 12.99 101.24 1,195.28 -13.42 64.61 57.86 2.50 2.50 0.00 1,300.00 15.49 101.24 1,292.20 -18.22 88.73 79.52 2.50 2.50 0.00 1,400.00 17.99 101.24 1,387.96 -23.83 116.97 104.89 2.50 2.50 0.00 1,500.00 20.49 101.24 1,462.36 -30.25 149.29 133.92 2.50 2.50 0.00 1,600.00 22.99 101.24 1,575.25 -37.47 185.61 166.54 2.50 2.50 0.00 1,619.43 23.47 101.24 1,593.10 -38.96 193.13 173.29 2.50 2.50 0.00 Hold for 109.02' 1,673.94 23.47 101.24 1,643.10 -43.20 214.42 192.42 0.00 0.00 0.00 Base Phrost 1,700.00 23.47 101.24 1,667.00 -45.22 224.60 201.57 0.00 0.00 0.00 1,728.45 23.47 101.24 1,693.10 -47.43 235.72 211.55 0.00 0.00 0.00 Start 3°/100' DLS, -16° TF, for 96.9' 1,800.00 25.55 99.95 1,756.20 -52.87 264.90 237.86 3.00 2.91 -1.80 1,824.35 26.26 99.56 1,780.10 -54.68 275.38 247.36 3.00 2.92 -1.62 Hold for 20'. 10-3/4" x 13-1/2" 1,844.35 26.26 99.56 1,798.04 -56.15 284.11 255.28 0.00 0.00 0.00 Start 4.5°1100' DLS, 0° TF, for 860.84' 1,863.45 27.12 99.56 1,815.10 -57.57 292.57 262.95 4.50 4.50 0.00 T-3 1,900.00 28.77 99.56 1,847.39 -60.41 309.46 278.27 4.50 4.50 0.00 2,000.00 33.27 99.56 1,933.07 -68.97 360.26 324.35 4.50 4.50 0.00 2,100.00 37.77 99.56 2,014.44 -78.61 417.53 376.30 4.50 4.50 0.00 2,149.67 40.00 99.56 2,053.10 -83.79 448.27 404.19 4.50 4.50 0.00 K-16 2,200.00 42.27 99.56 2,091.01 -89.28 480.92 433.80 4.50 4.50 0.00 2,300.00 46.77 99.56 2,162.29 -100.92 550.04 496.50 4.50 4.50 0.00 2,400.00 51.27 99.56 2,227.86 -113.45 62447 564.01 4.50 4.50 0.00 2,500.00 55.77 99.56 2,287.30 -126.80 703.73 635.91 4.50 4.50 0.00 2,600.00 60.27 99.56 2,340.26 -140.88 787.35 711.76 4.50 4.50 0.00 2,700.00 64.77 99.56 2,386.40 -155.61 874.81 791.09 4.50 4.50 0.00 2,705.19 65.00 99.56 2,388.60 -156.39 879.45 795.30 4.50 4.50 0.00 Start 4°1100' DLS, 463.29° TF, for 732.94' 2,800.00 66.75 95.87 2,427.36 -167.98 965.17 873.89 4.00 1.85 -3.89 2,900.00 68.69 92.09 2,465.29 -174.38 1,057.46 960.27 4.00 1.94 -3.78 5112018 10.17:50AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Schlumberger Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan: 1H-115 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Project: Kupawk River Unit MD Reference: Plan: 54.1+39 @ 93.1 oust (Doyon 142) Site: Kupawk 1H Pad North Reference: True Well: Plan: 1H-115 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-115 Design: 1 H-115wp21 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate ''. (usft) (1) (usft) (usft) (usft) (usft) (°/100usft) (°1100usft) (°1100usft) 3,100.00 72.79 84.81 2,531.32 -169.13 1,246.00 1,142.11 4.00 2.09 -3.59 3,200.00 74.95 81.30 2,559.11 -157.50 1,341.33 1,236.67 4.00 2.15 -3.51 3,300.00 77.15 77.87 2,583.22 -139.95 1,436.76 1,333.06 4.00 2.21 -3.44 3,400.00 79.40 74.49 2,603.54 -116.55 1,531.81 1,430.81 4.00 2.25 -3.38 3,438.13 80.27 73.21 2,610.27 -106.11 1,567.86 1,468.33 4.00 2.28 -3.34 Hold for 6056.3' 3,500.00 80.27 73.21 2,620.73 -88.50 1,626.24 1,529.31 0.00 0.00 0.00 3,600.00 80.27 73.21 2,637.63 -60.03 1,720.61 1,627.87 0.00 0.00 0.00 3,700.00 80.27 73.21 2,654.53 -31.56 1,814.97 1,726.43 0.00 0.00 0.00 3,800.00 80.27 73.21 2,671.43 -3.09 1,909.33 1,824.99 0.00 0.00 0.00 3,900.00 80.27 73.21 2,688.33 25.37 2,003.69 1,923.56 0.00 0.00 0.00 4,000.00 80.27 73.21 2,705.23 53.84 2,098.05 2,022.12 0.00 0.00 0.00 4,100.00 80.27 73.21 2,722.14 82.31 2,192.41 2,120.68 0.00 0.00 0.00 4,200.00 80.27 73.21 2,739.04 110.77 2,286.77 2,219.24 0.00 0.00 0.00 4,300.00 80.27 73.21 2,755.94 139.24 2,381.13 2,317.80 0.00 0.00 0.00 4,400.00 80.27 73.21 2,772.64 167.71 2,475.49 2,416.36 0.00 0.00 0.00 4,500.00 80.27 73.21 2,789.74 196.18 2,569.85 2,514.92 0.00 0.00 0.00 4,600.00 80.27 73.21 2,806.64 224.64 2,664.21 2,613.48 0.00 0.00 0.00 4,700.00 80.27 73.21 2,823.54 253.11 2,758.58 2,712.04 0.00 0.00 0.00 4,800.00 80.27 73.21 2,840.44 281.58 2,852.94 2,810.60 0.00 0.00 0.00 4,900.00 80.27 73.21 2,857.34 310.04 2,947.30 2,909.16 0.00 0.00 0.00 5,000.00 80.27 73.21 2,874.25 338.51 3,041.66 3,007.72 0.00 0.00 0.00 5,100.00 80.27 73.21 2,891.15 366.98 3,136.02 3,106.28 0.00 0.00 0.00 5,200.00 80.27 73.21 2,908.05 395.44 3,230.38 3,204.84 0.00 0.00 0.00 5,300.00 80.27 73.21 2,924.95 423.91 3,324.74 3,303.41 0.00 0.00 0.00 5,400.00 80.27 73.21 2,941.85 452.38 3,419.10 3,401.97 0.00 0.00 0.00 5,500.00 80.27 73.21 2,958.75 480.85 3,513.46 3,500.53 0.00 0.00 0.00 5,600.00 80.27 73.21 2,975.65 509.31 3,607.82 3,599.09 0.00 0.00 0.00 5,700.00 80.27 73.21 2,992.55 537.78 3,702.18 3,697.65 0.00 0.00 0.00 5,800.00 80.27 73.21 3,009.46 566.25 3,796.55 3,796.21 0.00 0.00 0.00 5,900.00 80.27 73.21 3,026.36 594.71 3,890.91 3,894.77 0.00 0.00 0.00 6,000.00 80.27 73.21 3,043.26 623.18 3,985.27 3,993.33 0.00 0.00 0.00 6,100.00 80.27 73.21 3,060.16 651.65 4,079.63 4,091.89 0.00 0.00 0.00 6,200.00 80.27 73.21 3,077.06 680.11 4,173.99 4,190.45 0.00 0.00 0.00 6,300.00 80.27 73.21 3,093.96 708.58 4,268.35 4,289.01 0.00 0.00 0.00 6,400.00 80.27 73.21 3,110.86 737.05 4,362.71 4,387.57 0.00 0.00 0.00 6,413.24 80.27 73.21 3,113.10 740.82 4,375.20 4,400.62 0.00 0.00 0.00 UGC 6,500.00 80.27 73.21 3,127.76 765.52 4,457.07 4,486.13 0.00 0.00 0.00 6,600.00 80.27 73.21 3,144.67 793.98 4,551.43 4,584.69 0.00 0.00 0.00 6,700.00 80.27 73.21 3,161.57 822.45 4,645.79 4,683.26 0.00 0.00 0.00 6,800.00 80.27 73.21 3,178.47 850.92 4,740.15 4,781.82 0.00 0.00 0.00 6,900.00 80.27 73.21 3,195.37 879.38 4,834.52 4,880.38 0.00 0.00 0.00 7,000.00 80.27 73.21 3,212.27 907.85 4,928.88 4,978.94 0.00 0.00 0.00 7,100.00 80.27 73.21 3,229.17 936.32 5,023.24 5,077.50 0.00 0.00 0.00 7,200.00 80.27 73.21 3,246.07 964.78 5,117.60 5,176.06 0.00 0.00 0.00 7,300.00 80.27 73.21 3,262.97 993.25 5,211.96 5,274.62 0.00 0.00 0.00 7,400.00 80.27 73.21 3,279.87 1,021.72 5,306.32 5,373.18 0.00 0.00 0.00 7,500.00 80.27 73.21 3,296.78 1,050.19 5,400.68 5,471.74 0.00 0.00 0.00 7,600.00 80.27 73.21 3,313.68 1,078.65 5,495.04 5,570.30 0.00 0.00 0.00 7,700.00 80.27 73.21 3,330.58 1,107.12 5,5159.40 5,668.86 0.00 0.00 0.00 7,800.00 80.27 73.21 3,347.48 1,135.59 5,683.76 5,767.42 0.00 0.00 0.00 7,900.00 80.27 73.21 3,364.38 1,164.05 5,778.12 5,865.98 0.00 0.00 0.00 5/1/2018 10:17:50AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Plan: 11-1-115 Wellbore: Plan: 1H-115 Design: 1H-115wp21 Planned Survey Measured Vertical Dogleg Vertical Depth Inclination +N/ -S Azimuth Depth lust[) (_) V) (usft) (usft) 8,100.00 80.27 73.21 (-/100usft) 3,398.18 8,200.00 80.27 73.21 0.00 3,415.08 8,300.00 80.27 73.21 0.00 3,431.99 8,400.00 80.27 73.21 6,260.23 3,448.89 8,442.68 80.27 73.21 6,249.93 3,456.10 UG -B 0.00 0.00 1,318.54 6,290.20 8,500.00 80.27 73.21 0.00 3,465.79 8,600.00 80.27 73.21 0.00 3,482.69 8,700.00 80.27 73.21 0.00 3,499.59 8,800.00 80.27 73.21 6,654.47 3,516.49 8,900.00 60.27 73.21 6,627.37 3,533.39 9,000.00 80.27 73.21 1,448.72 3,550.29 9,100.00 80.27 73.21 0.00 3,567.19 9,134.94 80.27 73.21 0.00 3,573.10 UG -A 6,910.46 7,048.71 0.00 0.00 9,200.00 80.27 73.21 7,083.15 3,584.10 9,300.00 80.27 73.21 7,004.82 3,601.00 9,400.00 80.27 73.21 1,562.59 3,617.90 9,494.42 80.27 73.21 0.00 3,633.86 Start 4°1100' DLS, -131.99° TF, for 571.21' 0.00 9,500.00 80.12 73.04 7,282.64 3,634.81 9,600.00 77.46 70.00 1,619.53 3,654.25 9,700.00 74.84 66.89 -3.02 3,678.19 9,740.34 73.79 65.61 -2.66 3,689.10 Na 7,471.20 7,637.76 4.00 -2.62 9,800.00 72.26 63.70 7,676.32 3,706.52 9,900.00 69.73 60.42 7,558.31 3,739.10 10,000.00 67.26 57.04 1,770.58 3,775.76 10,100.00 64.87 53.53 -3.28 3,816.34 10,165.64 63.35 51.15 -2.46 3,645.00 Hold for 14.71' 7,796.47 8,002.79 4.00 -2.39 10,180.35 63.35 51.15 8,058.03 3,851.60 Adjust TF to 0°, for 141.56' - WS_D -3.62 1,915.18 10,200.00 63.35 51.15 0.00 3,860.41 10,269.52 63.35 51.15 0.00 3,891.60 WSLC 1,965.17 7,915.52 8,144.21 0.00 10,300.00 63.35 51.15 7,936.73 3,905.27 10,321.91 63.35 51.15 1,994.55 3,915.10 Start 0.6°1100' DLS, 0.65° TF, for 460.22' - WS_B 0.00 10,393.70 63.71 51.15 8,247.31 3,947.10 WS A4 0.01 2,038.40 8,006.43 8,252.56 10,400.00 63.74 51.16 2,087.43 3,949.89 10,487.03 64.17 51.16 0.01 3,988.10 WS A3 8,335.98 0.50 0.50 0.01 10,500.00 64.24 51.16 0.50 3,993.75 10,600.00 64.74 51.17 8,480.81 4,036.62 10,672.63 65.10 51.17 8,217.33 4,067.60 WS -A2 0.50 0.01 2,249.30 8,268.43 10,700.00 65.24 51.17 0.01 4,079.10 10,772.13 65.60 51.18 0.00 4,109.10 Hold for 346.14' 10,800.00 65.60 51.18 4,120.61 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Schlumberger Standard Proposal Report Well Plan: 11A-115 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 5/1/2018 10:17:50AM Page 6 COMPASS 5000.14 Build 85 Vertical Dogleg Build Turn +N/ -S +E/ -W Section Rale Rate Rate (usft) (usft) (usft) ("1100usft) (°/100usft) (-/100usft) 1,220.99 5,966.85 6,063.11 0.00 0.00 0.00 1,249.45 6,061.21 6,161.67 0.00 0.00 0.00 1,277.92 6,155.57 6,260.23 0.00 0.00 0.00 1,306.39 6,249.93 6,358.79 0.00 0.00 0.00 1,318.54 6,290.20 6,400.85 0.00 0.00 0.00 1,334.86 6,344.29 6,457.35 0.00 0.00 0.00 1,363.32 6,438.65 6,555.91 0.00 0.00 0.00 1,391.79 6,533.01 6,654.47 0.00 0.00 0.00 1,420.26 6,627.37 6,753.03 0.00 0.00 0.00 1,448.72 6,721.73 6,851.59 0.00 0.00 0.00 1,477.19 6,816.09 6,950.15 0.00 0.00 0.00 1,505.66 6,910.46 7,048.71 0.00 0.00 0.00 1,515.60 6,943.42 7,083.15 0.00 0.00 0.00 1,534.12 7,004.82 7,147.27 0.00 0.00 0.00 1,562.59 7,099.18 7,245.83 0.00 0.00 0.00 1,591.06 7,193.54 7,344.40 0.00 0.00 0.00 1,617.94 7,282.64 7,437.46 0.00 0.00 0.00 1,619.53 7,287.90 7,442.95 4.00 -2.68 -3.02 1,650.61 7,380.91 7,540.99 4.00 -2.66 -3.05 1,686.26 7,471.20 7,637.76 4.00 -2.62 -3.11 1,701.90 7,506.75 7,676.32 4.00 -2.60 -3.16 1,726.32 7,558.31 7,732.78 4.00 -2.57 -3.20 1,770.58 7,641.83 7,825.59 4.00 -2.53 -3.28 1,818.84 7,721.34 7,915.74 4.00 -2.46 -3.39 1,870.87 7,796.47 8,002.79 4.00 -2.39 -3.51 1,906.93 7,843.21 8,058.03 4.00 -2.32 -3.62 1,915.18 7,853.45 8,070.24 0.00 0.00 0.00 1,926.20 7,867.13 8,086.54 0.00 0.00 0.00 1,965.17 7,915.52 8,144.21 0.00 0.00 0.00 1,982.26 7,936.73 6,169.49 0.00 0.00 0.00 1,994.55 7,951.99 8,187.67 0.00 0.00 0.00 2,034.85 8,002.03 8,247.31 0.50 0.50 0.01 2,038.40 8,006.43 8,252.56 0.50 0.50 0.01 2,087.43 8,067.33 8,325.14 0.50 0.50 0.01 2,094.76 8,076.43 8,335.98 0.50 0.50 0.01 2,151.35 8,146.73 8,419.75 0.50 0.50 0.01 2,192.60 8,197.97 8,480.81 0.50 0.50 0.01 2,208.17 8,217.33 8,503.88 0.50 0.50 0.01 2,249.30 8,268.43 8,564.77 0.50 0.50 0.01 2,265.21 8,288.20 8,588.33 0.00 0.00 0.00 5/1/2018 10:17:50AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Schlumberger Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan: iH-115 Company: ConocoPhillips (Alaska) Inc. -Kupi Casing TVD Reference: Depth Plan: 54.1+39 @ 93.10usft (Doyon 142) Project: Kuparuk River Unit Diameter (usft) MD Reference: Name Plan: 54.1+39 Q 93.10usft (Doyon 142) Site: Kuparuk 1H Pad 118.10 20" x 42" North Reference: 42 True Well: Plan: 1H-115 10-3/4 13-1/2 Survey Calculation Method: Minimum Curvature Wellbore: Plan: IH -115 8-3/4 Design: 1H-115wp21 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-5 +E/ -W Section Rate Rate Rate (usft) O (1) (usft) (usft) (usft) (usft) (1/100usft) ('/100usft) (11100usft) 10,914.94 65.60 51.18 4,168.10 2,330.83 8,369.76 8,685.51 0.00 0.00 0.00 WS -Al 11,000.00 65.60 51.18 4,203.24 2,379.39 6,430.11 8,757.42 0.00 0.00 0.00 11,100.00 65.60 51.18 4,244.55 2,436.48 8,501.06 8,841.96 0.00 0.00 0.00 11,118.00 65.60 51.18 4,251.99 2,446.75 8,513.83 8,857.18 0.00 0.00 0.00 7" x 8414^ 11,118.27 65.60 51.18 4,252.10 , 2,446.91 8,514.02 8,857.41 0.00 0.00 0.00 TD: 11111118.27'111113, 4262.1' TVD Design Targets Target Name -hitImiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W -Shape (1) (1 (usft) (usft) (usft) 1H-115 T01 -D 042018R 0.00 0.00 3,851.60 1,915.18 7,85345 - plan hits target center - Circle (radius 100.00) 1H-115 T02 -B 042018R 0.00 0.00 3,915.10 1,994.55 7,951.99 - plan hits target center - Circle (radius 100.00) 1 H-115 T03 -Base 04201 0.00 0.00 4,252.10 2,446.91 8,514.02 - plan hits target center - Circle (radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C) (17 118.10 118.10 20" x 42" 20 42 1,824.35 1,780.10 10-3/4"x 13-1/2" 10-3/4 13-1/2 11,118.00 4,251.99 7"x8-3/4" 7 8-3/4 5/112018 10.17.50AM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kupi TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kupamk 1H Pad North Reference: Well: Plan: 114-115 Survey Calculation Method: Wellbore: Plan: 114-115 T-3 Design: 1H-115wp21 K-15 Schlumberger Standard Proposal Report Well Plan: 111-115 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lfthology 1,673.94 1,643,10 Base Pfrost 1,863.45 1,815.10 T-3 2,149.67 2,053.10 K-15 6,413.24 3,113.10 UG -C 8,442.68 3,456.10 UG -B 9,134.94 3,573.10 UG -A 9,740.34 3,689.10 Na 10,180.35 3,851.60 WS_D 10,269.52 3,891.60 WS_C 10,321.91 3,915.10 WS_B 10,393.70 3,947.10 WS -A4 10,487.03 3,986.10 WS -A3 10,672.63 4,067.60 WS A2 10,914.94 4,168.10 WS Al 11,118.27 4,252.10 WS -Base Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +El -W (waft) (usft) (usft) (usft) Comment 500.00 500.00 0.00 0.00 KOP: Start 1'/1 OO'DLS, 105° TF, for 200' 700.00 699.96 -0.90 3.37 Start 2°/100' DLS, -5` TF, for 301.33' 1,001.33 1,000.00 -6.37 29.09 Start 2.5"/l00'DLS, 0' TF, for 618.1' 1,619.43 1,593.10 -38.96 193.13 Hold for 109.02' 1,728.45 1,693.10 -47.43 235.72 Start 3'/100' DLS, -15° TF, for 95.9' 1,824.35 1,780.10 -54.68 275.38 Hold for 20' 1,844.35 1,798.04 -56.15 284.11 Start 4.5'/100' DLS, 0" TF, for 860.84' 2,705.19 2,388.60 -156.39 879.45 Start 4'/100' DLS, -63.29° TF, for 732.94' 3,438.13 2,610.27 -106.11 1,567.66 Hold for 6056.3' 9,494.42 3,633.86 1,617.94 7,282.64 Start 4"/100' DLS, -131.99° TF, for 671.21' 10,165.64 3,845.00 1,906.93 7,843.21 Hold for 14.71' 10,180.35 3,851.60 1,915.18 7,853.45 Adjust TF to 0', for 141.56' 10,321.91 3,915.10 1,994.55 7,951.99 Start 0.5°/100' DLS, 0.65° TF, for 450.22' 10,772.13 4,109.10 2,249.30 8,268.43 Hold for 346.14' 11,118.27 4,252.10 2,446.91 8,514.02 TD: 11118.27' MD, 4252.1' TVD 5/1/2018 10.17:50AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-115 Plan: 1H-115 50029xxxxx00 1 H-115wp21 ConocoPhillips Clearance Summary Anticollision Report 01 May, 2018 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1 Pad - Plan: 1H -115 -Plan: 1H-115-1H-115wp21 Well Coordinates: Datum Height: Plan: 54.1+39 @ 93.10usft (Doyon 142) Scan Range: 0.00 to 11,118.27 usft. Measured Depth. Scan Radius is 1,307.93 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 wellpalhs within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips ConocoPhillips Anticollision Report for Plan: 1H-115-1H-115wp21 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad - Plan: 1H -116 -Plan: 1H-116-1H-115wp21 Scan Range: 0.00 to 11,118.27 usft. Measured Depth. Scan Radius is 1,307.93 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is Unlimited 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 - Destgn (usft) (usft) (usft) (usft) usft Kuparuk 1 H Pad 1H -05 -1H -05-1H-05 2,421.58 104.36 2,421.58 43.46 2,575.00 1.714 Clearance Factor Pass - Major Risk 1 H-05 - 1 H-05 - 1 H-05 2,438.59 102.12 2,438.59 43.54 2,600.00 1.743 Centre Distance Pass - Major Risk iH-05-1H-105-1H-105 2,460.04 82.04 2,460.04 27.79 2,625.00 1.512 Clearance Factor Pass - Major Risk iH-05-1H-105-iH-105 2,478.08 81.44 2,478.08 29.59 2,650.00 1.571 Centre Distance Pass - Major Risk 1 H-102 - 1 H-102 - 1 H-102 - 100.48 329.97 100.48 326.88 100.00 106.920 Centre Distance Pass - Major Risk 1H -102 -1H -102-1H-102 275.47 331.21 275.47 326.32 275.00 67.712 Clearance Factor Pass - Major Risk 1 H-102 - 1 H-1021-1 - 1 H-10211 100.48 329.97 100.48 327.01 100.00 111.630 Centre Distance Pass - Major Risk 1 H-102 - i H-1021-1 - 1 H-1021-1 275.47 331.21 275.47 326.45 275.00 69.564 Clearance Factor Pass - Major Risk 1 H-102 - 1 H-1021-2 - 1 H-1021-2 100.48 329.97 100.48 327.01 100.00 111.630 Centre Distance Pass - Major Risk 1 H-102 - 1 H-1021-2 - 1 H-1021-2 275.47 331.21 275.47 326.45 275.00 69.564 Clearance Factor Pass - Major Risk IH-102-1H-10213-iH-10213 100.48 329.97 100.48 327.01 100.00 111.630 Centre Distance Pass - Major Risk 1H-102-1H-1021-3-iH-1021-3 275.47 331.21 275.47 326.45 275.00 69.564 Clearance Factor Pass - Major Risk 1H -102 -1H -1021-4-1H-1021-4 100.48 329.97 100.48 327.01 100.00 111.630 Centre Distance Pass - Major Risk 1H -102 -IH -1021-4-1H-10214 275.47 331.21 275.47 326.45 275.00 69.564 Clearance Factor Pass - Major Risk 1H -103 -IH -103-1H-103 50.07 269.89 50.07 267.13 50.00 97.958 Centre Distance Pass - Major Risk 1 H-103 - 1 H-103 - 1 H-103 275.06 270.78 275.06 265.12 275.00 47.813 Clearance Factor Pass - Major Risk 1 H-103 - 1 H-10311 - 1 H-10311 50.07 269.89 50.07 267.78 50.00 127.951 Centre Distance Pass - Major Risk 1 H-103 - 1H -103L1 - 1 H-10311 275.06 270.78 275.06 265.38 275.00 50.116 Clearance Factor Pass- Major Risk IH-103-1H-1031-2-iH-1031-2 50.07 269.89 50.07 267.65 50.00 120.512 Centre Distance Pass - Major Risk 1H -103 -1H -10312-1H-10312 8,997.57 377.17 8,997.57 250.67 11,050.00 2.982 Clearance Factor Pass - Major Risk 1H -103 -1H -1031-3-1H-10313 50.07 269.89 50.07 266.22 50.00 73.503 Centre Distance Pass - Major Risk 1H -103 -IH -10313-1H-10313 9,025.58 351.08 9,025.58 206.55 11,200.00 2.429 Clearance Factor Pass - Major Risk 1 H-103 - i H-1031-4 - 1 H-1031-4 50.07 269.89 50.07 266.22 50.00 73.503 Centre Distance Pass - Major Risk 1 H-103 - 1 H-10314 - 1 H-10314 8,709.43 313.78 8,709.43 172.76 10,875.00 2.225 Clearance Factor Pass - Major Risk 1H -109 -1H -109-1H-109 50.10 179.98 50.10 177.61 50.00 75.946 Centre Distance Pass - Major Risk 1H -109 -1H -109-1H-109 400.07 181.55 400.07 173.24 400.00 21.841 Clearance Factor Pass - Major Risk 1H -111 -1H -111-1H-111 550.70 119.93 550.70 110.80 550.00 13.124 Centre Distance Pass - Major Risk 1H -111 -1H -111-1H-111 3,295.26 166.05 3,295.26 83.27 3,175.00 2.006 Clearance Factor Pass - Major Risk 01 May, 2018 - 10:14 Page 2 of 6 COMPASS ConocoPhillips Anticollision Report for Plan: 1 H-115 -1 H-115wp21 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad - Plan: 1H -116 -Plan: 1H-115-1H.115wp21 Scan Range: 0.00 to 11,118.27 usft. Measured Depth. Scan Radius Is 1,307.93 usft. Clearance Factorcutoff is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips (Alaska) Inc. -Kup] Kuparuk River Unit 01 May, 2018 - 10:14 Page 3 orb 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 1H-113 - 1H-113 - 1 H-113 50.06 59.85 50.06 57.28 50.00 23.297 Centre Distance Pass- Major Risk 1H -113 -1H -113-1H-113 349.96 61.41 349.96 55.24 350.00 9.941 Clearance Factor Pass - Major Risk 1H -114 -1H -114-1H-114 725.60 24.34 725.60 12.33 725.00 2.027 Centre Distance Pass - Major Risk 1 H-114 - 1 H-114 -1 H-114 826.00 24.86 826.00 11.51 825.00 1.663 Clearance Factor Pass - Major Risk 1 H-116 - 1 H-116 - 1 H-116 424.67 28.24 424.87 19.58 425.00 3.258 Centre Distance Pass - Major Risk 1 H-116 - 1 H-116 - i H-116 524.78 29.03 524.78 18.31 525.00 2.707 Clearance Factor Pass - Major Risk 1 H-118 - 1 H-118 - 1 H-118 50.25 69.79 50.25 87.05 50.00 32.792 Centre Distance Pass - Major Risk IH -118 - IH -118 - IH -118 848.62 97.37 848.62 83.02 850.00 6.781 Clearance Factor Pass - Major Risk iH-119 - 1H-119 - 1H-119 50.04 120.09 50.04 117.74 50.00 51.099 Centre Distance Pass- Major Risk IH -119 - IH -119 - 1H-119 424.91 123.46 424.91 115.97 425.00 16.469 Clearance Factor Pass- Major Risk 1H-401(UGNU) - IH -401 - 1 HA01 1,625.60 113.01 1,625.60 69.94 1,850.00 2.624 Clearance Factor Pass - Major Risk Plan: 1H -104 -Plan: 1 H-104 - 1 H-104wp23 300.00 209.83 300.00 204.49 300.00 39.276 Centre Distance Pass - Major Risk Plan: 1H -104 -Plan: 1 H-104 - 1 H-104wp23 449.96 211.06 449.96 203.29 450.00 27.176 Clearance Factor Pass - Major Risk Plan: 1H -106 -Plan: 1H-108-1H-108wp21 450.10 239.83 450.10 231.87 450.00 30.112 Centre Distance Pass - Major Risk Plan: 1H -108 -Plan: 1H-108-1H-108wp21 601.50 240.98 601.50 230.75 600.03 23.550 Clearance Factor Pass - Major Risk Plan: 1H -110 -Plan: 1H-110-11-1-110wp28 300.10 149.89 300.10 144.55 300.00 28.048 Centre Distance Pass - Major Risk Plan: 1H -110 -Plan: 1H-110-1H-110wp28 450.06 151.10 450.06 143.32 450.00 19.406 Clearance Factor Pass - Major Risk Plan: 11-1-112 - Plan: 11-1-112 - 1 H-112wp21 500.10 89.85 500.10 81.01 500.00 10.166 Centre Distance Pass - Major Risk Plan: 1H -112 -Plan: 1H-112-1H-112wp21 600.56 90.67 600.58 80.34 600.00 8.777 Clearance Factor Pass - Major Risk Plan: 1H-117 - Plan: 1H-117 - 1H-117wp26.1 475.10 60.24 475.10 51.83 475.00 7.170 Centre Distance Pass- Major Risk Plan: 1H -117 -Plan: 1H-117-1H-117wp26.1 1,295.69 64.32 1,295.69 42.86 1,300.00 2.997 Clearance Factor Pass - Major Risk 01 May, 2018 - 10:14 Page 3 orb COMPASS ConocoPhillips AnticolIision Report for Plan: 1 H-115 - 1 H-115wp21 Survey tool program From To (usft) (usR) 39.00 1,200.00 1H-115wp21 1,200.00 1,824.35 1 H-115wp21 1,200.00 1,824.35 1 H-115wp21 1,824.35 3,324.35 1H-115wp21 1,824.35 11,118.27 1 H-115wp21 Ellipse error terms are correlated across survey tool tie -on 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. Survey/Plan Survey Tool GYD-GC-SS MWD MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit 01 May, 2018 - 10.14 Page 4 of 6 COMPASS %38, May 01 MIS 1 H-115wp21 Ladder View • Cl N .- O m O V A3 0 0 ' 2r �j 1 r 0 ; � \ x � c 300- 00 0 0 a00— - V) t� i c m ' I 0 x1 00 -- c U I' ,u I 0 0 1500 3000 4500 6000 7500 9000 10500 Measured Depth SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 118.10 118.10 20" x 42" 39.00 1200.00 1H-115wp21 (Plan: 11-1-115) GYD-GC-SS 1780.10 1824.35 10-3/4" x 13-1/2" 1200.00 1824.35 1H-115wp21 (Plan: 11-1-115) MWD 4251.919 1118.00 7'x8-3/4" 1200.00 1824.35 1H-115wp21 (Plan: 11-1-115) MWD+IFR-AK-CAZ-SC 1824.35 3324.35 1H-115wp21 (Plan: 11-1-115) MWD 1824.35 11118.27 1H-115wp21 (Plan: 1H-115) MWD+IFR-AK-CAZ-SC " A a 0 3 i r c60— .2 i i I c C 030 w U I ' 0- 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth NaTel ., . 1111 . � : , � ,•• . ..: ... '-, .. . ■ Wil I 1 1 / 11 MOME 1 MEM MM tiI i B i/< • : rs 1 qoy1� � p v.��'1��Q��t 1 : ;HI MEM �� 11111� "'^ 1 ' I�r� t 1�P��I�►��III� eey,�fis,�1. • ►. .,,, ��I ,t., , .,, yY N� �.� A ��r )� � i n1111 P■•tlnNa. • 1 1 •1.1 i 11 I ` r ar/� U.iF FOR." OR."O r ^S _ 5 iri s•I�y.syrylliifi �aoV VIy •• ir�f .1 : 1 r/rld r1 11I r Irn p�JI.r I/IIIir ///�j/� a.AIMMMI, MEMORIES •, rr 1 1 r•�iA d � 74 1 I /� 1 1 �� 1 •1/ � \ ''�j� -�'S • 1 1 : 1 �``\�\�� 1 � _,. ;. 4rQ1�i�l ', I�il/a /0/�!1/Yl�•• 1 1 1 1 1.1 � Irly/allia%/// MEE 8790 • 560 1 Su - 9560 10340 11118 110340 1 :1 1055, May 01 2018 1 H-115wp21 39.00 To 11118.27 AC Wells Only 1H -102L3 1H -102L4 1H -102L2 1H -103L3 1H-102L11H-103L1 1H-118 IH -102 1H -103L2 1 H-05-" iH-119 1H-103 1H -103L4 1H-1 1H-115wp21 c_ 1H-114 1H-104wp23 0 'D 1-117wp26. 1T+-11 1H-10 c t C Z 1H-113 IH -11 1 H-110wp2 1 H-40 1H-112wp21 iH-108wp21 Easting (1500 usf tin) AC Flipbook M09, May 01 2018 1 H-115wp21 39.00 To 1000.00 AC Flipbook SURVEY PROGRAM 39 500 pth FronDepth To Tool 39,00 1200,00 GYD-GC-SS 1H-118 500 - 690 1200.001824.35 MWD 1200.001824.35 MWD+IFR-AK-C 1824.35 3324.35 MWD -_,-0�,,,,,_-_--....... 690 870 1824.391118.27 MWD+IFR-AK-C 3"30 30 870 1060 1060 1240 °-, 1240 1430 CASING DETAILS 16 TVD MD Name1430 118.10 118.10 20" x 42" 300 60 , 1780.101824.3`90-3/4" x 13-1/2" 1610 1800 4251.991118.00 7" x 8-3/4" 1800 2190 MD Azi TFace `° ' 2190 2580 39.00 0.00 0.00 500.00 0.00 0.00 700.00105.00105.00 2580 2960 1001.33101.24 -5.00 1619.43101.24 0.00 2960 3350 1728.45101.24 0.00 270 90 1824.35 99.56 -15.00 __ 3350 _ 3740 1844.35 99.56 0.00 2705.19 99.56 0.00 3740 4120 3438.13 73.21 -63.29 9494.42 73.21 0.00 10165.64 51.15131.99 4120 4510 10180.35 51.15 0.00 �D .. 10321.91 51.15 0.00 1 H-114 4510 49( 10772.13 51.18 0.65 11118.27 51.18 0.00 4900 5680 240 120 5680 6450 6450 7230 " 71 7230 8010 210 150 1H-113 8010 8790 8790 9560 180 9560 10340 H-112wp21 10340 11118 11:11, Mag 01 2018 1 H-115wp21 900.00 To 2000.00 AC Flipbook SURVEY PROGRAM 39 500 pth Fmr�epth To Tool 39.00 12W00 GYD-GC-SS 500 690 1200.001824.35 MWD 1 H-117wp26.1 0 1200.001824.35 MWD+IFR-AK-CA 690 870 1824.35 3324.35 MWD 1824.391118.27 MWD+IFR-AK-C 330 30 870 1060 1 H-116 1060 1240 1240 1430 CASING DETAILS TVD MD Name 1430 16' 118.10 118.10 20" x 42"- 300"� �� 1780.101824.3510-3/4" x 13-1/2" 1610 1800 4251.981118.00 7" x 8-3/4" 1800 2190 MD Azi TFace 30 2190 2580 39.00 0.00 0.00 500.00 0.00 0.00 700.00105.00105.00 2580 2960 1001.33101.24 -5.00 1619.43101.24 0.00 2960 3350 1728.45101.24 0.00 270 90 1824.35 99.56 -15.00 3350- 3740 1844.35 99.56 0.00 2705.19 99.56 0.00 3740 4120 3438.13 73.21 -63.29 _ 9494.42 73.21 0.00 10165.64 51.15131_99 \ 4120 4510 10180.35 51.15 0.00 10321.91 51.15 0.00 4510 49('^ 10772.13 51.18 0.65 11118.27 51.18 0.00 4900 5680 240 120 5680 6450 60 1 H-114 6450 7230 7230 8010 210 150 8010 8790 90 8790 9560 180 9560 10340 10340 11118 11:11, May 01 2018 1 H-115wp21 1900.00 To 4000.00 AC Flipbook SURVEY PROGRAM 39 500 pth FronDepth To Tool 39.00 1200.00 GYD-GC-SS 500 ------- 690 1200.001824.35 MWDH-117wp26.1 0 1200.001824.35 MWD+IFR-AK-CA 690 870 1824.35 3324.35 MWD 1824.391118.27 MWD+IFR-AK-CA 33 .330 870 1060 1060 1240 1H-105 1240 1430 CASING DETAILS 1H-114 TVD MD Name 1430 16 118 11.10 20" x 2" 300 � 17800 1 .1018244.3510-3/4" x 13-1//2" , \60 1610 1800 4251.991118.00 7" x 8-3/4" I / \ / I 1800 2190 MD 0 T 30 2190 2580 0 00 39.00 0.0.00 0.00 500.00 00. 0105.0105.00 1001.33101.24 -5.00 j �' 1 2580 2960 1619.43101.24 0.00 / 2960 3350 1728.45101.24 0.00 1824.35 99.56 -15.00 270 , -•--- r 90 _ 3350 3740 1844.35 99.56 0.00 I i 2705.19 99.56 0.00 3438.13 73.21 \ '/ /i�� 3740 4120 -63.29 9494.42 73.21 0.00 10165.64 51.15131.99 1 \ iq� � l �N� 4120 4510 10180.35 51.15 0.00 ` 30 ° 10321.91 51.15 0.00 �� 4510 49('- 10772.13 51.18 0.65 11118.27 51.18 0.00 j 4900 5680 240 �, 1II / 120 5680 6450 60 6450 7230 7230 8010 21 oma' ,, 150 8010 8790 90 8790 9560 180 9560 10340 10340 11118 11:13, May 01 2018 1 H-115wp21 3900.00 To 11118.27 AC Flipbook SURVEY PROGRAM 39 500 pth FronDepth To Tool 39.00 1200.00 GYD-GC-SS 500 690 1200.001824.35 MWDo 1200,00 1824,35 MWD+IFR-AK-CA 690 870 1824.353324.35 MWD 90 1824.391118.27 MWD+IFR-AK-CA 330 30 870 1060 1060 1240 1240 1430 CASING DETAILS 60 TVD MD Name 1430 16' 118.10 118.10 20" x 42" 300 60 1780.101824.3510-3/4" x 13-v2" 1610 - 1800 4251.981118.00 7" x 8-3/4" 1800 2190 MD Azi TFace 30 2190 2580 39.00 0.00 0.00 500.00 0.00 0.00 700.00105.00105.00 2580 2960 1001.33101.24 -5.00 1619.43101.24 0.00 2960 3350 1728.45101.24 0.00 270 90 1824.35 99.56 -15.00 _ 3350 - 3740 1844.35 99.56 0.00 2705.19 99.56 0.00 3740 4120 3438.13 73.21 -63.29 9494.42 73.21 0.00 10165.64 51.15131.99 4120 4510 10180.35 51.15 0.00 30 10321.91 51.15 0.00 4510 49r 10772.13 51.18 0.65 11118.27 51.18 0.00 4900 5680 240 120 5680 6450 60 6450 7230 7230 8010 210 150 8010 8790 90 8790 9560 180 9560 10340 10340 11118 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 11-1-115 50029xxxxx00 Plan: IH -115 Plan: 1 H-115wp21 Error Ellipse Survey Report 01 May, 2018 Company: ConocoPhillips(Alaska) Inc.-Kup1 Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-115 Wellbore: Plan: 11-1-115 Design: 1H-115wp21 Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MO Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1H-115 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93+10usft (Doyon 142) True Minimum Curvature 1.00 sigma 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 Site Kuparuk 1H Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0 " Grid Convergence: 0.37 ° ell Plan: 1H-115 From ell Position +N/S 0.00 usft Northing: Latitude: Tool Name +E/ -W 0.00 usft Easting: Longitude: rsition Uncertainty 1,200.00 0.00 usft Wellhead Elevation: Ground Level: 54.10 u Wellbore Magnetics Design Audit Notes: Version: Vertical Section: Plan: 1H-115 Model Name BGGM2017 1H-115wp21 Sample Date Declination Dip Angle 6/12/2018 17.06 Phase: PLAN Tie On Depth: Depth From (TVD) +N/ -S +E1 -W (usft) (usft) (usft) 39.00 0.00 0.00 80.93 39.00 Direction 73.00 Field Strength (nT) 57,466 Survey Tool Program Date 5/1/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 1,200.00 1H-115wp21 (Plan: 1H-115) GYD-GC-SS Gyrodata gyro single shots 1,200.00 1,824.35 1H-115wp21 (Plan: 1H-115) MWD MWD - Standard 1,200.00 1,824.35 1H-115wp2l (Plan: 11-1-115) MWD+IFR-AK-CAZ-SC MWD+IFRAK CAZ SCC 1,824.35 3,324.35 1H-115wp21 (Plan: 1H-115) MWD MWD -Standard 1,824.35 11,118.27 1H-115wp2l (Plan: 11-1-115) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 511/2018 10:20.1fAM Page 2 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 Pad Well: Plan: 1H-115 Wellbore: Plan: 11-1-115 Design: 1H-115wp21 Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: Norm Reference: Survey Calculation Method: Output errors are at Database: Plan Survey Tool Program Date 5/1/2018 Depth From Depth To (shift) (waft) Survey (Wellbore) Tool Name Remarks 1 39.00 1,200.001H-115vi (Plan: 11-1-115) GYD-GC-SS Gyrodata gyro single shots 2 1,200,00 1,824.35 1H-115wp21 (Plan: 11-1-115) MWD MWD - Standard 3 1,200.00 1,824.35 1H-11511 1 (Plan: 11-1-115) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 1,824.35 3,324.351/1-115vi (Plan: 11-1-115) MWD MWD- Standard 5 1,824.35 11,118.271H-115wp21 (Plan: 1H-115) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Well Plan: 11-1-115 Plan: 54.1+39 @ 93.10usR (Doyon 142) Plan: 54.1+39 @ 93.1 Dust (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station Wasuretl Inchush n Azimuth Vadmal al9eaiBa Usual Vertical Magnituch San imajor semlminor Depth DI Error Bias Eeor Bias E., Biu 0 Biu Error Error Azimuth Tool (usft) r) P) loan) lure) (usft) (usft) (use) luau) malt) (usft) east) )usft) (°I 3900 0.00 0.00 39.00 000 0.00 0.00 0.00 000 000 000 000 000 000 UNDEFINED 10000 000 0.00 100.00 0.04 000 004 000 1.15 0.00 0.00 0.04 0.04 0.00 GYD-GC-SS(1, 1) 110.10 000 0.00 118.10 0.19 000 0.19 0,00 1.15 0.00 0.00 0.19 0.19 000 GYD-GC-SS(1, 1) 200.00 000 0.00 200eO 0.19 000 0.19 000 1.15 0.00 0.00 019 0.19 0.00 GYD-GCSS(1, 1) 30000 0.00 0.00 300.00 0.33 0.00 0.33 0.00 1.15 001 Del 033 0.33 0.0 GYD-G0SS(1. 1) 40000 0.00 000 40000 048 0.00 048 0.00 1.15 0.01 001 0.48 048 0.00 GYD-GCSS(1, 1) 50000 0.00 0.00 50000 062 0.00 062 OeD 1.15 0.02 0.02 062 0.62 000 GYD-GCSS(1. 1) 600.00 1.00 105.00 599.99 073 0.00 0.73 0.00 1.15 0.03 0.03 0.73 073 45.00 GYD-GGSS(1. 1) 700.00 2.00 10500 699% 081 0.00 0.81 ODID 1.16 0.05 0.05 0.81 031 4500 GYD-GGSS(1, 1) 80000 400 102.50 799.82 090 0.00 0.91 DOO 116 0.07 0.07 0.91 0.91 1456 GYD-GC-S$(1. 1) 900.00 5.99 101.66 89043 1.01 -001 1.02 000 1.16 0.09 0.09 1.02 1.02 1341 GYD-GC-SS(1, 1) 1.000.00 7.99 101,24 99888 1.13 -001 1.15 ON 1.16 0.11 0.11 1.15 1.15 9847 GYD-GC-SS(1, 1) 1,001.33 8.02 101.24 1,000.00 1,13 -001 1.15 000 1.16 0.11 0.11 1.15 1.15 90]2 GY C-SS(1, 1) 1,100.00 10.49 10124 1.097,38 1.25 -001 129 ow 1.16 0.13 0.14 1.29 1.28 10028 GYD-GC-SS(1, 1) 1.200.00 12.99 101.24 1,19528 1.38 -002 1.44 See 1.16 016 016 1.44 142 100.41 GYPGO-65(1.1) 1,300.00 1549 101.24 1,292.20 1.45 -003 154 002 1.15 0.19 0.19 1.54 1.50 100.95 MM (1. 2) 1.400.00 17.99 101.24 1,387.98 145 -0.04 1.67 0.07 1.15 022 0.24 1.67 1.52 10201 MMn.2) 11500.00 2049 10124 1482.36 147 -0.05 1.94 0.13 1.14 0.26 0,29 1.94 1.56 102.10 MWD(1, 2) I.So000 22.99 101.24 1,575.25 1.50 -0.06 236 021 1.14 0.29 0.36 2.36 1.62 102.17 sam(1, 2) 1.619.43 23.47 101.24 11593.10 1.51 -0.05 245 023 1.14 0.30 0.38 245 164 102.17 MAD (1, 2) 1,673.94 23.47 10124 1,643.10 1.50 -0.08 288 030 1.15 0.33 0.45 2.88 1.69 102.14 IAM (1, 2) 1,700.00 23.47 101.24 1,88700 1.56 -a% 2.88 0.30 1.15 0.33 0.45 2.88 1.69 102.14 MWD(1, 2) 1,728.45 23.47 101.24 1,693.10 1.60 -O.D6 3.04 033 1.16 0.34 048 3.04 1.71 102.13 MWM(1, 2) 1,ano.o0 25.55 9895 1.75820 1M -OOB 346 040 1.17 0.37 0.55 145 177 102.02 MWD(1, 2) 1,824.35 26.26 Ratio 1,780.10 1.54 -008 209 002 1.13 0.38 0.39 2.10 1.69 10807 MM (2.3) 1,844.35 28.26 99.56 1,79804 1.54 -0.0 2.13 004 1.13 0.38 0.40 2.14 1.70 10806 MWD(23) 1,803.45 27.12 99,55 11815.10 153 -0.10 231 0.11 1.13 0.41 0.43 2.31 171 104s4 MM (2.3) 1,90000 28.77 99,56 1,84739 153 -0.10 231 0.11 1.13 041 043 2.31 1.71 104a4 MVVD(2, 3) 2,000.00 33.27 99.56 1,93307 1.52 -0.13 283 0.28 1.12 0.46 0.53 2.83 1.76 102.24 JAM (2. 3) 21100100 37.77 Bass 2,01444 154 -0.17 359 045 1.12 0.40 0.80 3.59 1.84 101.23 MVID(2, 3) 2,149.67 40.00 99.56 2,053.10 1.60 -0.21 4.55 0.89 1.14 0.52 O.BB 4.56 1.93 100.72 MwV (2, 3) 5/12018 10:20,11AM Page 3 COMPASS 5000.14 Build 85 Company: ConocoPhillips(Alaska) Inc.-Kup1 Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 11-1-115 Wellbore: Plan: 11-1-115 Design: 1H-115wp21 Position uncertainty and bias at survey station Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1H-115 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Measured Inclination AzinnAh v.dical R1ghude Usual Vertical Magnitude Semianajor Semi+nlner Daptb Depth Error Blas Ermr Bias Eeor Bias MBlas Error Error Azimuth Th01 Wan) (°) r) (usfl) (uaR) (ain) (usfl) (..ft) Wan) (usm (usfl) (usfl) (usa) V) 2,200.00 42.27 99.56 2,09101 180 -021 4.55 069 1.14 0.52 ON 456 193 10032 ATM (2, 3) 2300.00 46]2 99.56 2.162.29 VO -025 5.68 0.97 120 0.55 1.14 568 2.04 100.44 MWD(2.3) 2,40000 51.27 99.58 2,27.88 1.84 -029 6.94 1.29 130 0.58 1.44 694 2.16 100.27 MWD(2,3) 2,500.00 55.7 99.56 2,282.30 2.01 -0.34 830 168 1.45 061 1.80 8.30 2.28 100.15 MWD(2,3) 2.60000 60,27 9950 2.340.26 2M -0.30 9.76 2,07 1.64 O.BI 220 9,76 2.40 100.07 MM (2.3) 2,70000 64.22 99.56 2,386.40 242 -0.43 1128 252 186 066 2.64 11.20 2.51 100.00 uVM(2,3) 2,205.19 65.00 99.56 2,388.60 243 -Odd 11.36 2.55 1.89 0.66 265 11.36 2.52 100.00 MWD(2,3) 2.8o0.0U 66]5 95.82 2.427,36 2,72 -0.53 1224 301 2.15 068 3.10 12]2 2.61 93]6 MM (2. 3) 2.900.00 6869 92.09 2,48529 804 -0.62 14.12 351 264 069 3.52 14.22 2.21 WAS MM (2. 3) so00.o0 20.20 8040 2,50000 sm 471 1547 399 2.24 0.21 4.05 1520 280 9828 MM (2, 3) 3,100.00 MIS 84.81 2,531.32 3.22 -0.60 16.29 646 IN 0.72 453 1710 290 9722 MWD(2,3) 3,200.00 24.95 01.30 2.559.11 603 -0.87 18.07 4.92 138 024 501 1882 2.99 96.01 MWD(2,3) 3,300.00 22.15 n,87 2,583.22 4.33 -0.92 19.30 535 372 025 542 20.14 3.09 94.71 MWD+IFR-AK-CAZ-SC(3,3) 3,400.00 2940 24.49 2,603.54 242 -063 7.84 023 2.12 0.76 101 8.34 243 95.37 MWD+1FR-AK-CAZ-SC(3,3) 3,438.13 80.22 23.21 2,61022 251 -0.64 2.92 0.24 223 020 1.02 852 2.44 94.84 MNID+IFR-AK-CAZ-BC(3,3) 3,50000 8027 2321 2,620.23 281 -0.64 830 0.24 2.33 028 1.04 0.82 2.42 9395 MWD+IFR-AK-CAZ-SC(3,3) 3,60000 80.22 2321 2,632.63 272 4.64 884 0.24 2.50 0.22 1.02 9.33 250 92.62 MM+IFR-AK-CAZSC(3.3) 3,200.00 8022 2321 2.654.53 293 -0.64 940 0.24 2.66 0.28 141 9.86 2.54 91.44 MWD+1FR-AK-0A2-SC(3,3) 3,800.00 80.22 2321 2,621.43 3.10 -0.64 995 0.24 2.03 0,78 1.14 10.39 252 90.36 MW0+1FR-AK-CAZSC(3,3) 3.900.00 80.22 2121 2,888.33 3.22 -0.07 10.51 0.24 300 0.79 1.17 1092 2.60 8943 MM+1FR-AWCAZ-SC(3, 3) 4,000,00 60.22 2321 2,20523 3.43 -064 11,08 024 3.17 0.80 1.21 11.42 263 88.57 MWD+1FR-AK-CAZ-SC(3, 3) 4,100.00 00.22 73.21 2,222.14 160 -084 1165 0.24 3.34 0.81 1.25 1201 206 82.80 MWD+1FR-A)(-CAZ-SC(3,3) 4,200.00 00.27 73.21 2,739.04 3]2 -084 1221 0.24 3.51 0.81 1.28 1258 2.09 8709 MW IFR-W-CAZ-SC(3, 3) 4,300.00 80.27 7121 2.755.94 3.94 -0.64 12.28 0.24 3.68 082 1.32 1312 212 8645 MW IFR-AK-0AZ-SC(3,3) 4,400.00 80.27 23.21 2,77284 4.12 .064 13.30 0.24 3.85 083 1.36 13.68 2,75 85,86 MND+IFR-AK-CM-W(3.3) 4,500.00 80.27 7321 2,78974 4.29 -064 13.93 0.24 4.02 084 140 14.24 2.78 85.32 MWD+1FR-AK-0AZ-SC(3,3) 4,600.00 80.22 23.21 2,80664 4.46 -064 14.51 0.24 4.19 0.84 1.44 14.80 2.80 84.82 MM+IFR-AK-CAZ-SC(3, 3) 4,700.00 80.22 23.21 2,823.54 683 464 15.08 024 4.32 085 148 15.30 2.83 8432 MM+IFR-AK-CAZ-W(3,3) 4,800.00 80.27 7321 2,840.44 4.81 -064 15.66 024 4.54 086 153 15.93 2.86 83.94 MWD+IFR-AK-CAZ-SC(3,31 4,900.00 80.22 73.21 2,852.34 4.98 -064 1024 024 4.71 0.87 1.52 16.50 289 8355 MWO+IFR-AK-CAZSC(3,3) 5,000.07 80.22 73.21 2,87425 5.15 464 16.82 024 4.80 0.86 181 17.07 2.92 03.10 MWD+1FR-AK-CAZSC(3.3) 5110000 9022 7321 2,691.15 5.33 -0.64 1740 0.24 5.06 0.89 160 12.64 2.94 82.84 MWD+1FR-AK-CAZSC(3,3) 5200.00 80.22 73.21 2,900.05 550 4.64 1798 024 5.23 0.09 1,70 18.21 2.92 82.52 MWD+1FR-AK-CAZSC(3,3) 5,300.00 80.22 23.21 2,92485 588 464 1856 0.24 5.40 090 176 1829 3.00 02.23 MWD+IFR-AK-DAZ-$C(3, 3) 5.400.00 80.27 73.21 2,941.85 585 464 19.14 0.24 558 0.91 179 1936 303 8195 MWD+1FR-AK-CAZ-SC(3,3) 5,500.00 80.22 23.21 2,90.75 803 -0.64 1972 024 5.75 D.92 1.84 1994 306 81.68 MM+IFR-AK-CAZ-SC(3,3) 5,600.00 80.22 7121 2.825.65 620 -0.64 20.31 0.24 5.92 0.93 189 2051 800 81.44 MWDHFR-AK-CK-SC(3,3) 5.200.00 8022 73.21 2.992.55 6.38 -0.64 20.89 024 6.10 094 1.91 21.09 3.11 8120 MWD+IFR-AWCAZ-SC(3,3) 5,800.00 80.22 23.21 3,09.46 8.55 -0.64 2147 024 6.27 0.94 1.98 21.87 3,14 8098 MWD+1FR-AR-CAZ-SC(3,3) 5180000 8022 2321 3,026.36 6.23 -064 22.06 024 845 095 2.03 2225 3.17 80,78 MWD+1FR-AK-CAZ-SC(3, 3) 6,o0000 80.27 73.21 3.043.26 6.90 464 2264 0.26 662 0.96 208 22.83 320 90.58 MWD+IFR-AK-CAZ-SC(3,3) 6.10000 8027 73.21 3000.16 2.08 -0.64 23.23 0.24 679 0.97 2.13 23.41 3.22 80.39 MWD+1FR-AK-CAZ-SC(3,3) 6,200.00 80.27 73.21 3,07.06 2.25 -064 23.81 024 897 0.98 2.18 23.99 325 80.21 MWD+IFRAK-CP-SC (3,3) 6.30000 80.27 73.21 sm.% 2.43 484 24.40 0.24 7.14 0.99 224 24.52 328 80.05 MWD+IFR-AWCAZ-W(3.3) 8.40000 8017 73.21 3,110.86 2.61 -0.64 24.90 0.24 2.32 100 2.29 25.15 3.31 79.88 MWD+IFR-AK-CP-SC (3.3) 6,41121 60.7 73.21 3,113.10 778 -0.84 25.52 0.24 7.49 1.01 2.34 2573 3.34 79.73 MWD+1FR-AK-CAZ-SC(3,3) 8.50000 0027 73.21 3,1776 778 -0.64 25.52 0.24 2.49 101 234 2573 3.34 79.23 AAM+IFR-AK-CP-SO (3,3) 60000 8022 7321 3,144.67 2.96 -0.84 26.15 0.24 787 102 2.39 26.31 3.32 2059 MWD+IFR-AK-CAZ-SC(3,3) 6]0000 80.27 73.21 3.16157 8.14 .0.64 28]4 0.24 2.84 103 245 211.90 340 29.45 MVMAFR-AK-CAZ-SC(3.3) 6.070.00 80.27 73.21 3.17842 8.31 -0.64 22.32 0.24 8.01 1.04 250 22.48 343 29.31 MND+IFR-AK-CAZ-SC(3,3) 6,900 00 No 73.21 3,195.37 8.49 -064 27.91 024 6.19 1.05 256 28.06 345 29.19 MWD+IFR-AK-CAZ-SC(3,3) 7,00a00 80.27 23.21 3,212.27 8.67 -064 28.50 0.24 0.35 106 261 28.64 368 29.06 MM+IFR-AK-CAZ-SC(3, 3) 7,100.00 80.22 23.21 3.229.17 8.84 -0.64 28.08 0.24 0.54 1.07 267 2923 351 28.95 MWD+1FR-AK-CAZSC(3,3) 7,200.00 80.27 23.21 3,246.07 9.02 484 29.67 024 8.71 1.08 272 2881 3.54 28.83 MWD+IFR-AK-CAZ-SC(3,3) 5/12018 70:20: ifAM Page 4 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kupawk l H Pad Well: Plan: 11-1-115 Wellbore: Plan: 1H-115 Design: 1H-115wp21 Position uncertainty and bias at survey station Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: iH-115 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Measured Inclination AunuN vertical Highslde uw.l Venical all 3.1ma)or semiminor Depth Depth Emr 01. Emr Bias Ertor alas 0Bias E. Ertor AZMuM Tool (valn 1°1 11) Wan) loan) roan) Was) (osu (waft) (uaft) (waft) (uso) asim (1) 7,30000 0027 7321 3252.97 920 -064 30.26 0.24 8.89 109 2.78 30.40 357 7873 MW0+IFR-AK-CA-SC(3,3) 7,400.00 80.2] 73.21 3,279.87 937 -064 Mail 024 90fi 1.10 2.84 30.96 3.60 7&62 MWD+IFR-AK-CA-BG (3.3) 7,500.00 80.27 73.21 3,296]8 9.55 .064 3143 0.26 9.24 1.11 2.89 31.57 3fi3 7852 MWD+1FR-AW0AZS0(3, 3) 7,89000 80.27 7321 3,31363 973 -1164 32.02 0.24 941 1.12 2.95 32.15 3.66 78.43 MWD+1FR-AK-CA -SC (3, 3) 7.700.00 60.27 7321 3,330.50 9.90 -064 32.61 024 9.59 1.13 3.01 32.74 369 70.33 MWD+IFR-AK-CA -SC (3, 3) 7,80000 00.27 73.21 3.347.48 1008 -0.84 33.19 0.24 9.6 1.14 307 33.32 3.2 7925 MWD+IFR-AK-CAZ C(3, 3) 7,90000 00.27 7321 3.304.38 1026 -0.64 33.78 024 994 1.15 3.13 33.91 3.5 78,16 MWD -IFR -AK -CA -SC (3, 3) eolxi00 80.27 7321 3,381.28 1043 -0.64 34.37 0.24 10.11 1.16 3.19 3/49 378 78.00 MWD+IFRAI(-CA-SC(3, 3) 0,100.00 80.27 73.21 3,398.18 1061 Alas 3496 0.24 10.29 1.17 325 3500 3.81 7800 MWD+IFR-AK M-BC(3,3) 0,200.00 80.27 73.21 3,41508 1079 -0.84 35.55 0.24 1046 1.16 331 35.66 3.84 77.92 MWD+IFR-AWCA-SC(3,3) 8,300.00 8027 7321 3431.99 10.97 -0.64 36.13 024 1064 1.19 3.38 W25 387 77.85 MM -IFR -MC -SC (3.3) 8,400.00 0027 73.21 3,448.09 11.14 -0.64 36.72 024 1081 1.20 3.44 36.04 390 77.77 MWD+IFR-AK-CM-80(3.3) 8,442.60 80.27 73.21 3,456.10 1132 -0.84 3731 D.24 Was 1.21 ?50 37.42 3.93 77,70 MWD+IFR-AK-CA-SC(3, 3) 0.500.00 8027 73.21 3,485]9 1132 -e64 37,31 024 less, 1.21 3.50 37.42 3.93 7770 MWD+IFR-AK-CALSC(3,3) 6.600.00 00.27 73.21 3,40269 11.50 -064 37.90 0.24 11.16 1.22 3.56 38.01 3.98 77,64 MM+IFR-AK-CMSC(3,3) 0,700.00 00.27 73.21 3,499.59 11.67 -0.64 3849 0.24 11.34 L23 3.63 38.60 4.00 77.57 MW0+1FR-AK-CA-SC (3,3) 8,000.00 80.27 73.21 3,51849 lies -0.64 3907 0.24 1151 1.24 3.69 39.18 403 07.51 MW0+1FR-AK-CA-SC (3,3) 8.90000 0027 73.21 3,533.39 1203 -064 3986 0.24 11.69 1.25 3.76 39.77 408 T,44 MWD+IFR-AK-CMSC (3.3) 9,000.00 00.27 73.21 3,550.29 1221 -084 40.25 024 11.86 1.27 302 40.36 4.09 77.39 MWDHFR-AK-CA-SC(3, 3) 9.100.00 809 73.21 3,567.19 12.30 -064 40.84 0.24 1204 128 3.89 40.94 4.12 77.33 MMAFR-AK-CA -SC (3, 3) 9,134.94 80.27 73.21 3.573.10 12.56 -0.84 41.43 0.24 12.21 1.29 395 4153 4.15 77.27 MWD+IFR-AK-CAZ C(3,3) 920000 80.27 73.21 3,684.10 1258 -064 41.43 024 1221 1.29 3.95 41.53 4.15 77.27 MWD+IFR-AK-CA-SC(3,3) 9,307.00 8027 7321 3,60100 12.74 -064 42.02 0.24 12.39 1.30 4.02 42.12 4.18 77.22 MWD+IFR-AK-CA-SC(3,3) 940seD 80.27 73.21 3,617.90 12.92 4'84 4281 024 12.56 1.31 4.09 42.71 422 77.16 MWDHFR-AK-CMSC(3,3) 9,49442 80.27 73.21 3.633.86 13.08 4) 84 43.16 024 12.3 1.32 4.15 4326 4.25 77.11 MWD+IFR-AK-CA-SC(3,3) 9,500.00 00.12 7304 3,63481 13.10 -063 43.18 025 1234 1.32 4.15 43.29 4.25 77.11 MW IFR-AK-CM-SC(3.3) 9,600.00 77.46 70.00 3.65425 13.38 4),44 4337 046 12.91 134 4.23 43.70 4.28 77.07 MWD+IFR-AK-CA-SC(3,3) 9.70000 7684 Well 3,678.19 13.71 -0.25 43.43 068 13.00 1.38 4.30 44.11 431 7700 MW AFR-N(-CA-GC(3.3) 9,74034 73.9 65.61 3,689.10 14.12 -006 43.34 090 13.25 1.38 4.39 44.50 4.35 76.90 MWD+IFR-AWCALSC(3,3) 9.800.00 72.26 8370 3.70652 14.12 -0.08 4334 0.90 13.25 1.30 4.39 44.50 435 76.90 MWD+IFR-AK-0A-SC(3,3) 9.900.00 8973 6042 3,739.10 1464 0.10 43.08 1.14 1342 141 4.48 "All 4.39 76.78 MWDAFR-AK-CA-SC(3,3) 10,00000 67.26 57.04 3,775]6 15.31 026 42.64 1.38 13.50 145 457 4323 4.44 76.64 MWD+IFR-AK-CP-SG (3,3) 10.100.00 64.87 53.53 3,818.34 16.16 0.40 4200 1.63 13.73 1.49 4.67 45.57 4.51 7840 MWD -IFR -AK -GA -S (3,3) 10.16584 03135 51.15 3,045.00 1683 0.48 4148 180 13.03 152 4.3 4578 4.56 76.37 MWD+IFR-AK-GA-SG(3.3) 10,18035 63.35 51.15 3.85160 1885 0.48 41.52 1.80 13.85 1.53 475 45.83 4.56 76.34 MWD+IFR-AK-CA SC (3, 3) 10,200.00 63.35 51.15 3.66041 1680 048 41.62 180 1388 154 4.7 4592 4.58 76.29 1AWD+IFR-AK-CA -SC (3, 3) 10289.52 6335 51.15 3,89160 17.03 048 42.12 1.80 A03 1.59 4.87 4838 403 76.03 MVMIFR-AK-CMSC(3, 3) 10,300.00 63.35 51.15 3,905.27 17.03 048 42.12 1.80 14.03 1.59 687 4838 4.0 76.03 MWD+IFR-AK-CA-SG(3, 3) 10,321.91 63.35 51.15 31915.10 1700 0.48 42.23 180 14% 1.80 4.89 4849 465 75.90 MWD+IFR-AK-CA -SC (3, 3) 10,39370 6371 51.15 3,947.10 17.12 0.45 42.63 180 14.10 164 4.98 4685 470 75.8 MWD+IFR-AK-CMSC(3, 3) 10,400.00 63.4 51.16 3,94989 17.12 045 4263 180 1418 164 4.98 46.05 470 75.8 MWDNFR-AK-CA -SC (3, 3) 10,407.03 04.17 51.16 3,900.10 17,21 041 43.14 1.00 14.33 1.69 5.08 47.32 436 75.53 MM+IFR-AK-CA-SC(3, 3) 10,500.00 64.24 51.16 3.99375 17.21 041 43.14 1.80 14.33 169 508 47.32 476 7553 MWD+IFR-N(-W-SC(3,3) 10.600.00 64.74 51.17 4,038.82 17,30 037 4386 t00 1448 1.3 5.19 47.79 4.82 7529 MWDNFR-AR-CA-SC(3,3) 10,67263 65.10 51.17 4,067,60 17.39 0.33 44.10 1.80 1484 1.8 5.29 46.26 489 7304 MWD+IFR-AR-CA -SC (3,3) 10.70000 65.24 51.17 4,07910 17.39 0.33 44.10 1.80 14.84 1.8 5.29 48.26 4.89 75.04 MWD+IFR-MR- -SC (3,3) 10,772.13 65.00 51.18 4,109.10 17.45 0.30 44.55 1.80 1475 1.82 537 4861 4.94 74.87 MWDHFR-AR-CA-SC(3,3) 10,800.00 65.60 51.18 4.120.61 17.49 0.30 44.70 1.00 1429 1.83 540 40.4 4.96 74.80 MWD+IFR-AK CM -80 (3.3) 10.900.00 65.60 51.18 4,18193 17.65 0.30 45.22 1.60 14.94 1.80 5.51 49.22 5.02 74.56 MWD+IFR-AKCA-SC(3,3) 10,91494 65.00 51.10 4,168.10 17.80 0.30 4574 1.00 15.10 1.92 5.62 49.70 5.09 74.33 MWD+IFR-M-CA-SC(3.3) 11,000.00 85.60 51.18 4,203.24 17,80 0.30 45.4 1.00 15.10 1.92 5.62 49.0 5.07 74.33 MWD+IFR-AK-CA-8C(3, 3) 11,10000 65.60 $1.10 4,244.55 17.95 0.30 4826 1.00 1525 1.97 5.72 WAS 5.16 74.10 MWD+IFR-AWCA-SC(3, 3) 11,118.00 85.60 51.18 4,251.99 17.98 0.30 48.36 1.00 15.28 1.90 575 50.27 5.18 74.06 MW IFR-AK-CALW(3.3) 11,11827 65.60 51.18 4,252.10 17.90 0.30 46.36 1.00 1528 1.90 5.75 50.27 5.18 7406 MWD+IFR-MK- -SC (3.3) 5712018 10.20: IIAM Page 5 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupamk River Unit Site: Kupamk 1H Pad Well: Plan: 1H-115 Wellbore: Plan: 1H-115 Design: 1H-115wp21 Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Design Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +Nl-S +E/ -W -Shape V) V) (usft) (usft) (usft) 1H-115 T01 -D 042018 R 0.00 0.00 3,851.60 1,915.18 7,853.45 - plan hits target center - Circle (radius 100.00) 1 H-115 T02 -B 042018 R - plan hits target center - Circle (radius 100.00) 1 H-115 T03 -Base 04201 - plan hits target center -Circle (radius 100.00) 0.00 0.00 3,915.10 1,994.55 7,951.99 0.00 0.00 4,252.10 2,446.91 8,514.02 Well Plan: 111-115 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Formations Measured Vertical Casing Points Depth Depth Dip Direction (usft) Measured Vertical 1,673.94 Casing Hole Depth Depth T-3 Diameter Diameter (usft) (usft) Name C') C9 118.10 118.10 20"x42" 20 42 1,624.35 1,780.10 10-3/4" x 13-1/2" 10-3/4 13-1/2 11,118.00 4,251.99 7"x8-3/4" 7 8-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology V) (�) 1,673.94 1,643.10 Base Pfrost 1,863.45 1,815.10 T-3 2,149.67 2,053.10 K-15 6,413.24 3,113.10 UG -C 8,442.68 3,456.10 UG -B 9,134.94 3,573.10 UG -A 9,740.34 3,689.10 Na 10,180.35 3,851.60 WS—D 10,269.52 3,891.60 WS_C 10,321.91 3,915.10 WS_B 10,393.70 3,947.10 WS_A4 10,487.03 3,988.10 WS—A3 10,672.63 4,067.60 WS_A2 10,914.94 4,168.10 WS Al 11,118.27 4,252.10 WS—Base 5/12018 10:20:11AM Page 6 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupanik River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-115 Wellbore: Plan: 11-1-115 Design: 1H-115wp21 Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 11-1-115 Plan: 54.1+39 @ 03.10usit (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 500.00 500.00 &00 0.00 KOP: Start 1°/100' DLS, 105° TF, for 200' 700.00 699.96 -0.90 3.37 Start 2°/100' DLS, -5° TF, for 301.33' 1,001.33 1,000.00 -6.37 29.09 Start 2.5-/100' DLS, 0° TF, for 618.1' 1,619.43 1,593.10 -38.96 193.13 Hold for 109.02' 1,728.45 1,693.10 47.43 235.72 Start 3°/100' DLS, -15° TF, for 95.9' 1,824.35 1,780.10 -54.68 275.38 Hold for 20' 1,844.35 1,798.04 -56.15 284.11 Start 4.5.1100' OLS, 0° TF, for 860.84' 2,705.19 2,388.60 -156.39 879.45 Start 4'/100' DLS, -63.29° TF, for 732.94' 3,438.13 2,610.27 -106.11 1,567.86 Hold for 6056.3' 9,494.42 3,633.86 1,617.94 7,282.64 Start 4'/100' DLS, -131.99° TF, for 671.21' 10,165.64 3,845.00 1,906.93 7,843.21 Hold for 14.71' 10,180.35 3,851.60 1,915.18 7,853.45 Adjust TF to 0*, for 141.56' 10,321.91 3,915.10 1,994.55 7,951.99 Start 0.5°1100' DLS, 0.65° TF, for 450.22' 10,772.13 4,109.10 2,249.30 8,268.43 Hold for 346.14' 11,118.27 4,252.10 2,446.91 8,514.02 TD: 11118.27' MD, 4252.1' TVD Checked By: Approved By: Date: 511/2018 10: 20: 1fAM Page 7 COMPASS 5000.14 Build 85 Pool Report 11:22, May 01 2018 1 H-1 1 5 w p 21 WELLBORE TARGET DETAILS OMP CO-ORDINATES) Name TVD 1H-115 T01 -D 042018 RP 935180 Shape CWa (RadW IMOD) Quarter Mile View 1H-115 T01-0042018 RP OM 1H-115 T02 -B 042018 RP T02-8 042018 RP OM 995,00 9915.10 "Ie (FI 192000) CWe (RaOius: 10000) 1H-115 1H-115 T03 -Base 042018 PP 3915.10 4252.10 Cimle (Rachis' 1320,00) Circle (Radios: 100.00) 6000 ,H-102 ^ 1H -102L1_ ^� ''.. ^�N 500 4500- 1H-,18 w 9 ^ I � � C 3 ,�NnG j to 7 C- C)3000 LO jos � iH-114 + _ L � � 81500- 1500 z Z 1H-109 y O 'S (n 0- -1500- -1500 7_41 -.107 i - -1500 0 1500 3000 4500 6000 7500 9000 10500 West( -)/East(+) (1500 usft/in) 1H-115wp21 Surface Location 41 Coordinate Converter From: Datum: INAD83 I Region: alaska +� r- Latitude/Longitude Decimal Degrees J C UTM Zone: �' F South r- State Plane Zone: 4 + Units us -ft + t - Legal Description (NAD27 only) Starting Coordinates: -- --------- X: 1168958505 Y: 15980743.49 �1H-115wp21 Surface Casing CPAP Coordinate Converter From: ---- -- - -. - _.... ---- -_ Datum: NAD83 Region: alaska + t' Latitude/Longitude IDecimalDegrees + t UTM Zone: I- r- South r State Plane Zone:q + Units: us--ft--3 I r Legal Description (NAD27 only) To Datum: NAD27 Region: alaska + C' Latitude/Longitude IDecimalDegrees + r UTM Zone: True r South r: State Plane Zone: q + Units: us -ft + r Legal Description (NAD27 only) I---- ---- . ---- - ------ FEndingCoordinates. ----- ---- -- ---- - X: f 549553.428073663 Y: 5980991.67622377 Transform Quit I Help lolal To:. -._... ---- Datum: NAD27 Region: alaska + r Latitude/Longitude IDecimalDegrees + C UTM Zone: True F- G State Plane Zone: F--:-] Units: us -ft + C Legal Description (NAD27 only) Starting Coordinates:— ------- Ending Coordinates: ----- --- - -- X: 11689860.76 x 549829.13355178 Y: 159806M63 Y: 5980938.8122525 — - _Transform _ Quit Help 1H-115wp21 Top of Production Horizon PAI Coordinate CIn_ e o From: _. -. _ _.. _....-._--- ---. -.... - To -.-.- Datum: NAD83 Region: alaska Datum: NAD27 Region: alaska f Latitude/Longitude IDecimaiDegiees r Latitude/Longitude Decimal Degrees f UTM Zonal— r South r UTM Zone: True r South r State Plane Zone: q Units: us -ft , r State Plane Zone: q . Units: us -ft i fi Legal Description (NAD27 only) C"' Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X: 1697425 X 557393.274439425 Y: 5982710 Y: 5982957.99085178 Transform Quit Help 1 H-115wp21 TD M CPAI Coordinate Converter q Fie I'1°'°°z` 4 '-From:-------- Datum NAD83 . Region: alaska I • Latitude/Longitude IDecimalDegrees f•UTM Zone: r South G State Plane Zone:__q Units: us -ft • Legal Description (NAD27 only) To:. Datum: NAD27 Region:alaska T Latitude/Longitude Decimal Degrees C UTM Zone: True r South r State Plane Zone: q - I Units: us -R r Legal Description (NAD27 only) Starting Coordinates: ---------------- Ending Coordinates, X: 11698082 Y: 15983246 ........................................................... . i Transform X: 1558050.266771782 Y: F5983493.96555127 Quit Help 1H-115wp21 Surface Location -CPAs Coordinate Converter From: - - - -- - -- Datum: NAD83 Region: alaska r Latitude/Longitude IDecimalDegrees UTM Zone: F— r South F State Plane Zone: F--3- Units: us -ft C Legal Deacription IPlA,G27 on,V) - Starting Coordinates:---------- ----- X: 11689585.05 Y: 15980743.49 1H-115wp21 Surface Casi In CPA' Coordinate Converter To:__ -- Datum: INAD27 I Region: falaska 11 r Latitude/Longitude Decimal Degrees�J� f•UTM Zone: True r South r• State Plane Zone: jq Units: us -ft C• Legal Description (NAD27 only) Legal Description Township: 012 FN—,-] Range: 010 E Meridian: U Section:28 FNL - 4991.1885 FEL 785.76969 .............. _Transform ! Quit Help From -- Datum: INAD83 Region: alaska C Latitude/Longitude Decimal Degrees —� r" UTM Zone: I- r South C State Plane Zone: 14 -j Units: us -ft i i Legal DescJip(inn (P13k<7 oril}) Starting Coordinates: --- X: 11689860.76 Y: 15980690.63 =Q To Datum:NAD27 Region: alaska r Latitude/Longitude IDecimalDegrees • UTM Zone: True r South • State Plane Zone: r4 ----_-w] Units: us -ft G Legal Description (NAD27 only) Legal Description----- -- Township: 012 FN-.] Range: 010 E Meridian: JU Section:28 FNL 5045.8852 FEL 510.52020 -......-Trensfo..... ��..__....! Quit Help �� From: Datum: NAD83 I Region: alaska {' Latitude/Longitude IDecimalDegrees _.._ f UTM Zone: r— r South G State Plane Zone: q - Units: us -ft r Legal Description (Nr.D27 anbrl - -StartingCoordinates: --- -- X: 11697425 Y: 5982710 1 H-115wp21 TD M CPAs Coordinate Converter From: . ------ ---- -- __ _.. 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Per K170005ACS N 25 30 29 28 27 I 25 1G 36 37 IRKc5 33 34 T i inp (JJ3536 /I� T11NR DE 5 4 3 6 2 1 ®120 1A 14A ASP GRID NORTH 0119 12 7 CPFl 10 c 0118 8 9 '4'P 11 12 0117 �o 0116 0115 18 7 16 15 14 13 0114 1E LEGEND ®113 0112 IF 1a 24 24 19 20 21 2 23 0 AS—BUILT CONDUCTOR ®111 0110 VICINITY MAP • EXISTING CONDUCTOR 0109 SCALE: 1" = 2 MILES 0104 ®108 0103 28 27 oil 33 34 ®102 0106 0101 DS1 H •20 •19 022 •17 •16 •15 •1 •2 •3 •4 •UGNU 01 •14 •5 •12 •11 •10 06 •21 013 •9 07 •18 �1• SEE SHEET 2 & 3 FOR COORDINATE TABLE " 111111i AREA: 1H ConocoPhillips Alaska, Inc. NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSOC. 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 L16-35, L16-40, L17-02 & L17-03. 6. ALL DISTANCES SHOWN ARE GROUND. GRAPHIC SCALE 0 100 200 400 1 inch = 200 ft. 10 LOUNSBURY & ASSOCIATES, INC. 911RWYDRS nGINEERE PWNNERS MODULE: XXXX UNIT: D1 DS1H WELL CONDUCTOR 11 102/01/171 JAH I LGM I (Create Per K170005ACS 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. 1 787' 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 1 5,980,961.86' 549,555.50' 1 N 70' 21' 31.575" W 149' 35' 51.006" 259' 784' 48.0' 54.1' *115 1 5,980,991.68' 549,553.43' N 70' 21' 31.868" W 149' 35' 51.062" 289' 1 786' 1 48.0' 54.1' *116 5,981,021.61' 549,551.58' N 70' 21' 32.163" W 149' 35' 51.110" 319' 1 787' 48.0' 54.1' *117 5,981,051.73' 549,548.80' N 70' 21' 32.459" W 149' 35' 51.185" 349' 790' 4&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" 438' 795' 48.0' 54.1' * CONDUCTOR ASBUILT THIS SURVEY �;•.•LAY .' 49th W *% 1 c-.JEREMIAH •F. CORNELL -- �♦.,� n•.LS.12663•••.a,O•,�SAV Pow SURVEYOR'S CERTIFICATE 1 HEREBY CERTIFY THAT I 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 THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE CORRECT AS OF JANUARY 31, 2017. LOUNSBURY & ASSOCUTES, INC. :VSYORS RNGIMERS PW NERS AREA: 1H MODULE: XXXX UNIT: DI ConocoPhillips DS1H M WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO. PART: REV: LK6108d31 12/27/16 1 CEA-D1HX-6108D31 1 3 OF 3 1 Appendix ■ Tier 1: Standard ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ Drilling within 30° of horizontal inclination AND drilling within 30°of magnetic East/West azimuth in extreme northern or southern locations ■ Tier 3: Critical Steering ■ Driller's Target of 50' Radius or Less ■ Lease line constraint ■ Small Geologic Target ■ Failure of Major Risk Rule (Close Approach) ■ Defined during directional planning, based on the positional uncertainty ■ Theoretical intersection of the path of the well being planned with an offset well ■ If HSE risks are eliminated, the Tolerable Collision Risk assessment can be implemented ■ Tier 4: Single section containing both Tier 2 and Tier 3 challenges 6 ... ConocoPhillips ■ Tier 1 (Standard): ■ Directional interval across which no special mitigations are needed ■ Tier 2 (Challenging Orientation): ■ Increase non-magnetic insulation of MWD tool in the BHA ■ Take rotational check shots and/or increase survey frequency at the start of a BHA run ■ Alter well directional plan, if feasible ■ Consider gyro surveys where feasible ■ Tier 3 (Critical Steering): ■ Increase survey frequency across critical interval ■ Increase correction frequency across critical interval ■ Take rotational check shots and/or increase survey frequency if the critical interval is at the start of a BHA run ■ Define escalation based on deviation from plan ■ Minor Risked close approach intervals with a high financial or scope risk should strongly consider the use of relevant mitigations ■ Tier 4 (Critical Steering & Challenging Orientation): ■ Consider all Tier 2 & 3 mitigations 7 eve's'• i� eiii € Conoc( Phillips 1H-115 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 Stuck pipe Low temperatures, additions of ScreenKleen. Running sands and gravels Low Maintain planned mud parameters, increase mud weight, Abnormal reservoir pressure Low use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), Differential sticking Moderate pumping out Washouts / hole sloughing Low Cool mud temperatures, minimize circulating times when Hole swabbing on trips 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 Low 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), pum ing 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-115 Dolling Hazards.doc 51WO18 Ln C c Wellhead / Tubing Hanger / Tree 13-3/8" x 4-V2' IBTM, 5M Insulated Conductor: Crossover below TH : 4-1/2" x 3-1/2" Tubing 20" Casing r� 10-3/4" 45.5#, L-80 HYD563 @ 1,824 ft MD RA/PIP Tags @ 3,000'& 9,950' MD 3-1/2", 9.2 #, L-80, Hyd 563 3-1/2" MMG with SOV Feed Through Packer #4: 10,150' MD Multi Drop Gauge Mandrel 2.812" Cameo D Nipple Upper MM710,412'MD Lower MM Feed Through Packer #3: 10 Multi Drop Gauge Mandrel Up Low Feed Through Packer #Multi Drop Gaugeanre Upper MMG Lower MMG Feed Through Packer #L 10,500"MD Single Drop Gauge Mandrel 2.813" Cameo XN Nipple Upper MMG _ Lower MMG Baker WIV 1 H-115 Injector Well Design PTD Wellbore Schematic °D" Sand Perforations: 10180'-10281' MD Semper/Magnet Assy Dumb iron muleshoe "B" Sand Perforations: 10322'- 10396' MD A4 Sand Perforations: 10428'- 10465' MD A3 Sand Perforations: 10564' - 10612' MD e� 7" 26#, L-80, HYD563/TXP @ 11,118' MD s ails llIAa Attachment 6 BOP Confi¢uration 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. Loepp, Victoria T (DOA) From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Thursday, May 24, 2018 8:55 AM To: Loepp, Victoria T (DOA) Cc: Bearden, J Daniel Subject: RE: [EXTERNAL]RE: Expedited PTD for 1H-108, 1H-115 Follow Up Flag: Follow up Flag Status: Flagged Victoria, Good morning and thank you for the note. We apricate the state's assistance, this will give us some operational flexibility as operations/reservoir condition dictate. Hope you have a great Memorial Day weekend! 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.gov] Sent: Thursday, May 24, 2018 8:14 AM To: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Cc: Bearden, J Daniel <J.Daniel. Bearden @conocophillips.com> Subject: RE: [EXTERNAL]RE: Expedited PTD for 1H-108, 1H-115 These two PTDs will be ready by June 1, likely sooner. From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Wednesday, May 23, 2018 8:59 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Bearden, J Daniel <J.Daniel. Bearden@conocophillips.com> Subject: RE: [EXTERNAL]RE: Expedited PTD for 1H-108 The 1H-115 would be the next well after the 1H-108. Best estimate would be 6/16.. 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: Wednesday, May 23, 2018 8:19 AM To: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Cc: Bearden, J Daniel <J.Daniel. Bea rden@conocophillips.com> Subject: [EXTERNAL]RE: Expedited PTD for 1H-108 What is the revised spud date for 1H-115? Will there be revisions to the submitted PTD package? From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Wednesday, May 23, 2018 7:17 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.Rov> Cc: Bearden, J Daniel <J.Daniel.Bearden conocophillips.com> Subject: Expedited PTD for 11-1-108 Victoria, Good morning. We wanted to reach out this morning and contact you regarding a PTD for the 1H-108 that was delivered to the AOGCC yesterday. Due to a last second change in the rig schedule, we are asking for an expedited PTD approval on the 11-1-108 (planned spud date of 6/4). We are currently drilling the 11-1-110 injector, which is the first well placed in the "south" block of our 1H NEWS development program (see red outlined of "South Block" in 1H NEWS Development Nap below). While drilling the 8- 3/4" production section late Monday night and early Tuesday morning, we drilled though our 5 reservoir sands and encountered 2 sands with oil, 2 sands that were wet, and 1 sand with what we believe is an oil/water contact. We are needing an additional data point and time to adjust/calibrate our understanding of the southern fault block and any knock-on effects that has on the last pent -lateral to be drilled (11-1-104). Because of this, we are asking the state to help us fast track the permit for the 11-1-108 so we can drill the 11-1-108 next. This will allow for a data point (up structure) within the "south" block and give us some time to delineate where is the oil/water contact within each of these sands. Knowing that information, will be critical to help ConocoPhillips prudently and responsibly develop the south block. We would like to have a follow-up phone call today to further discuss any questions you might have. Please let us know if there is any further info we can provide to help assist the 11-1-108 in moving through the system. 11-1 NEWS Development Map ._1014 Offi ne aefr:ear, South Bock Where is extent of oil/water contact? Thanks, Ben Tolman Staff Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(o)1(307) 231-3550(m) 11-1-110 IH -113 3 a -y MI. oa una lol OG b.ee 1 nt O` •. w.. t ' ., q.. 6 I Il. 14 Gi I .A'11 1 � 1 ._1014 Offi ne aefr:ear, South Bock Where is extent of oil/water contact? Thanks, Ben Tolman Staff Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(o)1(307) 231-3550(m) 11-1-110 IH -113 3 a -y Davies, Stephen F (DOA) From: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Sent: Friday, May 4, 2018 4:14 PM To: Davies, Stephen F (DOA) Subject: RE: [EXTERNAL]KRU 11-1-115 (PTD #218-053) - Request 11-1-117 will not be pre -produced Nick Lehman Drilling Engineer I Conoco Phillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Lehman@ConocoPhillips.com From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Friday, May 4, 2018 4:10 PM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: RE: [EXTERNAL]KRU I1i-115 (PTD #218-053) - Request Nick, One more question: Will this well be pre -produced for 30 days or longer, or will it simply be flowed back for clean up? Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.daviesrdalaska.eov. From: Lehman, Nick R [mailto:Nick.R.Lehman@conocophillips.comj Sent: Friday, May 4, 2018 3:46 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.eov> Subject: RE: [EXTERNAL]KRU 11-1-115 (PTD #218-053) - Request Yes, normally pressured down to the WestSak. The only zone we may some depletion in is the WestSak due to offset production, but if we do see depletion, we don't expect it to be more than 0.1-0.4 ppg. Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Leh man @ConocoPhillips. corn From: Davies, Stephen F (DOA)[mailto:steve.davies@alaska.eov] Sent: Friday, May 4, 2018 3:16 PM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: RE: [EXTERNAL]KRU 11-1-115 (PTD #218-053) - Request Davies, Stephen F (DOA) From: Lehman, Nick R <Nick.R.Lehman@conocophilli ps.com> Sent: Friday, May 4, 2018 3:46 PM To: Davies, Stephen F (DOA) Subject: RE: [EXTERNAL]KRU 1 H-115 (PTD #218-053) - Request Yes, normally pressured down to the WestSak. The only zone we may some depletion in is the WestSak due to offset production, but if we do see depletion, we don't expect it to be more than 0.1-0.4 ppg. Nick Lehman Drilling Engineer I Conoco Phillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick.R.Lehman@ConocoPhillips.com From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Friday, May 4, 2018 3:16 PM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: RE: [EXTERNAL]KRU 11-1-115 (PTD #218-053) - Request Nick, So the entire geologic section, from Sagavairktok though Ugnu, Schrader Bluff, and West Sak, are all expected to be 8.4 to 8.6 ppg EMW? Any depleted sands? Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies0alaska.eov. From: Lehman, Nick R [mailto:Nick.R.Lehman@conocophillips.coml Sent: Friday, May 4, 2018 3:11 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.aov> Subject: RE: [EXTERNAL]KRU 1H-115 (PTD #218-053) - Request Stephen, On submitted PTD application for 1H-115, please see the following for answers to your questions. I also attached snapshots from the application. Please feel free to give me a call to discuss if needed, my office is 907-263-4951 and my cell is 832-499-6739. Expected Formation Tops — Attachment #2, Directional Program, 14th page Estimated pore pressure - Page 4 of PTD, under Drilling Hazards Information, "Requirements of 20 AAC 25.005 (C)(4) lbwiro Bhof211AAC LKWi,x4i .Lnr.1N w bWTl,xuw IJr yfvnvrn nwb�MvJ �=n N1 h fd.1�1 The maximum potential wrface pressure (MPSP) while drilling I H-115 is calculated using an estimated max inmm reservoir pressure of 1.819 psi (Naw4 on IH -105 MDT pressure of 1769 psi. SA ppg equivalent, and corrected to depth), a gas gradient of 0.10 psilh, and the estirnaW depth of the West Sak A2 sand 114,068' TVD: A Sand Estimated. BHP = 1.819 psi A Sand estinfated depth = 4.168' TVD Gas Gradient = 0.10 psi ft as per 20AAC 25.6Y75 (ch4)(A) Hydrostat of full gas column = 4Q7 psi (6,068' TVD n 0.10 psifft) MPSP=BHP- gas column =1,41?IIA (1,819 psi -407 psi) 111,2.+.n /.✓ .: N_+ The well bore is not expected to penetrate any shallow gas zones. 3,.r il) a.r 1.8..8.8, rv•..w.w..., ,ym.srnns.v ..+e. ciw.wnUv r+.,...w.e e,w, h,.,,c.b„w,Jw....) %,..,1y. p/,.. nro•ue.1" Ae.n.w n. Jwr Sec attached IH• 115 Drilling; Hazards Summar -3 o Normally pressured with no abnormal pressure, page 6 under Abnormally Pressured Formation Information. "Requirements of 20 AAC 25.005 (CI(9) RramirmwoU of 20 AAC 25.007 409) WA - Application is not for an explomory of stradgmphic test well. o Thus, pore pressure of 8.4-8.6ppg expected Nick Lehman Drilling Engineer I Conoco Phillips Alaska SchlumbefW ConoeoPhil lips StwNlwd Proposal Re9e,t nrMm WKm1b] twacpOiounobY 9INR lh.o3 aWWY cwowptmpsvam)M-KW1 TWO 901. Rin 511.79 a 931ou1C1(Do1ao 1111 q�pC K19l LL191R111 bM1Y0i: Ric U I.79 o 97.1(WN I8epnIV) WX K11p11t 1M P11 1010111 rAf woo T81 9811 R IWI15 r CMOND OINUM 119111Km CVYaie 111619: PWL 16.115 41W. nI.115MIQ1 fO1111didill, 11111111111101 Mad no OWN 41111 t# abeam 1194 I1t14 If1911 MOW C 111 +511.91 1,43.11 nae o95n lA6aH 1A16.10 TJ 2.IN.W 1.8W.W K-15 6A177/ 1117.111 uric 1647.60 311%.19 U" 9.171.91 3,515.18 u[.A 974-34 3,609.11 M W,118,37 3,16158 w5 o *269A1 3,191.68 YP_C 10.711.91 1.915.10 919_0 10,797.18 3,911.t8 M M ICAfm 3.900.10 W�_AI 1657263 4851A8 WS-V 109491 414.18 9G-Al 11.111,9 1752.10 YO%5 M Estimated pore pressure - Page 4 of PTD, under Drilling Hazards Information, "Requirements of 20 AAC 25.005 (C)(4) lbwiro Bhof211AAC LKWi,x4i .Lnr.1N w bWTl,xuw IJr yfvnvrn nwb�MvJ �=n N1 h fd.1�1 The maximum potential wrface pressure (MPSP) while drilling I H-115 is calculated using an estimated max inmm reservoir pressure of 1.819 psi (Naw4 on IH -105 MDT pressure of 1769 psi. SA ppg equivalent, and corrected to depth), a gas gradient of 0.10 psilh, and the estirnaW depth of the West Sak A2 sand 114,068' TVD: A Sand Estimated. BHP = 1.819 psi A Sand estinfated depth = 4.168' TVD Gas Gradient = 0.10 psi ft as per 20AAC 25.6Y75 (ch4)(A) Hydrostat of full gas column = 4Q7 psi (6,068' TVD n 0.10 psifft) MPSP=BHP- gas column =1,41?IIA (1,819 psi -407 psi) 111,2.+.n /.✓ .: N_+ The well bore is not expected to penetrate any shallow gas zones. 3,.r il) a.r 1.8..8.8, rv•..w.w..., ,ym.srnns.v ..+e. ciw.wnUv r+.,...w.e e,w, h,.,,c.b„w,Jw....) %,..,1y. p/,.. nro•ue.1" Ae.n.w n. Jwr Sec attached IH• 115 Drilling; Hazards Summar -3 o Normally pressured with no abnormal pressure, page 6 under Abnormally Pressured Formation Information. "Requirements of 20 AAC 25.005 (CI(9) RramirmwoU of 20 AAC 25.007 409) WA - Application is not for an explomory of stradgmphic test well. o Thus, pore pressure of 8.4-8.6ppg expected Nick Lehman Drilling Engineer I Conoco Phillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Lehman @ConocoPhillips, co m From: Davies, Stephen F (DOA)[ma iIto: Steve. davies@alas ka.eovl Sent: Friday, May 4, 2018 1:40 PM To: Lehman, Nick R <Nick.R.Lehman@conocophiIlips.com> Subject: RE: [EXTERNAL]KRU 11-1-115 (PTD #218-053) - Request Nick, Could CPA] please provide a list of expected formation tops (TVD preferably, or TVDSS) and estimated pore pressures (in units of psi or ppg) expected in 114-115 similar to the example shown below (taken from another operator's public - domain Permit to Drill application)? This allows me to ensure that the planned mud program is adequate and that no over- or under -pressured formations are anticipated. (See 20 AAC 25.005(c)(4).) Formation Tops and Pore Pressure Estimate (SOR) Formation Depth (TVDss) Most Likely Pore Pressure (ppg) Fluid Type (for sands only) SV4 2617 8.40 KOP - 9 518" 2868 8.40 SV3 3063 8.40 Water SV2 3201 8.40 Water 3584 8.40 Water SV1 3585 9.00 Water UG4 3985 9.30 Water UG3 4260 9.30 Water UG1 4990 9.30 Water 5319 9.30 Water WS2 5320 8.70 Water WS1 5502 8.70 Water 5710 8.70 Water CM3 5711 9.30 Thanks, Steve Davies AOGCC 111L, AC- d"d 06 �f q,2-- /O, o 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 Steve Davies at 907-793-1224 or steve.daviesCdalaska.aov. From: Lehman, Nick R [mailto:Nick.R.Lehman@conocophillips.com] Sent: Friday, May 4, 2018 12:45 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.eov> Subject: RE: [EXTERNAL]KRU 114-115 (PTD #218-053) - Request Sure Stephen. Attached is the 11-1-115 wellplan. Please note that the geodetic reference for X -Y coordinates listed in this survey is NAD83. Thanks, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-49511 Cell (832)499-6739 Nick.R.Lehman@ConocoPhillips.com From: Davies, Stephen F (DOA)[mailto:steve.davies@alaska.eovl Sent: Friday, May 4, 2018 12:20 PM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: [EXTERNAL]KRU 11-1-115 (PTD #218-053) - Request Nick, I would like to ask a favor of you. There are two staff geologists at AOGCC, but one retired last week, so --for the near term --I will be the geologist reviewing all Permit to Drill and Sundry applications for Alaska. It will save me time if CPAI could provide proposed directional survey data in electronic form in addition to the printed survey provided with each Permit to Drill application. Having survey data in Excel or ASCII -table format saves me about 20 minutes per application (else I have to scan and convert each page to spreadsheet -format in order to load the data into my geoscience workstation). If this is inconvenient, don't worry about it; it just cuts down application permit -processing time for everyone. Thank you, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.daviesPalaska.eov. Remark: AOGCC PTD No. 218-053 - Coordinate Check 4 May 2018 INPUT Geographic, NAD27 KRU 1H-115 Latitude: 70 21 31.86800 Longitude: 149 35 51.06200 OUTPUT State Plane, NAD27 5004 - Alaska 4, U.S. Feet 1/1 Northing/Y: 5980991. 639 Easting/X: 549553.418 Convergence: 0 22 44.63597 Scale Factor: 0.999902789 Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: Wa ( /- //S PTD: l7 /C�— /-)S! Development V Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: /4 i POOL: G�/�SCf� �1 / Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL (If last two (tits No. , API No. 50- -_ Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- _) from records, data and logs acquired for well name onpermit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) 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 Requiremepts 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 WCLL rCKMI I I:HCGKLI, I nein a reel KUVAKUK KlVtK, We5T SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1H-115 Program SER Well bore seg PTD#: 2180530 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type SER / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Administration 17 Nonconven, gas conforms to AS31,05,03ft t.A),(LZA-D) - - - - - - - - - - - - - - - - - - - - NA 1 Permit fee attached. ....................... .. ... - NA--- - ..---...... 2 Lease number appropriate... - - - - - - --- - - - - -- - - - - - - -- - - - - - - - Yes - - _ Surface Location lies within ADL0025639; Top Prod Int & TD lie within ADL0025638.. 3 Unique well. name and number - - - - - - - - - - - - - - - - Yes 4 Well located in.a defined pool- - - - - - - - - - -- - - - - - ---- - - - --- .. - Yes - - Kuparuk River, West. Sak Oil Pool - 490150, governed by CO 406C 5 .Well located proper distance from drilling unit boundary .. . . . . . . . . ..... . Yes - - CO 406C, Rule 3: no restrictions as to well spacing except that no pay shall be cps ned in a well closer 6 Well located proper distance from other wells.. _ - - - - - - - - - - - - - - Yes _ - than 500 feet loan externalpropertyline where ownership or landownership changes, 7 Sufficient acreage.available indrilling unit . - _ _ - - _ ... _ _ - - Yes - _ - . Well is more than 500 feet from an external property line. 8 Adevisted, is wellbore plat. included - - - - - - Yes 9 Operator only affected pargr. - - - - - -- - - - - - - - - Yes - 10 Operator has. appropriate bond in force - _ - - - - ---- - - - - - - - --- - - - - - Yes Appr Date 11 Permit can be issued without conservation order- - - - - - - - - - - - - - - - Yes SFD 5/9/2018 12 Permit can be issued without administrative approval - - - - - - _ - _ - Yes 13 Can permit be approved before 15 -day wait- _ - _ _ _ _ - - _ - Yes .... 14 Well located within area andstrata authorized by. Injection Order # (put. 10# in. comments) (For: Yes 15 All wells. within 1/4 mile area of review identified (For service well only).. - _ - ... Yes .... - _ _ Area Injection Order No. -2B 16 18 Pre -produced injector; duration of pre production less than 3 months. (For service well only) . Conductor stringprovided... - - - - - . . .. . . . . .. . . . _ No . - Yes .. Operator; Well will not be preyproduced. 80' conductor set. Engineering 19 Surface casing. protects all known USDWs - - - - - - - - - -- - -- - - -- - - - - -- - - - - . - - - Yes - _ .. - _ ... - - ... Surface shoe at 1824' MD_ 20 CMT vol adequate to circulate on conductor & surf csg . . . . . . .... . .... . . . . .. Yes - - - 138%. excess cement planned - - - - 21 CMT, vol adequate to tie-in long string to surf csg- - - - - - - - - . _ .. . - No 22 CMT will coverall known. productive horizons - - - _ - - _ . _ .. _ Yes _ - Productive. interval will be completed with perforated production casing 23 Casing designs adequate for C, T, B &-permafrost ... . . ... . . . .. . . . . . . . .Yes - 24 Adequate tankage or reserve pit - .. - _ - - _ - .... - - - - ..... _ . Yes - - Rig has steel tanks; all waste.to approved disposal wells 25 If a re -drill, has a 1Or403 for abandonment been approved - - _ - - - ... - - .. NA _ 26 Adequate wellbore separation proposed _ - - - - - - .. - - - - - - - .. - Yes - - - Anti -collision analysis complete; no major risk failures 27 If djverter required, does it meet regulations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. - Yes - - - Diverter size and route meets regulation Appr Date 28 Drilling fluidl program schematic & equip list adequate- - _ - - - _ - - - . - . _ - - . Yes _ - - Max fpnnation pressure is 1819 psig(8.6 ppg EMW); will drill w/ 8.8-10.0 ppg-EMW VTL 5/29/2018 29 BOPES,_do they meet regulation _ - - - _ _ . - _ - _ - _ _ _ - - _ - - _ - - Yes 30 BOPE.press rating appropriate; test to (put psig in comments). - - - - - - - - - .. . Yes ... _ MPSP is 1412 psig; will fest BOPS to 3500_psig. _ 31 Choke manifold complies w/API. RP -53 (May $4). _ - - .. - -Yes 32 Work will occur without operation shutdown- - - - - Yes 33 Is presence of H2S gas probable- - - _ - - - - - - - .. - - Yes 34 .Mechanical.condition of wells within AOR verified (For service well only) - - . - _ - Yes .. - _ - .. 1 H-103, IHA 15 and 1H-113 proposed mechanical condition verified.. _ . _ 35 Permit can be issued w!o hydrogen, sulfide measures _ - - _ - - - ... - - - _ No - H2S measures required, Well 1H -102 20 ppm H2S on November 20, 2017. Geology 36 Data. presented on potential overpressure zones--- - - - - - - - - -- - _ ... _ ... Yes _ -measured - Expected reservoirpressure is 8.4.- 8,6 ppg EMW; will -be drilled with 8.$ - 10.0 ppg mud. Appr Date 37 Seismic analysis of shallow gas.zones- - - - - - - - - - --- - - - - - - NA SFD 5/4/2018 38 Seabed condition survey (if off -Shore) . . ..... . . . ... . . . . ... - . - - ... NA - - - - - 39 Contact name/phonefor weekly -progress reports [exploratory only].. - _ - ... - _ - - NA _ - Geologic Engineering Pub' Commissioner: Date: Commissioner: Date Date 6T S/�0I/'(� n 'r7" l �" 1, e� n